ML13008A524

Initial Exam 2012-301 Final SRO Written Exam

ML13008A524
Person / Time
Site:	Brunswick
Issue date:	01/03/2013
From:	NRC/RGN-II
To:	Progress Energy Carolinas
References
Download: ML13008A524 (190)

Text

M - - - - - - - - - - (0 CO 0) 01 C) r\.) - z 3 M ro rJ 0)01 - () M - 0 (31 - ) M - 0(00) -i

- J 4. 4 C,3 () () (.) (.) () () () CA) CA) M N) N) N) 01 4 m

(0 (0 (0 (0 (0 (0 CD CO 0) 0) CO C)) 0) 0) CO 0) 0)

- (0 (0 0 0) CA N) - 0 (0 0) - 0) -

CD (0 0) - 0) 01 ( N) - C) (C> CO J 01 4

- - - N)

C) - - - - - - - - -

ES-401 Site-Specific SRO Written Examination Form ES-401-8 Cover Sheet U.S. Nuclear Regulatory Commission Site-Specific SRO Written Examination Applicant Information Name:

Date: Facility/Unit:

Region: I El II El Ill El IV El ReactorType: WEICEEIBWE]GEEI Start Time: Finish Time:

Instructions Use the answer sheets provided to document your answers. Staple this cover sheet on top of the answer sheets. To pass the examination you must achieve a final grade of at least 80.00 percent overall, with 70.00 percent or better on the SRO-only items if given in conjunction with the RO exam; SRO-only exams given alone require a final grade of 80.00 percent to pass. You have 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> to complete the combined examination, and 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> if you are only taking the SRO portion.

Applicant Certification All work done on this examination is my own. I have neither given nor received aid.

Applicants Signature Results RO/SRO-Only/Total Examination Values / / Points Applicants Scores I I Points Applicants Grade I I Percent

1. Unit Two is operating at rated power when the 2A CRD pump trips.

The 2B CRD pump has been stwted.

The following CRD conditions e*st:

CRD CHARGING WTR PRESS HI is in alarm CRD flow rate is at 30 gpm Cooling water differential pressure is 18 psid Which one of the following choices completes the statements below?

The CRD CHARGING WTR PRESS HI annunciator setpoint is set to alarm when charging water pressure is jj.

lAW 2OP08, Control Rod Drive HydrauHc System Operating Procedure, to clear this alarm the procedure will direct A. (1) 1510 psig (2) throttling closed C12-FOI4B, CRD Pump 2B Discharge Isolation Valve B. (1) 1510 psig (2) throttling closed C12-PC\-F003, Drive Pressure Vlv C. (1) 275 psid above reactor pressure (2) throttling closed Ci2F0i4B, CRD Pump 2B Discharge Isolation Valve D. (1) 275 psid above reactor pressure (2) throttling closed C12-PCV-F003, Drive Pressure Vlv Page 1 of 100

2. Which one of the following identifies the power supply to 20 RHR Pump?

A.E1 B. E2 C.E3 D.E4 Page 2 of 100

3. RHR Loop A is operating in the Shutdown Cooling mode of operation with the following parameters:

RHRSW Pump 2A Operating RHRSW Flow 2000 gpm RHR Pump 2A Operating RHR Loop A Flow 6000 gpm Which one of the following choices completes the statements below?

The required operator action to lower the cooldown rate lAW 20P-17, Residual Heat Removal System Operating Procedure, is to (1)

The effect of this action is that heat exchanger shell to tube differential pressure will (2)

A. (1) throttle open El l-F048A, HX 2A Bypass Valve (2) rise B. (1) throttle open Ell-F048A, HX 2A Bypass Valve (2) lower C. (1) throttle closed E1l-PDV-F068A, HX 2A SW Disch Vlv (2) rise D. (1) throttle closed El1-PDV-F068A, HX 2A SW Disch Vlv (2) lower Page 3 of 100

4. Unit Two is in Mode 3 with shutdown cooling in service when a loss of 2D RHRSW Booster pump occurs.

Both RHR pumps and 2B RHRSW pump continue to operate.

The operator observes annunciator RHR HXA/B Disch Cig Wtr Temp Hi in alarm and the RHR HX service water ouflet temperature is indicating 185°F.

Which one of the folowing choices completes the statements below?

Continued operation with this alarm in wiB cause JIj.

lAW the APP, the operator is required to (2)

A. (1) overheating of the RHR Pumps (2) raise RHRSVJ flow B. (1) overheating of the RHR Pumps (2) throttle open E1l-FOO3B, HX 2B Outlet Vlv C. (1) short term seismic qualification concerns with the RHRSW system (2) raise RHRSW flow D. (1) short term seismic qualification concerns with the RHRSW system (2) throttle open Eli -FOO3B, HX 2B Outlet Vlv Page 4 of 100

5. Unit Two is operating at rated power when the circuit breaker on 120V Distribution Panel 32A to the NUMAC Steam Leak Detection Monitor B21-XY-5948A and 5949A trips.

Which one of the following identes the effect of this condition on the HPCI system?

A. E41-F002, HPCI Inboard Steam Line Isolation Valve, will immediately auto-isolate.

B. E41-F003, HPC! Outboard Steam Line Isolation Valve, will immediately auto-isolate.

C. The area temperature isolation signal is disabled for the E41-F002, HPCI Inboard Steam Line Isolation Valve. E41-F002 remains open.

D. The area temperature isolation signal is disabled for the E41-F003, HPCI Outboard Steam Line Isolation Valve. E41-F003 remains open.

Page 5 of 100

6. A transient has occurred on Unit One causing the following plant conditions:

Drywell pressure 12 psig Reactor water leve 65 inches Reactor pressure 360 psig Which one of the following choices completes the statement below?

E21-FOO5A, Core Spray A Inboard Injection Valve, is (1) , and E21-FO3IA, Mm Flow Bypass Valve, is (2)

A. (1) open (2) open B. (1) open (2) closed C. (1) closed (2) open D. (1) closed (2) closed Page 6 of 100

7. An ATWS has occurred on Unit One and reactor water level deliberately lowered lAW LPC. The following conditions exist:

Reactor Water Level maintained between LL4 and TAF Reactor Power 9%

Reactor Pressure 960 psig SLC Tank Level 2800 gallons SLC Pumps Both operating Which one of the following choices completes the statements below?

Adequate mixing of the boron with reactor water (1) assured at this level.

Under the current conditions the time for the SLC tank to reach 0% would be approximately (2) minutes.

A. (1) is (2) 32 to 34

8. (1) is (2) 65 to 68 C. (1) is NOT (2) 32 to 34 D. (1) is NOT (2) 65 to 68 Page 7 of 100

8. Unit Two is in a hydraulic ATWS with the following plant conditions:

Reactor power 31%

Mode Switch RUN Which one of the following additional conditions will prevent the operator from resetting RPS and inserting a manual scram prior to the LEP-02, Section 3 jumper installation with the given conditions?

A. SDV HI-HI LEVEL RPS TRIP annunciator sealed in.

B. Reactor water level is at 170 inches.

C. IRMA UPSCALE/INOP and IRM B UPSCALE/INOP annunciators sealed in.

D. B21-F022A, Inboard MSIV and B21-F028D, Outboard MSIV, closed.

Page 8 of 100

9. Unit One is at rated power. Reactor Engineering has completed performance of OPT-Ol .9, LPRM CaUbration. The TIPs are currently located at the indexer.

Which one of the following choices compietes the statements below?

The TIPS Indexer is ocated in the (1)

While the TIPS are being withdrawn to the inshield position the expected control room annunciator(s) is(are) (2)

A. (1) TIP Room (2) Area Rad Rx Bldg High and Tip Room High Rad B. (1) TIP Room (2) Tip Room High Rad ONLY C. (1) Drywell (2) Area Rad Rx Bldg High and Tip Room High Rad D. (1) Drywell (2) Tip Room High Rad ONLY Page 9 of 100

10. Which one of the following choices completes the statements below?

The (1) varies the sensitivity levels as the IRM range switches are operated.

The IRM Channel Range Corr&ation Adjustment is required to be performed prior to range (2)

A. (1) voltage preamplifier (2) 3 B. (1) voltage preamplifier (2) 7 C. (1) pulse height discriminator (2) 3 D. (1) pulse height discriminator (2) 7 Page 10 of 100

ii. Unit Two is in the prcoess of 2 ctcr stat:: lAW OGP02, Approach to Criticality and Pressurization of the Reactor. cowing a refueling outage.

The following SRM read in are indicated:

All IRMs are on range 4.

Which one of the following identifies the expected plant response with the shorting links installed?

A. Alarm ONLY.

B. Alarm and rod block ONLY.

C. Alarm, rod block and 1/2 scram.

D. Alarm, rod block and full scram.

Page 11 of 100

12. The current quantity of operating LPRM detectors in the flux average is 17 for APRM 1.

An operator is preparing to bypass another LPRM on APRM 1.

Which one of the foowing predicts the expected annunciator(s) that will alarm after bypassing this LPRM?

A. APRM Trouble ONLY.

B. APRM Upscale Trip/mop ONLY.

C. APRM Trouble and Rod Out Block.

D. APRM Upscale Trip/mop and Rod Out Block.

Page 12 of 100

13. Unit One is operating at rated pcier.

Which one of the following identifies the impact of a loss of DC Switchboard 1A, if any, on Reactor vessel level control using RCIC?

RCIC (1) automatically initiate on a subsequent low level signal.

The E51-F045, Turbine Steam Supply Vlv, (2) auto-close on a subsequent high level signal.

A. (1) will (2) will B. (1) will (2) will NOT C. (1) will NOT (2) will D. (1) will NOT (2) will NOT Page 13 of 100

14. Unit Two operating at rated povIer when a small break LOCA occurs simultaneously with a Loss of Off-site Power to both units.

Reactor water level 35 inches Reactor pressure 600 psig and stabe DGI, DG2 and DG3 Tied to their respective busses DG4 Locked out 2A RHR pump failed to auto-initiate 2D RHR pump failed to auto-initiate 2A Core Spray pump tripped on overcurrent 2B Core Spray pump Under clearance ADS Inhibit Switches in AUTO Based on the conditions above, which one of the following identifies:

(1) the current status of Auto Depress Timers Initiated annunciator and (2) a subsequent operator action that will result in the ADS valves opening?

A. (1) The annunciator is in alarm (2) Starting 2A RHR Pump.

B. (1) The annunciator is in alarm (2) Starting 2D RHR Pump.

C. (1) The annunciator is NOT n alarm (2) Starting 2A RHR Pump.

D. (1) The annunciator is NOT in alarm (2) Starting 2D RHR Pump.

Page 14 of 100

15. Unit Two is operating at rated pcwer with B Loop Suppression Pool Cooling in service with cooling maximized.

A plant transient results in the foHowing stable conditions:

DW pressure 3 psg Reactor pressure 400 psig Reactor water level 50 inches Which one of the following choices completes the statement below?

In order to re-establish Suppression Pool Cooling lAW the SPC hard card, (1) must be restarted and the use of RHR SW Booster Pumps B & D LOCA Override Switch (2) be required.

A. (1) the 2BID RHR and 2BID RHR SW pumps (2) will B. (1) the 2BID RHR and 2B/D RHR SW pumps (2) will NOT C. (1) ONLY the 2B/D RHR SW Pumps (2) will D. (1) ONLY the 2B/D RHR SW Pumps (2) will NOT Page 15 of 100

16. A LOCA has occurred on Unit To. Subsequently a steam line leak occurs on the RCIC system. The following plant conditions are present 10 minutes after the steam line leak occurred:

Reactor water level 95 inches Drywell pressure 3.5 psig Reactor pressure 900 psig RCIC Steam Line Tunnel Ambient Temp 170°F The CRS orders the RO to manually isolate RCIC.

Which one of the following describes the effect when the RCIC Manual Isolation System B pushbutton is depressed on the E51-F007 and F008, Inboard and Outboard Steam Supply Isolation valves?

A. E51-F007 and F008 auto-close.

B. ONLY E51-F008 auto-closes.

C. ONLY E51-F007 auto-closes.

D. E51-F007 and F008 remain open.

Page 16 of 100

17. Unit 1 is operating at rated powe.

An operator is performing the vave operabiHty checks portion of OPT-08.2.2B, LPCIIRHR System Operability Test Loop B, and is preparing to stroke the E11-FOI6B, Drywell Spray Otbd sol Vlv, and E11-FO2IB, Drywell Spray Inbd isol Vlv.

Which one of the following compietes the statements below lAW OPT-08.2.2B?

The E11-FOI6B and E11-FO2IB J1J both be opened at the same time during the performance of this test.

When El 1-F021 B is stroked during this portion of the test, some water (2) enter the Dryweli through the spray header.

A. (1) can (2) may B. (1) can (2) will NOT C. (1) can NOT (2) may D. (1) can NOT (2) wfll NOT Page 17 of 100

18. Which one of the following choices completes the statements below lAW PCCP and 001-37.8, Primary Containment Control Procedure Basis Document?

In the PC/P leg, suppression pooi spray must be initiated before (1) pressure reaches 11.5 psig.

If suppression pool spray is NOT initiated before reaching 11 .5 psig, then (2)

A. (1) drywell (2) a crack could occur at the junction of the downcomer and the vent header B. (1) drywell (2) air wiH be drawn in throuç the vacuum relief system to deinert the primary containment C. (1) suppression chamber (2) a crack could occur at the junction of the downcomer and the vent header D. (1) suppression chamber (2) air will be drawn in through the vacuum relief system to deinert the primary containment Page 18 of 100

19. During Unit Two power operation, a power supply loss results in a reactor scram. The operator notes the fcowing MSRI indications immediately after the scram:

Inboard DC solenoid white light OUT Inboard AC solenoid white light LIT Outboard DC soenoid white Ught OUT Outboard AC solenoid white ight OUT Which one of the foliovving identfies the power supply that has been lost?

A. Division I AC Power B. Division I DC Power C. Division II AC Power D. Division Il DC Power Page 19 of 100

20. Which one of the following identfies the valves that can be operated from the RSDP and identifies the effect that a loss of MOO IXDB will have on the Unit One SRVs operations from the RSDP?

The control switches for SRVs B, E, and JJj are located on the RSDP.

These valves j2) be operated from the RSDP following a loss of MOO IXDB.

A.(1)F (2) can B. (1) F (2) can NOT C.(1)G (2) can D. (1) G (2) can NOT Page 20 of 100

21. Unit Two is operating at rated power with no activities in progress.

A leaking SRV has resulted in rising Suppression Pool temperature.

Which one of the following choices competes the statement below?

When Suppression Pool temperature first exceeds (1) entry into (2) is required.

A. (1) 95°F (2) POCP ONLY B. (1) 105°F (2) POCP ONLY C. (1) 95°F (2) POOP and RSP D. (1) 105°F (2) PCCP and RSP Page 21 of 100

22. Unit Two is at 20% power with main turbine ml! in progress lAW 20P-26, Turbine System Operating Procedure. irbine speed is 900 RPM and slowly rising.

The following turbine journal bearing vibration readings are observed on TSI-XR-640:

Bearing #1 5 ms Bearing #6 10 mils Bearing #2 5 ms Bearing #7 Ii mils Bearing #3 6 ms Bearing #8 13 mils Bearing #4 7 miis Bearing #9 11 mils Bearing #5 8 mis Bearing #10 10 mils Which one of the foflowing:

1) predicts the plant response ard

2) identifies required operator action(s), if any, lAW 20P-26?

A. (1) An automatic turbine trip will occur.

(2) Manually scram the reactor.

B. (1) An automatic turbine trip will occur.

(2) The reactor is NOT required to be manually scrammed.

C. (1) An automatic turbine trip will NOT occur.

(2) Manually scram the reactor and then trip the turbine.

D. (1) An automatic turbine trip will NOT occur.

(2) Manually trip the turbine, The reactor is NOT required to be manually scrammed.

Page 22 of 100

23. Unit Two is operating at 35% poier.

Which one of the foflowing choices completes the statements below concerning the CO-FV-49, SJAE Condensate Recirculafion Valve?

On a loss of the pneumatic suppiy to COFV49, condensate system flow will (1)

On a loss of control power to the CO-FV-49, condensate system flow will (2)

A. (1) increase (2) increase B. (1) increase (2) remain the same C. (1) remain the same (2) remain the same D. (1) remain the same (2) increase Page 23 of 100

24. Unit Two is operating at 60% poer with Reactor Feed Pump (RFP) 2A running and RFP 2B unavailable. RFP A Man.uai/DFCS selector switch is in the DFCS position.

The operator observes the foflowing:

RFP A Control Trouble alarm is received DFCS Control light for RFP A cn XU1 is out Which one of the following choices completes the statements below?

REP 2A speed will j.

The operator can control REP speed by (2)

A. (1) lower to 2550 rpm (2) operating the RFP Raise/Lower control switch on XU-1 B. (1) lowerto2550rpm (2) pacing the RFP A Speed Controller in Manual and adjusting the output demand C. (1) NOT change (2) operating the RFP Raise/Lower control switch on XU1 D. (1) NOT change (2) placing the RFP A Speed Controller in Manual and adjusting the output demand Page 24 of 100

25. Unit One drywell pressure is slc:ly rising and venting of the suppression chamber is being performed AW lOP-b, Standby Gas Treatment System Operating Procedure.

SBGT system vave status:

l-CAC-Vi72, Supp Pool Purçs Exh Vv Open l-CAC-V22, Torus Purge Exh VIv Open 1-VA-i D-BFV-RB, Reactor BLUding SBGT Train 1A Inlet Valve Closed 1-VA-i H-BFV-RB, Reactor Biiding SBGT Train I B Inlet Valve Closed Which one of the foHowing choicas completes the statements below concerning the predicted plant response if dryweH pressure reaches 1 .5 psig and reactor water level lowers to 160 inches and then stabilizes?

Both 1-CAC-V172 and i-CAC-V22 valves j.

Both i-VA-i D-BFV-RB and 1-VA-i H-BFV-RB valves (2)

A. (1) auto-close (2) remain closed B. (I) auto-close (2) auto-open C. (I) remain open (2) remain closed D. (1) remain open (2) auto-open Page 25 of iOO

26. Unit One is operating at rated power with Standby Gas Treatment (SBGT) system controls aigned as foUows:

Train A in PREF A Train B in STBY B Off-Site Power is lost.

DGI and DG2 tie to their respecfive busses.

RPV water level lowers to 115 inches and then stabilizes.

Containment parameters and radiation levels are normal.

Which one of the foowing identifies how SBGT Train A and B will respond?

A. SBGT Train A only will starL B. SBGT Train B only will start.

C. Both SBGT Train A and B wiH start.

D. Both SBGT Train A and B renain off.

Page 26 of 100

27. Unit Two is operating at rated pcwer when a 230 kV Transformer Bus Lockout occurs.

Which one of the foowing ident[ies the eiectrical bus that will remain de-energized with no operator actions?

A. 4160 Bus 2B B. 480 \/ MCC WTA C. 4160 Bus Common B D. 480 V MCC CWA-Bus A Page 27 of 100

28. Unit Two is operating at rated pcier when a Primary UPS Inverter malfunction results in an overvoltage on the inverter output.

Which one of the following choices completes the statements below?

The UPS Distribution Panel 2A (1) lAW the APPs, the required operator action is to place the UPS Distribution Panel 2A on (2)

A. (1) remains energized (2) MCC2CA B. (1) remains energized (2) the standby UPS inverter C. (1) is dc-energized (2) MCC2CA D. (1) is dc-energized (2) the standby UPS inverter Page 28 of 100

29. Which one of the following cornpetes the statements below regarding 125/250 VDC Station Distribution?

During an equalize charge, the charger output voltage to the battery will be at a (1) voltage than when in the float mode.

The 125 VDC batteries are sized to supply emergency power at a 150 amp rate for ( hours.

A. (1) lower (2) 8 B. (1) lower (2) 10 C. (1) higher (2) 8 D. (1) higher (2) 10 Page 29 of 100

30. DGI was running in Control Room Manual for the performance of OPT-I 2.2A, No. I Diesel Generator Monthly Load Test, and loaded to 2100 KW.

Subsequently off-site power was ost.

Which one of the following choices completes the statements below after the system has stabilized?

The current mode of DGI governor is in Jjj mode of operation.

DGI frequency is slightly( 60 Hz.

A. (I) droop (2) less than B. (I) droop (2) greater than C. (1) isochronous (2) less than D. (1) isochronous (2) greater than Page 30 of 100

31. A loss of offsite power occurs on Unit Two.

Unit One is at rated power.

Which one of the foHowing choices completes the statements below?

If DG3 fafled to auto-start and additional power is needed to support the EOPs the required operator action is to crosstie Jfl lAW OAOP-36.1, Loss of Any 4160V Buses or 480V E-Buses.

If a low lube oil pressure occurs on DG4, it () trip.

A. (1) EltoE3 (2) wi B. (1) E4toE3 (2) will C. (1) EltoE3 (2) will NOT D. (1) E4toE3 (2) will NOT Page 31 of 100

32. Unit One was operating at rated ower with AOG-HCV--102, AOG System Bypass Valve, control switch in AUTO.

Subsequently, several annuncrs began a!arming, including:

UA-03 4-2, Process Off-Gas Rad Hi-Hi UA-03 5-4, Process OG Vent Pipe Rad Hi-Hi UA-48 5-2, AOG System Disch Rad High UA-48 6-2, AOG Building Radiation High Which one of following annunciators is also triggered by the same radiation monitor that will prevent the AOG System Bypass Valve from being manually opened?

A. UA-03 4-2 B. UA-035-4 C. UA-485-2 D. UA-486-2 Page 32 of 100

33. Which one of the foflowing identThs the power suppy to the Main Stack Radiation Monitor?

A. Powered from Unit One UPS ONLY.

B. Powered from Unit Two UPS ONLY.

C. NormaHy powered from Unit One UPS, can be transferred to Unit Two UPS.

D. Normally powered from Unit Two UPS, can be transferred to Unit One UPS.

Page 33 of 100

34. Unit Two is operating at rated pe .ver when a large unisolable steam leak occurs in the turbine building. Annunciator TURB BLDG VENT RAD HIGH has been received.

Which one of the following choics completes the statements below?

The required action lAW RRCP is to jJJ_.

lAW 001-37.10, Rad!oactivity Reiease Control Procedure Basis Document, the basis for this action is to _j_.

A. (1) place Turbine Bldg Ventation in the recirculation line-up (2) ensure the Turbine Building envelope is maintained at a negative pressure B. (I) place Turbine Bldg Ventiation in the recirculation line-up (2) terminate a large unfiltered volume discharge flow path C. (1) start an additional Turbine Building Ventilation Exhaust Fan (2) ensure the Turbine Building envelope is maintained at a negative pressure D. (1) start an additional Turbine Building Ventilation Exhaust Fan (2) terminate a large unfiltered volume discharge flow path Page 34 of 100

35. The control room receives annunciator Rx Bldg Static Press 01ff-Low due to a microburst thunderstorm.

The operator observes that the V-Pi-1 297, Reactor Bldg Neg Pressure, on Pan& XU3 is reading 0 inches H20.

Which one of the following predicts the system response?

Reactor Building venHation:

A. supply and exhaust fans wil auto trip, SBGT system does NOT auto-start.

B. supply and exhaust fans wifl auto trip, SBGT system auto-starts.

C. exhaust fan vortex dampers will throttle open.

D. supply fan vortex dampers w! throttle closed.

Page 35 of 100

36. Unit One is at rated power.

Unit Two is at 48% power in singe recirculation loop operation.

Which one the following choices oompletes the statement below concerning the Minimum Critical Power Ratio (MCPR) safety limit for Unit One and Unit Two?

MCPR shall be greater than or eoual to jfl for Unit One.

MCPR shall be greater than or equal to for Unit Two.

A. (1) 1.11 (2) 1.12 B. (1) 1.11 (2) 1.13 C. (1) 1.12 (2) 1.12 D. (1) 1.12 (2) 1.13 Page 36 of 100

37. Unit Two is at rated power with the following pant conditions:

SJAE Train A is in full load operation CWIPs A, B, and D are in operation OW soI Valves Mode Seectcr switch is in the B position The following annunciators are ec&ved:

CW Screen A DiffHigh or Stopped CW Screen Diff He-Hi Exhaust Hood A Vacuum Low Exhaust Hood B Vacuum Lop Then CW Pump A Trip is received and CW Screen A Duff-High or Stopped annunciator clears.

The AC verifies that the screens are in fast mode of operation.

Which one of the following identes the required action(s) lAW OAOP-37.O, Low Condenser Vacuum?

A. Ensure CW Isol Vaves Mode Seector switch is in the C position.

B. Place SJAE A and B Trains in half load operation.

C. Start CWP C which is limited to two consecutive attempts.

D. Restart CWIP A which is Hmited to two consecutive attempts.

Page 37 of 100

38. Unit Two was operating at ratec Dower wher an electrical fault occurred.

The operator performed the arn immede operator actions and observes the followinQ electrical indications aer the transient:

OFF Which one of the foowing idenUfies the cause of the electrical transient?

A. UAT Lockout B. SAT Lockout C. 2B Bus Lockout D. Main Generator Lockout Page 38 of 100

39. The following conditions exist on Unit Two:

Bus E4 125 VDC control power normal supply breaker has tripped If a severe overcurrent condition subsequenUy occurs on 2B CRD pump motor windings, which one of the folovng identifies the breaker(s) that wiN trip?

(Assume no operator action taken)

A. 2-E4-AK8, CRD pump 2B breaker.

B. 2-E4-AJ9, BOP to E Bus slave breaker ONLY.

C. 2C-AC8, BOP to E Bus master breaker ONLY.

D. Both 2C-AC8, BOP to E Bus master and 2-E4-AJ9, BOP to E Bus slave breakers.

Page 39 of 100

40. Unit Two ts operating at rated pcver.

At 12:15:00 the following annurcators are received:

Stat Coolant Inlet Flow-Low Loss of Stat Coolant Trip Ckt Ener Reactor power has been lowered AW 0ENP-24.5, Reactivity Control Planning.

At 12:16:00 Main Generator arnoeres are 17814 amps.

Assuming no further operator acton, which one of the following indicates the expected plant response?

The Main Generator will trip at:

A. 12:17:00.

B. 12:18:00.

C. 12:18:30.

D. 12:19:30.

Page 40 of 100

41. Which one of the foIowing cond1ons meet the definition of Shutdown Under All Conditions Without Boron?

All rods inserted except:

A. nine rods at posiflon 02.

B. two rods which are at positior 04.

C. one rod at position 02 and one rod at position 24.

D. ten rods at position 02 and one rod at position 48.

Page4i of 100

42. Unit Two s at rated per when the following condidons are observed:

Reacrr water ev. 180 inches Stea FvVdc: 12.76 Mlbslhr Feec io incca s 12.05 Mbs/hr RFPT speed indccns are:

RFP A Speed REP B Speed 2RFBSI732 L2RFAs72 _j RFPA RFPB With conditions confinuing to degrade, which one of the following actions is required to restore and maintain normal ev& AW OAOP-23.0, Condensate/Feedwater System Failures?

A. Place the Master Feedwater Controller in MANUAL and restore normal level.

B. Place the A RFP Feedwater Controller in MANUAL and restore normal level.

C. Place the B RFP MANUAL/DFCS switch in MANUAL and restore normal level.

D. Place both RFP Feedwater Controllers in MANUAL and balance the REP speed.

Page 42 of 100

43. A LOOP has occurreS on Unit T::o with the following plant conditions:

HPCI Failed RCIC Under Clearance SLC hecting with Demin Water CRD Fow maximized lAW SEP-09 ADS Inhibited Reactor Water Level 36 inches and stable Reactor Pressure 950 psig and stable Suppression Pool Level -26 inches DryweH Pressure 2 psig and rising slowly Drywell Temperature 200°F and rising slowly (Reference Provided)

Which one of the following choices identifies the required action lAW PCCP?

A. Initiate DryweN Sprays ONLY AW SEP-02.

B. Start all available DW Coolers lAW SEP-10.

C. Perlorm Emergency Depressurization lAW RVCP.

D. Initiate Suppression Pool Sprays ONLY lAW SEP-03.

Page 43 of 100

44. Which one of the following competes the statement below lAW OAOP-32.O, Plant Shutdown From Outside Controi Room?

The reason that OAOP-32.O includes steps to open all RPS EPA breakers in the cable spreading area is:

A. to ensure that all CIS group solations occur and SBGT is running during the performance of the procedure.

B. for a situation where a manu1 scram could not be performed prior to exiting the control room.

C. to ensure RPS components era not damaged from an RPS Bus electrical perturbation.

D. for protection age nst over feeding the RPV.

Page 44 of 100

45.

On SPDS Screen 500, Radioacity Release Contro, the Off-Site Whole Body Dose Rate limit wih first be exceeded (C red Alarm condition) at which one of the following values?

A. 450 mRern / Yr B. 500mRem/Yr C. 2700 mRem/Yr D. 3000mRem/Yr Page 45 of 100

46. Unit One is perforrnirg a reactor 3tartup.

The following events occur prior o rolling the main turbine:

Bus ID experiences a fault ed trips Unit One NSW header ruptues in the Service Water Building All Unit One Service Water pumps supplying the NSW Header are manually tripped lAW OAOP-1 8.0, Nuoear Servic: Water System Failure.

The crew has completed all actics of 0AOP18.0.

Which one of the following identes the status of the Diesel Generator(s) and the cooling water supply?

A. ONLY DG1 is running with ccciing water supplied from the Unit Two NSW Pumps.

B. ONLY DGI is running with coaling water supplied from the Unit One CSW Pumps.

C. Both DGs I & 3 are running with cooling water supplied from the Unit Two NSW Pumps.

D. DGI is running with cooling ater supplied from the Unit One CSW Pumps and DG3 is running with cooling water supplied from the Unit Two NSW Pumps.

Page 46 of 100

47. Which one of the foBowing comstes both statements lAW OAOP-20.O, Pneumatic (Air/Nitrogen) System Failures?

Backup nitrogen system will automaticafly initiate when the non-interruptible air header pressure first lowers to JjJ osig.

One reason that the Backup Nitr;gen system automatically initiates is to ensure a pneumatic supply wW be maintaed to the (2)

A. (1) 105 (2) MSIVs B. (1) 105 (2) Hardened Wetwell Vent alves C. (1) 95 (2) MSIVs D. (1) 95 (2) Hardened VVetwell Vent alves.

Page 47 of 100

48. Unit Two s in Cold Shutdown ar the following conditions existed:

Loop A of SDC in service RWCU in service Subsequently all offste power is Dst.

The operators are executing OACP-15.0, Loss of Shutdown Cooling.

The El l-F009, RHR Shutdown Ooolng inbd Isol Vlv, cannot be re-opened.

Reactor water level is being maVained between 200-220 inches.

Which one of the foowing paraieters is allowed to be used for vessel coolant temperature monitoring lAW OAQP-15.0?

A. Reactor vessel pressure.

B. Vessei Bottom Drain Temperature.

C. Reactor recirculation loop temperature.

D. Bottom head metal temperatre.

Page 48 of 100

49. Which one of the focwing choices completes the statement below lAW OAOP-02.0, Control Rod Malfunction/Misposon, for a loss of CRD pumps?

If reactor pressure is Jjj ano CRD pressure cannot be restored to greater than or equal to 940 psig, immediat&y nsert a manual reactor scram upon the receipt of the J) HCU low pressure alarm.

A. (1) less than 950 psig (2) first B. (1) less than 950 psig (2) second C. (1) greater than or equal to 950 psig (2) first D. (1) greater than or equal to 950 psig (2) second Page 49 of 100

50. A core shuffle is in progress on init Two. After releasing a fuel assembly in the spent fuel poo the operator raises the main hoist to a safe elevation to pass through the transfer canal. The fNowing i9dcations on the refuel bridge are observed:

- Grapple Normal Up light NOT illuminated.

- Hoist Loaded Pght is NOT liuminated.

- Boundary Zone Bypass ligbt is illuminated.

While moving the refueling bridge to the core the refueling bridge movement abruptly stops.

Which one of the folowing identes the reason the refueling bridge motion has automatically stopped?

A. Air has been lost to the refusIng bridge.

B. Rod select power has been turned on.

C. A refuel floor ARM alarm has been received.

D. One full in (green) reed switch has failed.

Page 50 of 100

51. During an accident, Unit One pialt conditions are:

Reactor pressure 500 psig DryweN pressure 20 psig Suppression chamber pressure 19 psig Suppression poo eveI 42 inches Suppression poo temoerature 160°F (Reference provided)

Which one of the foowing is the reason emergency depressurization is required?

A. Steam exists in the suppression chamber air space, which indicates that the pressure suppression feature s being bypassed.

B. The combination of high supession chamber Ieve and pressure is threatening the design boundary loading of the torus.

C. Suppression chamber eve has lowered to the point of the downcomer etevations.

D. The suppression chambers heat capacity is being exceeded.

Page 51 of 100

52. Given the following piant conditicns with RC!O in pressure control mode:

RCIC controller output 70%

E51-F022, Bypass to CST Vv Th rott led RCIC Flow 300 gpm RCIC Discharge Pressure 1050 psg RPV pressure 810 psig, slowly lowering RClC controller Automatic set © 300 gpm Which one of the following idenftes two independent actions that will stabilize RPV pressure?

Throttle the E51-F022 in the jj direction, or by J) the RCIC Flow Controller auto setpoint.

A. (1)ocen (2) lowering B. (1)open (2) raising C. (1)closed (2) lowering D. (1) closed (2) raising Page 52 of 100

BEFORE SUPPRESSION POOL TEMP REACHES 15OF ESTABLISH CTMT COOL[NG REQUIREMENTS PER TABLE 3 REDUCING LPC INJECTION FLOW IF NECESSARY RCL-44 lAW 01-37.4, Reactc: Vessel Citro! Procedure Basis Document, which one of the following identifies why the step RCIL-44 is performed?

A. To prevent exceedng the Heat Capacity Temperature Limit.

B. To prevent exceeding primary containment design temperature.

C. To maintain NPSH to low pressure ECCS pumps.

D. To maintain cooling to HPCI and RCIC.

Page 53 of 100

54. Which one of the following ident9es a consequence of DW average air temperature reaching 341°F lAW 001-37.8, FImary Containment Control Procedure Basis Document?

A. SRVs may not operate B. Drywell High Range Monitors are no longer reliable C. Hardened Wetwel Vent Vaives may not operate D. CAC 4409 and 4410 Hydrogen Analyzers are no longer reliable Page 54 of 100

55. A LOCA has occurred concurrendy with a LOOP on Unit Two.

The following conditions exist:

DryweH Pressure 4.5 psig Reactor Water Leve 95 inches and rising with Core Spray Reactor Pressure 280 psig Suppression Chamber leve! 5.5 inches CST eve 20 feet Which one of the foHowing ident1es an injection source that must be secured tAW PCCP? (Assume no circuit afterEtions have been performed)

A. CRD B. RCIC C. HPC!

D. Core Spray Page 55 of 100

56. FollowIng a DBA LOCA on Unit Two, plant conditions are as follows:

Reactor water level 55 nches and rising Reactor pressure 150 psig Tows temperature 220°F Suppression Chamber pressue 10.5 pslg Tows level -43 Inches 2A Core Spray punp flow 5000 gpm 2B Core Spray pump flow 2000 gpm 2A RHR Loop flow 17000 gpm (Reference provided)

Which one of the following ldentl?es the ECCS pump(s) that Ware operating within the assodated NPSH lImit(s)?

A. 2B CS Pump ONLY B. 2k CS Pump and 2A RHR Loop ONLY C. 2ARHRL00pONLY D. 2B CS Pump and 2A RHR Loop ONLY Pages6of 100

57. The plant has experienced a level transient which has caused the Reactor Recirculation Pumps to trip. Level stabilized at Reactor Recirculation Pump trip setpoint.

Which one of the following choices completes the statement below?

Under these conditiois, natural rculation in the entire vessel ...jjj occurring because reactor water level is ().

A. (1) is (2) above the jet oump suction B. (1) is (2) above the steam separator return to the downcomer region C. (1) is NOT (2) below the jet iurnp suction D. (1) is NOT (2) below the steam separator return to the downcomer region Page 57 of 100

58. A primary system is cscharging ito the reactor building with the following plant conditions:

1005 Main ConcenserVac cm is 24.5 inches HG One Circ Water Pump is running MSIVs rerrain open Reactor BuHding 20 temperature is 205°F Reactor Buding 50 temperature is 165°F 1030 Reactor BuHding 2O temperature is 180°F.

Reactor Bcding 50 mperature s 165°F 1105 Engineerirg deterrnirs that the Reactor Buflding 50 has exceeded EQ envelopes.

(Reference provided)

Which one of the following is reo:uired by SCCP at 1105?

A. Perform emergency depress Ization.

B. Operate bypass vaves to coodown the reactor <100°F/hour.

C. Operate SRVs to cooldown the reactor at <100°F/hour.

D. Operate bypass valves to coodown the reactor >100°F/hour, emergency depressurization is NOT requred.

Page 58 of 100

59. An ATWS has occurrad on Unit Dne.

The following ATWS actions ha been performed:

Terminate and prevent acUors have been completed Reactor water level has been owered to 90 inches Table 3 conditions have NOT 5een met.

Reactor water evel band of 6 to 90 inches has been established Which one of the following idenPes why reactor water level was deliberately lowered to 90 inches lAW 001-37.5, Levs7Power Control Procedure Basis Document?

A. Raise feedwater subcoollng.

B. Increase the core boron concentration.

C. Reduce heat input to primary containment if the MSIVs close.

D. Minimize the possibility of larçe scale core oscillations.

Page 59 of 100

60. Which one of the foIcwing alarms is an entry condition into RRCP?

A. Service Wtr Effluent Rad High B. Area Pad RX Bldg High.

C. RBCCW Liquid Process Red High.

D. Process Reactor Building lent Rad High.

Page 60 of 100

61. Unit Two is at rated power with e pant air systems not crosstied.

The Unit Two air compressors h:ie failed causing the following plant conditions:

200 200 RB INSTR iR 4: RECE1\ER 2A In Alarm 150 PRESS L p

C:

A RB INST AiR In Alarm 00 -100 RECEIVER 26 HZ PRFSS lflW H

P pZ In Alarm U

SERViCE AIR PRESS LOW In Alarm ISTRUMUT SU8CE AIR HDER AIR KEDER PREURE PREURE

&-F442A-I Which one of the fowing identes the required operator action lAW OAOP-20.0, Pneumatic (Air/Nitrogen) System Failures?

A. Insert a manual reactor scrar.

B. Close ntrpt Air lsol Vtvs, IA-PV-722i&2 C. Open RNA-SV-5482, Div Backup N2 Rack lsol VIv.

D. Open PNS-Cross-tie Valve PNS-SV-5804A, PNS-CS-5804B Page 61 of 100

62. Which one of the foUowng choicss completes the statements below?

The Service Water to TBCCW MOVs (SW-V3 and V4) are powered from (1)

The Service Water to RBCCW MQVs (SW-\/1 03 and VI 06) are powered from (2)

A. (I) 2F12E (2) 2F12E B. (I) 2F/2E (2) E8 / E7 C. (I) E81E7 (2) 2F/2E D. (I) E81E7 (2) E81E7 Page 62 of 100

63. Unit Two is at rated power with ts feHowing alignment for RBCCW:

2A RBCCW contro swE:ch in ON 2B RBCCW contro sv :oh in ON 2C RBCCW controi sw:ch in AUTO The 2D to E3 master breaker tripped spuriously and DG3 failed to auto-start.

Which one of the foflowing ident%es the expected response of the RBCCW pumps?

A. No RBCCW pumps are runng.

B. ONLY the 2B RBCCW pump s running.

C. ONLY the 20 RBCCW pump s running.

D. 2B and 20 RBCCW pumps se running.

Page 63 of 100

64. The CRS has declared the Conto Room Envelope Boundary noperabIe.

A fire external to the control room has resulted in smoke intrusion into the control room.

The CRS has determined that ccntrol room evacuation is not necessary and has ordered the donning of Scott Air-Pak SCBAs by control room personnel.

Which one of the foflowing indicates the approximate length of time each SCBA bottle will last lAW 001-01.01, BNP Coduct of Operations Supplement?

A. 10 minutes B. One hour C. Two hours D. Four hours Page 64 of 100

65. Unit Two s operating at rated oc var when smaH oscillations due to unstable voltage regulation is observec.

Which one of the folbwing chcics completes the statements below lAW 20P-27, Generator and Exciter System Ocerating Procedure?

The first action requed is to J.

This action must be reported to e A. (1) place the generator voftae regulator in Manual (2) System Load Dispatcher B. (1) place the generator voita:e regulator in Manual (2) Plant Transmssion Activ[Jes Coordinator (PTAC)

C. (1) disable the Power System Stabilizer (PSS)

(2) System Load Dispatcher D. (1) disable the Power Syster Stabilizer (PSS)

(2) Plant Transmission Activies Coordinator (PTAC)

Page 65 of 100

66. FollowIng a seven day break in rk schedule an operator is assigned to an operating unit with the following work schedule.

Dayl 12 hours Day2 12 hours Day3 12 hours Day4 12 hours Day 5 0 hours Day6 12 hours Day7 13 hours Day8 14 hours Day 9 0 hours WhIch one & the folowing cholcas will ensure compliance lAW ADM-NGGC-0206, Managing Fatigue and Work Hour Limits, without requIring a waiver?

A. Take day I off.

B. Takeday7off.

C. Workonly 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> on day7.

D. Work only 13 hours1.50463e-4 days <br />0.00361 hours <br />2.149471e-5 weeks <br />4.9465e-6 months <br /> onday8.

Page 66 of 100

67. Which one of the foHowing identes the reason I OP-I 0, Standby Gas Treatment System Operating Procedure, prcbits venting the drywell and the suppression pool chamber simuftaneousy with the reactor at power?

This wouid cause the:

A. unnecessary cycng of torus :o dryweH vacuum breaker.

B. pressure suppression functicn to be bypassed.

C. unnecessary cycling of reactcr buUding to torus vacuum breakers.

D. SBGT Train wate; seal to blov out of the trough.

Page 67 of 100

68. Unit One s in a refueng outage and the initial loading of fuel bundles around each SRM is complete.

Which one of the foNowing competes both statements below lAW OFH-1 1, Refueling?

Fuel movement must be suspended when an SRM reading rises by a factor of (1) upon insertion of any single bunc!e OR if an SRM rises by a factor of (2) relative to the SRM baseline count rate.

A. (1) two (2) two B. (1) two (2) five C. (1) five (2) two D. (1) five (2) five Page 68 of 100

69. lAW 0A1-147, Systematic Approach to Troubleshooting, which one of the following identifies the trouble shooting acvities that must be approved by the Plant General Manager?

A. ONLY high risk activities (anvme).

B. ONLY those high risk activit.s that are performed during max/safe/gen periods of operation C. ALL medium and hgh risk activities that are performed during max/safe/gen periods of operation.

D. ALL high risk actvfties (anytime) and ONLY those medium risk activities that are performed during max/safe/gen periods of operation.

Page 69 of 100

70. Which one of the foio1ng meets the conditions required to be in MODE 4 lAW Technicci Specifications?

A. Reactor Mode Switch in eithe Shutdown or Refuel and one reactor head bolt has been fufly tensioned.

B. Reactor Mode Switch in eithe Shutdown or Refue and all reactor head bolts have been fully tensioned.

C. Reactor Mode Switch in Shutcwn and one reactor head bolt has been fully tensioned.

D. Reactor Mode Swtch in Shutdown and all reactor head bolts have been fully tensioned.

Page 70 of 100

71. Unit Two is operating at rated power, Drywe eakage calculations are being performed lAW the CD DSR.

The 0800 drywefl leakage calc 3ons were:

Floor Drain Leakage .3 gpm Equipment Drain eakage 3.5 gpm These leakage values have bear constant for several days.

At 1200 the differencs n integra r readings s:

Floor Drain 816 gallons Equipment Drain 960 gallons Which one of the foowing choices completes the statement below?

The calculated unideitified leakage is (1) which J within the limits of Technical Specifications LCD 3,L,4, RCS Operational Leakage.

A. (1) 3.4 gpm (2) is B. (1) 3.4gpm (2) is NOT C. (1) 4.0 gpm (2) is D. (1) 4.0 gpm (2) is NOT Page 71 of 100

72. Drywell p-assure is psig Suppression Pool LseI is 4 fee:

Which ore of the foowing cornpetes the statement below?

lAW PCCP, when venting the primary containment, the (1) UNLESS (2)

A. (1) suppression pDol is reqd to be vented first (2) alternate source term acons cannot be performed B. (1) sUppression pDci is requed to be vented first (2) PCPL-A is reached C. (1) offsite release rates must be maintained beow the ODCM release rate limit (2) alternate source term actons cannot be performed D. (1) offsite release rates must be maintained below the ODCM release rate limit (2) POPLA is reached Page 72 of 100

73. Access is required to a Unit One ant area for inspection.

Radiation levels in the area are 00 Mrem/hr at 30 cm and 510 Rads/hr at one meter from the radiation source.

Which one of the foVcwing choic.s completes the statements below lAW OE&RC-0040, Administrative Cotrois for High Radiation Areas, Locked High Radiation Areas, ard Very Hig adiatior reas?

This area is required to be postec as a Jj.

The MiNlMUM approvals requirec to enter this area are the E&RC manager (or designee), Rad Protection Supelsor, and .

A. (1) \fery High Radiation Area (2) Plant Generai Manager B. (1) Very :igh Radiation Area (2) Shift Manage; C. (1) Locked High Radiation Area (2) Plant Genera Manager D. (1) Locked High Radiation Aea (2) Shift Manager Page 73 of 100

74.

Which one of the foHowing ident1es the EOP flowchart symbol above lAW OEOP-O1-UG, EOP Users Guide?

A. Action Step B. Caution Step C. Critical Step D. Decision Step Page 74 of 100

75. Which one of the foBowing choic2s completes the statements below lAW OFPP-031, Fire Brigade Staffing oster an quiprnent Requirements?

The Fire Brigade Advisor positio (II The Fire Brigade Athisor *_j_ be diverted from supporting the Fire Brigade during OASSD-02 implementation.

A. (1) mustbefilledbyanSRO (2) can B. (1) can be filled by an RO (2) can C. (1) must be fiHed by an SRO (2) can NOT D. (1) can be filled by an RO (2) can NOT Page 75 of 100

76. Unit Two s at rated power with RHR Pump 2D under clearance/inoperable for three days.

OPT-07.2.A, Core Spray System Operability Thst Loop A comprehensive pump test is in o rogress.

he AC reports that stopped suction pressure reading was 4.5 psig.

1ST personnel have obtained the following ibration data with the pump operating as shown on the left:

ISH 0.356in1s peak 0.486 in/s peak 1W H 0.658 in/s peak l2 The AO reports the running suction pressure reading s 2.5 psig and that the lubricant levels are normaL (Reference provided)

PUMP 2A PUMP 2A DISCH DISCH Based on the performance of OPT-07.2.4A, which PRESS FLOW one of the foflowing identifies the most limiting 1T9DOA 1flR6ThA required action lAW Technical Specifications?

A. Return a low pressure injectb: system to OPERABLE in 4 days.

B. Place the unit in Mode 3 in 1 hours1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.

C. Return a low pressure injecticn system to OPERABLE in 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br />.

D. Return Core Spray system to OPERABLE in 7 days.

Page 76 of 100

77. Unit Two !s operating at 38% power performing a control rod pattern adjustment l&C has kfentified that the intem-adlate and Low Trip setpoints for RBM A and RBM B are inoperable.

The High Trip Setpo! it for both 3Ms Is operable.

MCPR Is currently 1.48.

(Reference provided)

Which one of the foliowing is the minimum Technical Specification action, if any, Is required, lAW LCO 3.3.2.1 Coifll Rod Block InstrumentatIon?

A. ConditIon A ONLY B. Condition B ONLV C. Condition A and Condition B D. NO required action Page77of 100

78. Unft Two Is perlormlrg a reactor startup, pdor to the point of adding heat.

IRM E is bypassed due to falling downscaie.

IRMA Upscale/mop aami is rec!ved due to the high voltage power supply falling ;ow to IRM A.

(Reference provided)

WhIch one of the folowlng choc ss completes the statements below?

The IRM power suppy faflure w cause a (11 Addressing only TRMS 3.3, Contoi Rod Block instnimentatlon, (21 A (1) rod biock ONLY (2) restore a requIred channel to operable status in 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> B. (1) rod block 0N..Y (2) NO required compensatoy measures, traddng ONLY C. (1) rod block and 112 scram (2) restore a required channe to operable status in 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> D. (1) rod block and 1/2 scram (2) NO required compensato-y measures, tracldng ONLY Page 78 of 100

79. Which one of the foowing choics completes the statements below?

The impact of a loss ower cy breaker to ADS on 125V DC Panel 4B is that (1 The procedural step or resettin: this indMduai power supply breaker to ADS on 125VDC Panel 4B is contained r j)_.

A. (1) ADS will initia:e if requirac from the logic ONLY (2) OAOP-39.O, Loss of DC Fower B. (1) ADS will initiate if require from the bgic ONLY (2) 2APP-A-03, 2-2, Auto Dc cress Control Pwr Failure fl3?

C. (1) ADS will initiate if required: from the logic ONLY (2) OAOP-39.O, Loss of DC Fower D. (1) ADS will initiate if requirec from the logic ONLY (2) 2APP-A-03, 2-2, Auto Dc cress Control Pwr Failure Page 79 of 100

80. Unit Two was operating at rateo ower when a loss of UPS Distribution Panel 2A occurs. Subsequenti a LOCA ccurs. The following plant conditions exist:

Reactor pressure 195 sig Torus eressure 10 pD Torus water level 4 inches Drywe temperat;Es 3iC Drywall Sprays NO svaHabie The CR5 has determined that e ergency deoressurization is required.

Which one of the following choices completes the statements beiow?

Terminating and preenting injeoon jj required.

If all ADS valves fail :o manually open, the crew s required to open the remaining SRVs A. (1) is (2) ONLY B. (1) is not (2) ONLY C. (1) is (2) and perform ADP D. (1) is not (2) and perform AEDP Page 80 of 100

81. During accident concons on li Two frie response of SBGT is indicated below:

Which one of the foVowing choices completes the statements below?

The SBGT 2A Fan auto :p if the preffiter compartment reaches 210°F.

For a condition where a fire has occurred in a SBGT Train the procedure steps for manually opening the solation vves to the deluge valves, to allow water to flow inside the SBGT Train, are ocated in A. (1) will (2) 20P-i0, Standby Gas Treatment System Operating Procedure B. (1) wiN (2) OOP-41, Fire Protection aid Well Water System C. (1) will NOT (2) 20P-i0, Standby Gas Treatment System Operating Procedure D. (1) wiil NOT (2) OOP-41, Fire Protection aid Well Water System Page 81 of 100

82. Both Units are both 3erating a ted power.

At 1730 on 12/15, 230V Batt A Q7arger Trouble and 250V Batt A Undeivoltage annunciators are received on Ur Two.

l&C reports that Batts:y Charger 2A-1 has a burned diode ring. No spare parts are available and it will take 5 days to make the needed repairs.

At 1600 on 12/18, &Sng perforence of SR 3.8.6.1 on the Unit One batteries, the following float voltage data was scorded:

Batter; lA-i Pilot CeN 2,10 V Battery IA-2 PHot CaN 2.34 V Battery lB-i Pilo: Ccli 2.05 V Battery IB-2 Pilot CeN 2.33 V (Reference provided)

Which one o the foNowing comp etes both of the statements below?

(1) 250V DC Battery Subsystems are inoperable lAW Technica! Specificahon 3.8.4.

The earliest time that both Units nust be in Mode 3 is by 12/19 at (2) hours.

A. (1) Only two (2) 0L00 B. (1) Oilytwo (2) 0500 C. (1) Three (2) 0400 D. (1) Three (2) 0500 Page 82 of 100

83. During peforrnance OPT09.2 HPCI System Operability Test, a HPCI steam line leak occurs. SBGT Train IA is coerating. The following conditions exist:

Process OG Vent P/ce Red Ii In alarm Process Rx Bldg lent Red i-i- In aiarm Stack radiation Ic es Rising Based on the conditions listed above, which one of the following choices completes the statements below?

SBGT iF Fan auto-star:ed.

The required action AVV RRCP to enter A. (1) has (2) the RSP B. (I) has (2) OGP-05 C. (1) has not (2) the RSP D. (1) has not (2) OGP-05 Page 83 of 100

84. Unit One s operating et rated pc er with HPCI suction ahgned to the Torus for CST Level sw!tch replacement. The £cUowing annunciator is received:

RCIC LOGIC BUS 3 PWR F/ LURE (Reference provided)

Which ons of the foowng choics competes the following statements?

There has been a loss of power o 125V DC Distribution Panel (1) lAW Technical Speccations LCD 3.5.3, ROIC System, the required action is to jj.

A. (1) 3B (2) be in Mode 3 within 12 hcdrs B. (1) 43 (2) be in Mode 3 within 12 hjrs C. (1) 3B (2) restore RCIC o operable within 4 days D. (1) 4B (2) restore RCIC o operabs within 14 days Page 84 of 100

85. While peorming PT 2.2, HPC EPABiLLY TEST, the HPCI steam supply ilne ruptured. HPCI fae to automoaIy isolate. Subsequently HPCI was manually isolated The foHowinc Steam eak Deec:on NUMAC channels are in alarm:

B21-XY-5949A, Cenel A3 reading 303°F B21-XY-5949B, Ciannel A3-3, reading 298°F B21-YY-5948A, Ciannel A5- reading 301°F B21-XY--5948B, Channel AS- reading 296°F No other channels n alarm.

Which one of the foowng cho!cs completes the statements below?

(Reference providec The req-ed actions W SOCE are to _jI.

The highest required EAL casscation for this event is _jj_.

A. (1) Scram the reactor and erergency depressurize (2) a Site Area Emergency B. (1) commence a cooldown a: normal rates (2) a Site Area Emergency C. (1) Scram the reactor and energency depressurize (2) an Alert D. (1) commence a cooldown a normal rates (2) an Alert Page 85 of 100

86. The curreit plant cc- :flons cn :- One are:

DryweH pressure psig, slowly rising Suporession Poc cessure 4 osig, slowly rising Drywel temperature 165°F, slowly rising Suppression Pooi level -28 inches, stable Which ore o the folciing chocs completes the statement below?

The CR5 is required Y concurre fly perform iI_.

The CRS wili direct 2)

A. (1) RYCP and POOP ONLY (2) SEP-02, Dryveil Spray cedure B. (1) RSP,RVCP,dPCCP (2) SEP-03, Suporession Pc .1 Spray Procedure C. (1) RSP, RVCP, and PCCP (2) SEP-02, Drywell Spray Procedure D. (1) RVCP and POOP ONLY (2) SEP-03, Suporession Pcr! Spray Procedure Page 86 of 100

87. Unit Two s cDeratirç at rated pcier when a PNS leak occurs.

Drywell pneumatics e been tnsarred to RNA lAW OAOP-20.O, Pneumatic (Air/N itropen) Systerr aHures.

Primary containmen axygen cer entration remains less than 4 volume percent.

(Reference provided Which ore o the fo ing choices competes the statements below lAW OAOP-20.O?

RNA is sippiying pniatics tc jjj.

An action statement 1echnic Specifications LCO 3.6.3.1, Primary Containment Oxygen Concentration, (2) o be entered.

A. (1) Suppression Pooi to Dry:;eii and Reactor Buflding to Torus Vacuum Breakers (2) is required B. (1) Suppression oo to Dry eH and Reactor Building to Torus Vacuum Breakers (2) is NOT required C. (1) Reactor BuiIdng to Torus Vacuum Breakers ONLY (2) is required D. (1) Reactor Buiidng to Torus Vacuum Breakers ONLY (2) is NOT required Page 87 of 100

88. A reactor scram on t.*t One ha occurred, The CRS has directed a Reactor pressure band of 800 1000 pg for the oowing dent conditions:

One SRV man uafly opened Reactor pressue 825 psig and lowering Control Rod postion All unknown Suop. Pool waer temp. 160°F Supp. Pool water level -2 feet 8 inches (Reference Provideó Which ore of the foowing choices completes the statements below?

The procadue required for pressJre contro s (1)

The pressure band tat the CR as directed acceptable.

A. (1) RVCP (2) is B. (1) LFC (2) is C. (1) RVCP (2) is NOT D. (1) LPC (2) is NOT Page 88 of 100

89. Followinç a Reactor crarn on L Two due to a loss of off-site power, the following plant conrHUcns exist:

Area Rad RXBIdç: High Ln alarm South RI-JR RM Frod Level in alarm South CS RM FIOQd Level H. n alarm Reactrr Building Z0 Rad Lev Rising Reaccr Building ZY Tempe: ure 125°F and rising Reactcr Water La Ci 150 inches Drywe Pressure 2.2 psig The CRS is evaluating the follow9g step:

MO SYSTEM DISCHARGiNG INTO TH REACTOR :

17 Which one ot the fo ring choi. competes the statements below?

The CR5 is required to answer sap SCCP-i 7 as _jj.

The CRS wifl direct the restart o PB HVAC lAW (2)

A. (1) YES (2) SEP-04, Reactor BuildinZ H\/AC Restart Procedure B. (1) NO (2) SEP-04, Resotor Buildir HVAC Restart Procedure C. (1) YES (2) OP-37.1, Reactor BuildirZ Heating and Ventilation System Operating Pocedure D. (1) NO (2) QD37j, Reactor BuildirZ Heating and Ventilation System Operating Procedure Page 89 of 100

90. Unit Two s operatinc at rated PC er when a complete !oss of UPS occurs.

The CRS has directec the RO tc nsert a manual reactor scram due to rising drywell pressure. Plant ccrThns are:

Manual Scram pushbuttons Depressed Mode Sw[ch Shutdown position RPS Lights NOT lit ARI Initiated Drywel pressure 2.1 psig APRM Downscale ghts NOT lit Scram Valve P11 Hdr Pm-s *11/o In alarm (Reference provided)

Which ore of the foowing choir s completes the statements below based on these current conditions?

The crew must use ), of L-02, Alternate Control Rod Insertion.

The highest requirec EAL classicafion is a(n) (2)

A. (1) Section 3, Reset RPS ar; Initiate a Manual Scram (2) Alert B. (1) Section 3, Reset RPS an Initiate a Manual Scram (2) Site Area Emergency C. (1) Section 4, SCRAM indiviciai rods with the scram test switches (2) Alert D. (1) Section 4, SCRAM indivjal rods with the scram test switches (2) Site Area Emergency Page 90 of 100

91. Unit Two s operatinc at rated oc er when a LOCA and a LOOP occur.

The following condits exist:

Reactor water iCVC 00 inches rising Drywe Pressure 2 psig Suppresson Poo Dressure 9 psig Suppression Poo Level 8 inches DG3 rpped on differential overcurrent DG4 R:sniinc ioaded ERFIS vaiabie lAW PCC, for thess conditiorvhich one of the following choices completes the statements below?

Primary containment hydrogen/c gen concentration must be determined by ...Jfl._.

When ve9ting of prirary containment has been established the CRS will direct the purging of the lAW SEPD5, Primary Containment Purging.

A. (1) p!aoing CAC. T-4410 ir ervce (2) Drywell or &Dpression C amber B. (1) pcing CAC--\T-4410 service (2) Drywell ONL C. (1) E&RC sample ONLY, CAC-AT-4410 cannot be used (2) Drywell or Suopression Chamber D. (1) E&RC sarnpe ONLY, CACAT-4410 cannot be used (2) Drywall ONLY Page 91 of 100

92. Surveillance testing of fire protecion components on Unit Two have yielded the following resu[ts:

North RHR room sprinker syc em inoperable South HR room sorinkler s em 0cc-able

-17 RHR Pump eeas Snoke detectors 1-4, 1-9, 3-6, and 3-9 are Ipele Fire Barriers Afl operable (Reference provided Which one of the foowing choices identifies the minimum required fire watches lAW OPLP-1 .2, Fire Protection Systen Operability, Action, and Surveillance Requirements?

A. Estabsh an hou fire watc n North RHR ONLY.

B. Estabsh a contiruous firewesh in North RHR and an houiiy firewatch in S0Lifi RHR.

C. Estab!ish a continous fire vetch in both North and South RHR.

D. Estabsh an houry fire watch n both North and South RHR.

Page 92 of 100

93. Unit Two s operstinc st rated c ar with 2A RHR Pump under clearance.

The Load Dispatcher notifies the control room conditions exist where adequate voltage support can NOT be crovided b he grid in the event of a LOCA.

(Reference provided Which one of the foowing choices compietes the statement below lAW Technical Specificeon 3.8.1, íO Sources Operating?

Enter LCO 3.8.1 reqred actions for Condition(s) (1)

The 2B Loop of RHR (2) recjired to be declared INOPERABLE.

A. (1) EONLY (2) is B. (1) CandE (2) s NOT C. (1) CandE (2) is D. (1) EONLY (2) is NOT Page 93 of 100

94. Which o;e of the foLng chocs completes the statements below when moving spent fuel w[thin the spent fuel pool (no core a[terations) lAW FH-1 IA, RefueHng Platform Qperations?

A dedicated individue to fulfiH the Spotter function w[th NO other concurrent duties i) required.

A dedicated Control Room Reacor Operator (2) required.

A. (1) s (2) s B. (I) s (2) s NOT C. (I) sNOT (2) s D. (I) sNOT (2) s NOT Page 94 of 100

95. Unit Two is operatinp at rated pc icr with Core Spray Pump 2A under clearance for pump rejoecement. ie North Room Cooler was subsequently determined to be i noperab e.

Which one of the foLJng cho.:.s completes the statements below lAW WCP-NCOC-0300, Work Request ln[tiation, Screening, Prioritization, and Classification?

The highest requirec vork order riority for the North RHR Room Cooler repair is (1)

Given this priority, actual work o the North RHR Room Cooler can (2)

A. (1) Pority1 (2) ONLY begin after work o:5er olanning B. (1) Prority2 (2) ONLY begin after work oier planning C. (1) Pri.ohtyl (2) begin immediately in paralel with work order planning D. (1) Priority 2 (2) begin immedately in pars id with work order planning Page 95 of 100

96. Which ore of the foicwing choic-s completes the statements below?

(Conside: each state ient seper:sy.)

lAW Tech Spec 5.2.2, Facility Sti, the shift crew composition may be less than the minimum equirement of 10 OFF. 50.54(m)(2)O) and Specifications 5.2.2.a and 5.2.2.g for a period of time rot to exceeb jJ for an unexpected absence of onduty shift crew rne:ibers.

lAW OPSNGGC-1 COO, Fleet Co9duct of Operations, the minimum required number of auxiliary operators for manning s shift at BNP is J).

A. (1) one hour (2) three B. (1) one hour (2) nine C. (1) two hours (2) three D. (1) two hours (2) nne Page 96 of 100

97.

Unit Two is shutdown following accident conditions with the given Drywell Monitor ndcations.

(Reference provided)

Which one of the following identifies whether any fission product barriers are lost or are potentially lost lAW OPEP-02.1, Brunswick Nucear Plant Initial Emergency Action Level Matrix?

A. None of the barriers are lost.

B. Lost Fue Clad Berder ONLY, C. Lost Fuel Clad and RCS Ba ers ONLY.

D. Lost Fuel Clad and RCS Bar ers, Containment Barrier potentially lost.

Page 97 of 100

98. The BSE Radioact Liquid Rease Permit is being approved with the following step fifled out cn te parr:

B. CONFIRM the following instrumentation is OPERABLE:

1. Liquid Radwaste Radioactivity Monitor, 2-D12-RM-K604 RO

2. Liquid Radwaste Effluent flow Measurement Device, nop 2-G 1 8-fiT-N 057 Which ore o the foL g chc : a compiees the statements below?

The rniniun requL approva commence any liquid release is(are) (I)

The Radioactive Liq. Release j_.

A. (1) U-itCRSON:i (2) can still occu QDCM cc9pensatory actions are implemented B. (1) Ut CRS ON (2) is NOT aliowz unless 2- 316-FIT-N057 is operable C. (1) Unit CRS anc Shift Manc :er (2) can still cccv f QDCM c npensatory actions are implemented D. (1) Unit CRS anc Shift Manaer (2) is NOT allow unless 2- 16-FlLNO57 is operable Page 98 of 100

99. Which or o the fo .ng is re :ird lAW Technical Specifications and Bases for 3.3.3.1, Post Accde: Monitcrr Instrumentation?

A. Drywel Hgh Rar e RadiatV Monitors Recorders (D22-R--1 95/4 7) are required for channel operability.

B. Drywe Hgh Rare adiadr Monitors Recorders (D22-T-41 95!4 7) are NOT required for channel operability.

C. Reactor Building :ea Red M nitors Annunciator UA-t 2-7, Ares ad Rx Bldg High, is required for channel operability.

D. Reactor Building rea Red nitors Annunciator UA-C 2-7, Area ad Rx Bldg High, is NOT required for channel opera bHity.

Page 99 of 100

100. A Generc Energer nas been sc!ared. Onsite Emergency Response facilities are being stefec!, bu err NOT ye :vaed.

Weather conditions Temoeraure 92°F Uppewind spee 9.8 r Lowe: whd see 73 Upper wino direc:crr 31 8N Lowe wind di:ecNn 314.

(Reference providec Which or o the fo cwing chok. s completes the statements below lAW OPEP-023.28, Ofs ThotecfrJc cton Recommendations?

Zone L jj reqcsd to be r ommended for evacuation.

The ( is respcsibte for nking this PAR.

A. (1) isNC (2) Se Emergeroy Coordincror B. (1) is NOT (2) Emergency Pesponse Mnager C. (1) is (2) Ste Ernergercy Coordn or D. (1) is (2) Emergency Pesponse if lager Page 100 of 100

SRO Written Exam Reference Index

1. OEOP-01-UG, Users Guide, Attachment 5, Figure 1, Drywell Spray Initiation Limit

2. OEOP-01-UG, Users Guide, Attachment 5, Figure 3, Heat Capacity Temperature Limit

3. 0EOP-01UG, Users Guide, Attachment 5, Figure 5, Core Spray NPSH Limit

4. OEOP-0l-UG, Users Guide, Attachment 5, Figure 6, RHR NPSH Limit

5. OEOP-01-UG, Users Guide, Attachment 5, Figure 7, Pressure Suppression Pressure

6. OEOP-01-UG, Users Guide, Attachment 10, Figure 22, Secondary Containment Area Temperature

7. OPT-07.2.4a, Core Spray System Operability Test Loop A

8. OPEP-02.l, Brunswick Nuclear Plant Initial Emergency Actions

9. 0PEP-02.6.28, Attachment 1, PAR Flowchart

10. OPEP-02.6.28, Attachment 2, Page 1 of 2, Evacuation Zones/Time Estimates/I 0 Mile EPZ Map II. TS 3.3.2.1, Control Rod Block Instrumentation

12. TS 3.5.1, ECCS - Operating

13. TS 3.5.3, RCIC System

14. TS 3.6.3.1, Primary Containment Oxygen Concentration

15. TS 3.8.1, AC Sources Operating

16. TS 3.8.4, DC SourcesOperating 17, TS 3.8.6, Battery Cell Parameters

18. TRM 3.3, Control Rod Block Instrumentation

19. COLR Table 1, RBM System Setpoints

20. COLR Table 2, RBM Operability Requirements

21. OPLP-0l .2, Fire Protection System Operability, Action, and Surveillance Requirements

ATTACHMENT 5 Page 16 of 28 FIGURE 1 Drywell Spray Initiation Limit 450

--I- -- -

LL. 400

---I-UNSAFE 0

-- +- I w I 350 I I

300 I 250 SAFE 200 150 100 50 5 15 25 35 45 55 65 75 0 10 20 30 40 50 60 70 DRYWELL PRESSURE (PSIG)

DRYWELL AVERAGE AIR TEMPERATURE MAY BE DETERMINED USING ATTACHMENT 4.

OEOP-01-UG Rev. 60 Page 75 of 151

0 m

0

-o cb SUPPRESSION POOL WATER TEMPERATURE (°F)

G) - - - - - - - - * %3 t%3 r%)

o

• F3 C) . 01 0) 4 0) CD 0 -

o 0 0 0 0 C 0 0 0 0 0 0 0 0

0 0

F.., C,)

rn C mci) CD 0 I I->

C) rn-n C)

-1 I111 H 0 C -I -o 0

-u--f 01 0 [ 1111t11f I QCD C)

CD 0 4 4 4. 4-++ I0 m a) 0 CnC O) mz 0 Cl) 0

-4 I-Cl) CD C) Z C,) 0 m>

C 0 o:,

0-n 01 0) 0 -Im m C CD 0 w Cl)

C mm II II I I I I I I 01 .. WM-0

-U 01

1) 0 F..) r.301F..)F..3 0 01 0100101 CD i -n-n-n-n

-I - -I-I-I-I 0

0

C m SUPPRESSION POOL WATER TEMPERATURE (°F) 0 I3 I 0* O)

C - - - - -

- > 2 0 C 01 O - O CD 0 - 1) C) . 01 0 -4 O I 0 m w 0 0 0 0 0 0 0 0 0 0 0 0 0 0 C 1-0) H C) :u C>

r >J0 0 0 <mO

i: m>5 0

>1-0 0 flm 0

U -

_0_ O CD

,, U-I 0) rn Cl) 0) Cfl <Crzj C H m ;o o C m 0 umom

- Cl)c,,z 0> -< I -I fl , I 0 0 mo I 3 u rnmu Qo I d1-ffl

- 1-0 rJ oz 0

> _0 01 43 o 0 0 0 0)>

C 0)

Ci) Ci)

-OW

° Co 0

-4,

- z 0 e

ATTACHMENT 5 Page 22 of 28 FIGURE 6 RHR NPSH Limit LL 290 0

w 280 -

270

• 40 PSIG 260 250 240

• 20 PSIG 230 220 10 PSIG 210 200 EEE EEH 190 180 z I 170

• OPSIG II 160 0 5,000 10,000 15,000 20,000 RHR PUMP FLOW (GPM)

SUBTRACT 0.5 PSIG FROM INDICATED SUPPRESSION CHAMBER PRESSURE FOR EACH FOOT OF WATER LEVEL BELOW A SUPPRESSION POOL WATER LEVEL OF -31 INCHES (-2.6 FEET).

• 5UPPRESSION CHAMBER PRESSURE (CAC-PI-1257-2A OR CAC-PI-1 257-2B)

OEOP-01-UG Rev. 60 Page 81 of 151

C m

0

-p C

SUPPRESSION POOL LEVEL (FT) 0 i i t .4 +

4 0) 01 . Is.) 0 C,)

Ce -- -- - -- -

- -U m

(I) (I,

- -Cl)- -

Cr, -- - - -

- *.I 0

.J fl CD Z -m- cn u 4.1 -- - - - -- -- -- - --

CD C )]

Q cnmgm 03 - - - - - - - - - - -

m - - - -- -- - -- - - -

- 01

- CD

-D - -

C - -- - -

0 Z

m - - - - - -- - - - - -

Cflc m

m FT

- In CD - - - - -

CC) 0 CD U,

[3 C

01

ATTACHMENT 10 Page2of5 Secondary Containment Temperature and Radiation Limits FIGURE 22 Secondary Containment Area Temperature TABLE 1 AREA TEMPERATURE LIMITS PLANT PLANT STEAM LEAK INSTRUMENT MAX NORM MAX SAFE AUTO AREA LOCATION DETECTION NUMBER! OPERATING OPERATING GROUP DESCRIPTION CHANNEL! WINDOW VALUE (°F) VALUE (°F) ISOL LOCATION (NOTE 1)

N CORE N CORE PANEL XU-3 VA-TI-1603 120 175 N!A SPRAY SPRAY ROOM S CORE S CORE PANEL XU-3 VA-TI-1604 120 175 N/A SPRAY SPRAY ROOM RWCU PUMP B21-XY-5949A G31-TE-NO16A ROOM A B21-XY-5949B G31-TE-NO16B CH. Al-i RWCU PUMP B21-XY-5949A G3i-TE-N0160 RWCU 140 225 3 ROOM B B2l-XY-5949B G3i-TE-NO16D OH. A2-i RWCU HX B21-XY-5949A G31-TE-NO16E ROOM B21-XY-5949B G31-TE-NO16F OH. A3-i N RHR B2i-XY-5948A El l-TE-NOO9A N RHR EQUIP ROOM OH. A5-4 175 295 N/A PANEL XU-3 VA-TI-1601 S RHR B21-XY-5948B Eil-TE-NOO9B EQUIP ROOM OH. A5-4 175 295 N/A PANEL XU-3 VA-TI-I 602 S RHR ROIC EQUIP B2i-XY-5949A E51-TE-N023A ROOM B21-XY-5949B E51-TE-N023B 165 295 5 OH. Ai-3 HPCI HPCI EQUIP B21-XY-5948A E41-TE-NO3OA ROOM B2I-XY-5948B E41-TE-NO3OB 165 4 OH. Al-I NOTE 1: MAX NORM OPERATING VALUE IS THE ANNUNCIATOR/GROUP ISOLATION SETPOINT WHERE APPLICABLE OEOP-01-UG Rev. 60 Page 140 of 151

ATTACHMENT 10 Page3of5 Secondary Containment Temperature and Radiation Limits FIGURE 22 Secondary Containment Area Temperature (Cont)

TABLE I AREA TEMPERATURE LIMITS PLANT PLANT STEAM LEAK INSTRUMENT MAX NORM MAX SAFE AUTO AREA LOCATION DETECTION NUMBER? OPERATING OPERATING GROUP DESCRIPTION CHANNEL? WINDOW VALUE (°F) VALUE (°F) ISOL LOCATION (NOTE 1)

RCIC STM B2 1 -XY-5949A E5 1 -TE-N025A TUNNEL B21-XY-5949B E51-TE-N025B 190 295 5 STEAM CH. A3-3 TUNNEL HPCI STM B21-XY-5948A E51-TE-N025C TUNNEL B21-XY-5948B E51-TE-N025D 190 295 4 CH. A5-1 20 FT NORTH B21-XY-5948A B21-TE-5761A CH. A1-4 20 FT 20 FT SOUTH B21-XY-5948B B21-TE-5763B 140 200 N/A OH. A1-4 50 FT 50 FT NW B21-XY-5948A B21-TE-5762A OH. A2-4 140 200 N/A 50 FT SE B21-XY-5948B B21-TE-5764B OH. A2-4 REACTOR MULTIPLE ANNUNCIATOR WINDOW ALARM N/A 3,4, BLDG AREAS PANEL A-02 5-7 SETPOINT AND/OR 5

REACTOR MSIV ANNUNCIATOR WINDOW ALARM N/A I BLDG PIT PANEL A-06 6-7 SETPOINT NOTE 1: MAX NORM OPERATING VALUE IS THE ANNUNCIATORJGROUP ISOLATION SETPOINT WHERE APPLICABLE OEOP-01-UG Rev. 60 Page 141 of 151

ATTACHMENT 2 Page 2 of 2 Unit 2 Core Spray Pump A Test Information Data Sheet

1. The lubricant level (pump running) is normal:

2. Calculate pump dP as follows:

Pump discharge pressure - suction pressure (run) = pump dP NOTE: Pump vibration measurement is required only during CPT. Vibration is measured at the test point marked on the pump for the correct bearing number and direction as indicated by the Test Position number as follows:

- the number indicates the bearing number from Attachment 5

- for position, N=North, S=South, E=East, W=West

- for direction, A=Axial, H=Horizontal, V=Vertical NOTE: Reference values for pump suction and discharge pressures are provided for determining the suitability of alternate test gauges, if used.

NOTE: Pump stopped suction pressure should normally be between 4 and 8 psig. This parameter is a function of torus pressure and suppression pool water level. Values outside of this range may also be indicative of air in the instrument line.

NOTE: Should quarterly pump test data exceed the CPT limits, the pump remains operable and the test results will be evaluated as part of the BNP 1ST trending program.

UNIT 2 CORE SPRAY PUMP A TEST DATA ALERT RANGE REQUIRED ACTION ACTUAL REFERENCE ACCEPTANCE RANGE TEST PARAMETER VALUE VALUE VALUE RANGE LOW HIGH LOW HIGH Suction Press.

(Stopped) psig 6.0 N/A N/A N/A N/A N/A Suction Press.

(Running) psig 4.0 N/A N/A N/A N/A N/A Discharge Press.

Psig 290.0 N/A N/A N/A N/A N/A Quarterly Pump DP psid 288.0 260.0 to 316.8 N/A N/A < 260.0 > 316.8 260.0 CPT Pump DP psid 288.0 267.8 to 296.6 to N/A < 260.0 > 296.6

<267.8 Flow Rate gpm 4,700 N/A N/A N/A N/A N/A Vibration-vel (in/s > 0.325 peak) Position iS H 0.230 0 to 0.325 N/A to N/A > 0.700 0.700 Vibration-vel (in/s > 0.325 peak) Position 1W A 0.212 0 to 0.325 N/A to N/A > 0.700 0.700 Vibration-vel (in/s > 0.325 peak) Position 1W H 0.156 0 to 0.325 N/A to N/A > 0.700 0.700 Performed By (Signature): Date: Time:

Reviewed, 1ST Group (Signature): Date:

OPT-07.2.4a Rev. 73 Page 34 of 42

110C I L__L_lCICIuIC lotri hid Irlulu Ii r__r___r__o_i_ ouIrr_tt hr 11 r

1 _

,u,,r I I Ii ,llIrt 0

, 2 dCCCoCCCC_,.<4 2

R Li ICiCle I lotFi UpuCeed 2

Hr LIClCl crn:rlnrcriJ line Feulrrullihit]

3 04-.

l cEDzrrrr T 9 7

I 3 2 8 rnnmT1 I1 rn L CI izj ran, ZCFF-1 run H F 3 l,lICI DE Table F-I FIssion Pioduct Barrier datrint Fuel Clad Saroor Reactor Coolant Systom Barrier Containment Barrier Loon Potential Loon Loon Potontial Loon j Loon Potontiol Loon InlnICIuIelndCl 1EottJ EitjDJLIltfl Ln I C I C C,0C 33 ,me,eo r

4d.Ccemer CrrOoOO,C3mCn,rne3eeC36O333CC.

iz:.: aoceC lnIeInI.ntCol 5 I IllnldlCIlb!tJ Inlet CI:Ie hOOCh IIIClelCICIOHtI 6

Notes Modes: LII LII LII OnmuoOC I ProujrcsnEootyy EAL-1 MODES 1, 2 & 3

/:&r, :Zt(J11Tk , jJFç (9,tJ$:tifdIz1I:

II4I3I4!4I1FJ 14 I flfl I I 141414441_ I I I 141 I I

I

• rrr rrnm4 R 2 2

TI rrLjEC ccDajrn <T il 3

rTrrrr DIII ozzmzrftni EiOECC I

• I I.J r lzzn.rnmzLII I

H 7Z 2

H 3

LZCZEEJEEIEZrEZ I I I I I I I El I I T501 1T1 I II flp &IAl1,,1dI1I11144 Notes 5

11111311 Fr13331 14111114 I413tfl II2I1II 13131 6

E 1311 Modes: [11 EL EL EL EL EAL-2 MODES 4, 5 & DefueOed

ATTACHMENT I Page 1 Of I PAR Flowchart al YES Are there impediments Shelter affected areas to eva cu ati on? or populations NO Evacuate Zones A, B, and 10 miles Downwind per Att 2. Shelter Zones per Att 2. (See Notes 1, 2, & 3)

.1 Continue assessment based on all available plant and field monitoring information. (See Notes 3 & 4)

Modify protective action recommendations as necessary (See Note 4)

NOTES:

1. Shelter remaining zones to have population 4. A protective action recommendation should not be indoors to monitor EAS broadcasts. reduced from the initial recommendation for any

2. Shelter may be the appropriate action for zone until the release is terminated, and the controlled releases of radioactive material from decision is coordinated with the state and counties.

containment if there is assurance that the The following guides should be considered prior to release is short term (puff release) and the area reducing a protective action recommendation:

near the plant cannot be evacuated before the a. Long term weather forecast conditions are plume arrives. obtained with a high degree of confidence in

3. For actual or projected doses> I Rem TEDE or the forecast. No sea-breeze in effect.

> 5 Rem CEDE (Thyroid), declare a General b. Radiological environmental conditions are Emergency and recommend evacuation of the defined.

general population from the affected areas. c. Plant conditions are stabilized.

Recommend use of KI if projected or actual d. Population dose savings are quantifiable as a dose is ? 5 Rem CEDE (Thyroid). result of the protective action recommendation change, and the decision is ALARA.

OPEP-02.6.28 Rev. 11 Page 10 of 15

ATTACHMENT 2 Page 1 of 2 Evacuation ZoneslTime EstimatesllO Mile EPZ Map MAXIMUM SHELTER EVACUATION WIND FROM EVACUATE ZONES TIMES (hours)

ZONES SUMMER WINTER 1800 - 195° A,B,G,H,J,K C,D,E,F,L,M,N 7:40 4:00 196°-236° A,B,H,J,K,L C,D,E,F,G,M,N 9:50 4:00 237°-271° A,B,J,K,L,M C,D,E,F,G,H,N 9:50 4:00 272° 288°

- A,B,J,L,M C,D,EF,G,H,KN 8:05 4:00 289° 316°

- A,B,L,M,N C,D,E,F,G,H,J,K 8:05 3:50 317°-327° A,B,M,N C,D,E,F,G,H,J,K,L 4:10 3:50 328° 009°

- A,B,C,M,N D,E,F,G,H,J,K,L 5:00 3:50 01000210 A,B,C,D,M,N E,F,G,H,J,K,L 8:30 5:20 022° 038°

- A,B,C,D,E,M,N F,G,H,J,K,L 9:35 6:00 039° 051°

- A,B,C,D,E F,G,H,J,K,L,M,N 9:35 6:00 052° 090°

- A.B,C,D,E,F G,H,J,K,L,M,N 9:35 6:10 091° 112°

- A,B,D,E,F C,G,H,J,K,L,M,N 9:35 6:00 113° 179°

- A,B,EF,G,H,J C,D,K,L,M,N 6:55 4:45 ALL ZONES IN A,B,C,D,E,F,G,H,J,K,L,M,N 9:50 6:10 10 MiLE_EPZ If projected or actual dose is> 5 Rem CDE (thyroid), recommend use of KI.

OPEP-02.6.28 Rev. 11 Page 11 of 15

Control Rod Block Instrumentation 3.3.2.1 3.3 INSTRUMENTATION 3.3.2.1 Control Rod Block Instrumentation LCO 3.3.2.1 The control rod block instrumentation for each Function in Table 3.3.2.1-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3.2.1-1 ACTIONS CONDTlON REQUIRED ACTION COMPLETION TIME A. One rod block monitor A.1 Restore RBM channel to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> (RBM) channel inoperable. OPERABLE status.

B. Required Action and B.1 Place one RBM channel in 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> associated Completion Time trip.

of Condition A not met.

OR Two RBM channels inoperable.

C. Rod worth minimizer (RWM) C.1 Suspend control rod Immediately inoperable during reactor movement except by startup. scram.

OR (continued)

Brunswick Unit 2 3.3-18 Amendment No. 243 I

Control Rod Block Instrumentation 3.3.2.1 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME C. (continued) C.2.1 .1 Verify 12 rods withdrawn. Immediately OR C.2.1.2 Verify by administrative Immediately methods that startup with RWM inoperable, for reasons other than bypassed control rod(s),

has not been performed in the last calendar year.

AND C.2.2 Verify movement of During control rod bypassed control rod(s) is movement in compliance with banked position withdrawal sequence (BPWS) by a second licensed operator or other qualified member of the technical staff.

D. RWM inoperable during D.1 Verify movement of During control rod reactor shutdown. bypassed control rod(s) is movement in accordance with BPWS by a second licensed operator or other qualified member of the technical staff.

(continued)

Brunswick Unit 2 3.3-19 Amendment No. 243

Control Rod Block Instrumentation 3.3.2.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME E. One or more Reactor Mode E.1 Suspend control rod Immediately SwitchShutdown Position withdrawal.

channels inoperable.

AND E.2 Initiate action to fully insert Immediately all insertable control rods in core cells containing one or more fuel assemblies.

Brunswick Unit 2 3.3-20 Amendment No. 243 I

Control Rod Block Instrumentation 3.3.2.1 Table 3.3.2.1-1 (page 1 of 1)

Control Rod Block Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED SURVEILLANCE ALLOWABLE FUNCTION CONDITIONS CHANNELS REQUIREMENTS VALUE Rod Block Monitor

a. Low Power RangeUpscale (a) 2 SR 3.3.2.1.1 (h)

SR 3.3.2.1.4 SR 3.3.2.1.7

b. Intermediate Power RangeUpscale (b) 2 SR 3.3.2.1.1 (h)

SR 3.3.2.1.4 SR 3.3.2.1.7

c. High Power RangeUpscale (c),(d) 2 SR 3.3.2.1.1 (h)

SR 3.3.2.1.4 SR 3.3.2.1.7

d. tnop (d),(e) 2 SR 3.3.2.1.1 NA

e. Downscale (d).(e) 2 SR 3.3.2.1.1 NA SR 3.3.2.1.7

2. Rod Worth Minimizer 1 SR 3.3.2.1.2 NA SR 3.3.2.1.3 SR 3.3.2.1.5 SR 3.3.2.1.8

3. Reactor Mode SwitchShutdown Position (g) 2 SR 3.3.2,1.6 NA (a) THERMAL POWER is 29% RTP and MCPR less than the limit specified in the COLR except not required to be OPERABLE if the Intermediate Power Range-Upscale Function or High Power RangeUpscale Function is OPERABLE.

(b) THERMAL POWER is Intermediate Power Range Setpoint specified in the COLR and MCPR less than the limit specified in the COLR except not required to be OPERABLE if the High Power Range-Upscale Function is OPERABLE.

(c) THERMAL POWER High Power Range Setpoint specified in the COLR and <90% RTP and MCPR less than the limit specified in the COLR.

(d) THERMAL POWER 80% RTP and MCPR less than the limit specified in the COLR.

(e) THERMAL POWER 29% and <90% RTP and MCPR less than the limit specified in the COLR.

(f) With THERMAL POWER 8.75% RTP.

(g) Reactor mode switch in the shutdown pouition.

(h) Allowable Value specified in the COLR.

Brunswick Unit 2 3.3-23 Amendment No. 247

ECCSOperating 3.5.1 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 3.5.1 ECCSOperating LCO 3.5.1 Each ECCS injection/spray subsystem and the Automatic Depressurization System (ADS) function of six safety/relief valves shall be OPERABLE.

APPLICABILITY: MODE 1, MODES 2 and 3, except high pressure coolant injection (HPCI) and ADS valves are not required to be OPERABLE with reactor steam dome pressure 150 psig.

ACTIONS LCO 3.0.4.b is not applicable to HPCI.

CONDITION REQUIRED ACTION COMPLETION TIME A. One low pressure ECCS A.1 Restore low pressure 7 days injection/spray subsystem ECCS injection/spray inoperable, subsystem to OPERABLE status.

OR One low pressure coolant injection (LPCI) pump in each subsystem inoperable.

B. One LPCI pump inoperable. B.1 Restore LPCI pump to 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> OPERABLE status.

AND OR One core spray (CS) subsystem inoperable. B.2 Restore CS subsystem to 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> OPERABLE status.

(continued)

Brunswick Unit 2 3.5-1 Amendment No. 260 I

ECCSOperating 3.5.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. Required Action and C.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time of Condition A or B not met. NQ C.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> D. HPCI System inoperable. D.1 Verify by administrative Immediately means RCIC System is OPERABLE.

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

E. HPCI System inoperable. E.1 Restore HPCI System to 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> OPERABLE status.

AND OR One low pressure ECCS injection/spray subsystem is E.2 Restore low pressure 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> inoperable. ECCS injection/spray subsystem to OPERABLE status.

F. One required ADS valve F.1 Restore required ADS valve 14 days inoperable, to OPERABLE status.

(continued)

Brunswick Unit 2 3.5-2 Amendment No. 233

ECCSOperating 3.5.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME G. One required ADS valve G.l Restore required ADS valve 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> inoperable, to OPERABLE status.

_Q One low pressure ECCS G.2 Restore low pressure 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> injection/spray subsystem ECCS injection/spray inoperable, subsystem to OPERABLE status.

H. One required ADS valve H.1 Restore required ADS valve 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> inoperable, to OPERABLE status.

HPCI System inoperable. H.2 Restore HPCI System to 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> OPERABLE status.

Required Action and 1.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time of Condition D, E, F, G, or H N.Q not met.

1.2 Reduce reactor steam 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> OR dome pressure to 150 psig.

Two or more required ADS valves inoperable.

(continued)

Brunswick Unit 2 3.5-3 Amendment No. 233

ECCSOperati ng 3.5.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME J. Two or more low pressure J.1 Enter LCO 3.0.3. Immediately ECCS injection/spray subsystems inoperable for reasons other than Condition A or B.

OR HPCI System and two or more required ADS valves inoperable.

Brunswick Unit 2 3.5-4 Amendment No. 233

RCIC System 3.5.3 3.5 EMERGENCY CORE COOLING SYSTEMS (ECCS) AND REACTOR CORE ISOLATION COOLING (RCIC) SYSTEM 3.5.3 RCIC System LCO 3.5.3 The RCIC System shall be OPERABLE.

APPLICABILITY: MODE 1, MODES 2 and 3 with reactor steam dome pressure> 150 psig.

ACTIONS NOTE LCO 3.0.4.b is not applicable to RCIC.

CONDITION REQUIRED ACTION COMPLETION TIME A. RCIC System inoperable. A.1 Verify by administrative Immediately means High Pressure Coolant Injection System is OPERABLE.

AND A.2 Restore RCIC System to 14 days OPERABLE status.

B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time not met.

B.2 Reduce reactor steam 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> dome pressure to 150 psig.

Brunswick Unit 2 3.5-12 Amendment No. 260 I

Primary Containment Oxygen Concentration 3.6.3.1 3.6 CONTAINMENT SYSTEMS 3.6.3.1 Primary Containment Oxygen Concentration LCO 3.6.3.1 The primary containment oxygen concentration shall be <4.0 volume percent.

APPLICABILITY: MODE I during the time period:

a. From 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> after THERMAL POWER is> 15% RTP following startup, to

b. 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> prior to a scheduled reduction of THERMAL POWER to

<15% RTP.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Primary containment oxygen A.1 Restore oxygen 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> concentration not within concentration to within limit.

limit.

B. Required Action and B.1 Reduce THERMAL 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> associated Completion Time POWER to 15% RTP.

not met.

Brunswick Unit 2 3.6-26 Amendment No. 233

AC SourcesOperating 3.8.1 3.8 ELECTRICAL POWER SYSTEMS 3.8.1 AC SourcesOperating LCO 3.8.1 The following AC electrical power sources shall be OPERABLE:

a. Two Unit 2 qualified circuits between the offsite transmission network and the onsite Class I E AC Electrical Power Distribution System;

b. Four diesel generators (DG5); and

c. Two Unit 1 qualified circuits between the offsite transmission network and the onsite Class IE AC Electrical Power Distribution System.

APPLICABILITY: MODES 1,2, and 3.

ACTIONS NOTE LCO 3.O.4.b is not applicable to DGs.

CONDITION REQUIRED ACTION COMPLETION TIME A. NOTE A.1 Restore Unit 1 offsite circuit 45 days Only applicable when Unit I to OPERABLE status.

is in MODE 4 or 5.

One Unit I offsite circuit inoperable.

(continued)

Brunswick Unit 2 3.8-1 Amendment No. 260

AC SourcesOperating 3.8.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. NOTES B.1 Declare required feature(s) Immediately from

1. Only applicable when with no power available discovery of Unit I is in MODE 4 inoperable when the Condition B or 5. redundant required concurrent with feature(s) are inoperable. inoperability of

2. Condition B shall not be redundant required entered in conjunction feature(s) with Condition A.

Two Unit 1 offsite circuits inoperable due to one Unit 1 balance of plant circuit path to the downstream 4.16 kV emergency bus inoperable for planned maintenance.

AND Ni2 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> DC associated with the affected downstream B.2 Perform SR 3.8.1.1 for AND 4.16 kV emergency bus OPERABLE offsite inoperable for planned circuit(s). Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> maintenance, thereafter AND B.3 Restore both Unit I offsite 7 days circuits and DC to OPERABLE status. AND 10 days from discovery of failure to meet LCO 3.8.1 .a orb (continued)

Brunswick Unit 2 3.8-2 Amendment No. 235

AC SourcesOperating 3.8.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME C. One offsite circuit inoperable C.1 Perform SR 3.8.1.1 for 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> for reasons other than OPERABLE offsite Condition A or B. circuit(s). N.Q Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> thereafter AND C.2 Declare required feature(s) 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> from with no offsite power discovery of no available inoperable when offsite power to one the redundant required 4.16 kV emergency feature(s) are inoperable, bus concurrent with inoperability of redundant required feature(s)

AND C.3 Restore offsite circuit to 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> OPERABLE status.

AND 10 days from discovery of failure to meet LCO 3.8.1.a orb (continued)

Brunswick Unit 2 3.8-3 Amendment No. 235

AC SourcesOperating 3.8.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME D. One DG inoperable for D.1 Perform SR 3.8.1.1 for 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> reasons other than OPERABLE offsite Condition B. circuit(s).

Once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> thereafter AND D.2 Declare required feature(s), 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> from supported by the inoperable discovery of DG, inoperable when the Condition D redundant required concurrent with feature(s) are inoperable. inoperability of redundant required feature(s)

AND D.3.1 Determine OPERABLE 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> DG(s) are not inoperable due to common cause failure.

OR D.3.2 Perform SR 3.8.1.2 for 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> OPERABLE DG(s).

AND D.4 Restore DG to OPERABLE 7 days status.

AND 10 days from discovery of failure to meet LCO 3.8.1 .a or b (continued)

Brunswick Unit 2 3.8-4 Amendment No. 235

AC SourcesOperating 3.8.1 ACTIONS (continued)

CONDITION REQUTRED ACTION COMPLETION TIME E. Two or more offsite circuits E.1 Declare required feature(s) 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> from inoperable for reasons other inoperable when the discovery of than Condition B. redundant required Condition E feature(s) are inoperable, concurrent with inoperability of redundant required feature(s)

AND E.2 Restore all but one offsite 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> circuit to OPERABLE status.

F. One offsite circuit inoperable NOTE for reasons other than Enter applicable Conditions and Condition B. Required Actions of LCO 3.8.7, Distribution SystemsOperating, AND when Condition F is entered with no AC power source to any 4.16 kV One DG inoperable for emergency bus.

reasons other than Condition B.

F.1 Restore offsite circuit to 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> OPERABLE status.

OR F.2 Restore DG to OPERABLE 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> status.

G. Two or more DGs G.1 Restore all but one DG to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> inoperable. OPERABLE status.

(continued)

Brunswick Unit 2 3.8-5 Amendment No. 235 I

AC SourcesOperating 3.8.1 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME H. Required Action and H.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time of Condition A, B, C, D, E, F &LQ or G not met.

H.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> One or more offsite circuits 1.1 Enter LCO 3.0.3. Immediately and two or more DGs inoperable.

OR Two or more offsite circuits and one DG inoperable for reasons other than Condition B.

Brunswick Unit 2 3.8-6 Amendment No. 235 I

DC SourcesOperating 3.8.4 3.8 ELECTRICAL POWER SYSTEMS 3.8.4 DC SourcesOperating LCO 3.8.4 The following DC electrical power subsystems shall be OPERABLE:

a. Unit 2 Division I and Division II DC electrical power subsystems; and

b. Unit I Division I and Division II DC electrical power subsystems.

APPLICABILITY: MODES 1,2, and 3.

ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. One DC electrical power A.1 NOTE subsystem inoperable. Enter applicable Conditions and Required Actions of LCO 3.8.7, Distribution SystemsOperating, when Condition A results in de-energization of an AC electrical power distribution subsystem or a DC electrical power distribution subsystem.

Restore DC electrical 7 days power subsystem to OPERABLE status.

(continued)

Brunswick Unit 2 3.8-23 Amendment No. 235

DC SourcesOperating 3.8.4 ACTIONS (continued)

CONDITION REQUIRED ACTION COMPLETION TIME B. Required Action and B.1 Be in MODE 3. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion Time of Condition A not met.

OR B.2 Be in MODE 4. 36 hours4.166667e-4 days <br />0.01 hours <br />5.952381e-5 weeks <br />1.3698e-5 months <br /> Two or more DC electrical power subsystems inoperable.

Brunswick Unit 2 3.8-24 Amendment No. 235 I

Battery Cell Parameters 3.8.6 3.8 ELECTRICAL POWER SYSTEMS 3.8.6 Battery Cell Parameters LCO 3.8.6 Battery cell parameters for the Unit 2 Division I and II batteries and the Unit I Division I and II batteries shall be within the limits of Table 3.8.6-1.

AND Battery cell average electrolyte temperature for the Unit 2 Division I and II batteries and the Unit I Division I and II batteries shall be within required limits.

APPLICABILITY: When associated DC electrical power subsystems are required to be OPERABLE.

ACTIONS Separate Condition entry is allowed for each battery.

CONDITION REQUIRED ACTION COMPLETION TIME A. One or more batteries with A.1 Verify pilot cells electrolyte 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> one or more battery cell level and float voltage meet parameters not within Table 3.8.6-1 Category C Category A or B limits, limits.

AND A.2 Verify battery cell 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> parameters meet

. Table 3.8.6-1 Category C N.Q limits.

Once per 7 days thereafter AND (continued)

Brunswick Unit 2 3.8-30 Amendment No. 235 I

Battery Cell Parameters 3.8.6 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. (continued) A.3 Restore battery cell 31 days parameters to Category A and B limits of Table 3.8.6-1.

B. Required Action and B.1 Declare associated battery Immediately associated Completion Time inoperable.

of Condition A not met.

OR One or more batteries with average electrolyte temperature of the representative cells not within limits.

OR One or more batteries with one or more battery cell parameters not within Category C limits.

Brunswick Unit 2 3.8-31 Amendment No. 235 I

Battery Cell Parameters 3.8.6 Table 3.8.6-1 (page 1 of 1)

Battery Cell Parameter Requirements CATEGORY A: CATEGORY B: CATEGORY C:

LIMITS FOR EACH LIMITS FOR EACH LIMITS FOR EACH DESIGNATED PILOT CONNECTED CELL CONNECTED PARAMETER CELL CELL Electrolyte Level > Minimum level indication > Minimum level Above top of plates, mark, and 1/4 inch above indication mark, and and not overflowing maximum level indication  % inch above mark maximum level indication mark Float Voltage 2.13 V 2.13 V 2.07 V Specific Gravity 1 .200 1 .195 Not more than 0.020 below iNJ2 average of all connected cells Average of all connected cells AND 1.205 Average of all connected cells 1.195 (a) It is acceptable for the electrolyte level to temporarily increase above the specified maximum level during and following equalizing charges provided it is not overflowing.

(b) Corrected for electrolyte temperature and level. However, level correction is not required when on float charge and battery charging current is < 2 amps.

(c) A battery charging current of < 2 amps when on float charge is acceptable for meeting specific gravity limits following a battery recharge, for a maximum of 7 days. When charging current is used to satisfy specific gravity requirements, specific gravity of each connected cell shall be measured prior to expiration of the 7 day allowance.

Brunswick Unit 2 3.8-33 Amendment No. 235

Control Rod Block Instrumentation 3.3 3.3 CONTROL ROD BLOCK INSTRUMENTATION TRMS 3.3 The control rod block instrumentation for each Function in Table 3.3-1 shall be OPERABLE.

APPLICABILITY: According to Table 3.3-1 COMPENSATORY MEASURES NOTE Separate Condition entry is allowed for each channel.

REQUIRED COMPENSATORY COMPLETION CONDITION MEASURE TIME A. NOTE A.1 Restore channel(s) to 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> Only applicable for OPERABLE status.

Functions 1,2 and 3.

One or more functions with one or more required channels inoperable.

B. One or more functions with B.1 Place one channel in trip. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> control rod block capability not maintained.

OR Required Compensatory Measures and associated Completion Time of Condition A not met.

Brunswick Unit 2 3.3-1 Revision No. 23 I

Control Rod Block Instrumentation 3.3 Table 3.3-1 (page 1 of 1)

Control Rod Block Instrumentation APPLICABLE MODES OR OTHER SPECIFIED REQUIRED TEST ALLOWABLE FUNCTION CONDITIONS CHANNELS REQUIREMENTS VALUE

1. Average Power Range Monitors

a. Upscale (Flow Biased> 1 3 TR 3.3.3 TR 3.3.4 TR 3.3.5

b. Inoperative 1,2 3 TR 3.3.5

c. Downscale 1 3 TR 3.3.5

d. Upscale (Fixed) 2 3 TR 3.3.3 TR 3.3.5

2. Source Range Monitors (bl 2

5

a. Detector Not Full In 2 TR 3.3.1

b. Upscale 2(l,5 2 TR 3.3.1

c. Inoperative 2,5 2 TR 3.3.1

d. Downscale 2,5 2 TR 3.3.1

3. Intermediate Range Monitors

a. Detector Not Full In 2,5 6 TR 3.3.1

b. Upscale 2,5 6 TR 3.3.1

c. Inoperable 2,5 6 TR 3.3.1

d. Downscale 2,5 6 TR 3.3.1

4. Scram Discharge Volume Water LevelHigh 1,2,5 TN 3.3.2 TR 3.3.3 (a) (0.55(W LuW) + 55.0% RTP] when Technical Specification 3.3.1.1, Function 2.b, is reset for single loop operation per LCO 3.4.1, Recirculation Loops Operating. The value of w is defined in plant procedures.

(b( Bypassed when detector is reading> 100 cps or Intermediate Range Monitor (IRM) channels are on Range 3 or higher.

(c) Bypassed when associated IRM channels are on Range 6 or higher.

(d) Deleted.

(e) Bypassed when IRM channels are on Range 1.

(f) With any control rod withdrawn from a core cell containing one or more fuel assemblies. Not applicable to control rods removed per Technical Specification 3.10.5, Single Control Rod Drive (CRD) RemovalRefueling, or 3.10.6, Multiple Control Rod WithdrawalRefueling.

(g) Signal is contained in Channel A logic only.

Brunswick Unit 2 3.3-4 Revision No. 36

Progress Energy Nuclear Fuels Mgmt. and Safety Analysis Design Caic. No. 2B21-0640 B2C20 Core Operating Limits Report Page 16, Revision 0 Table I RBM System Setpoints 1 a, d Trip Setpoint Setpoint Allowable Value Lower Power Setpoint (LPSPb) 27.7 S 29.0 Intermediate Power Setpoint (IPSPb) 62.7 . 64.0 High Power Setpoint (HPSPb) 82.7 < 84.0 Low Trip Setpoint (LTSPC) 114.1 114.6 Intermediate Trip Setpoint (ITSPC) 108.3 108.8 High Trip Setpoint (HTSPC) < 104.5 105.0 RBM Time Delay (td2) 2.0 seconds 2.0 seconds a See Table 2 for RBM Operability Requirements.

b Setpoints in percent of Rated Thermal Power.

c Setpoints relative to a full scale reading of 125. For example, < 114.1 means

< 114.1/125.0 of full scale.

d. Trip setpoints and allowable values are based on a high power analytical setpoint of 108% (unfiltered).

1 This table is referred to by Technical Specification 3.3.2.1 (Table 3.3.2.1-1) and 5.6.5.a.5.

Progress Energy Nuclear Fuels Mgmt. and Safety Analysis Design CaIc. No. 2B21-0640 B2C20 Core Operating Limits Report Page 17, Revision 0 Table 2 RBM Operability Requirements 2

IF the following conditions are met, THEN RBM Not Required Operable Thermal Power

(% rated) MCPR 1.83 TLO 29%and<90%

1.86 SLO 90% 1.47 TLO 2

Requirements valid for all fuel designs, all SCRAM insertion times and all core average exposure ranges.

R Progress Energy BRUNSWICK NUCLEAR PLANT Reference Use PLANT OPERATING MANUAL VOLUME XXII PLANT PROGRAM PROCEDURE UNIT 0

OPLP-O1.2 FIRE PROTECTION SYSTEM OPERABILITY, ACTION, AND SURVEILLANCE REQUIREMENTS REVISION 39 OPLP-O1 .2 Rev. 39 Page 1 of 50

TABLE OF CONTENTS SECTION PAGE 1.0 PURPOSE 3

2.0 REFERENCES

3 3.0 RESPONSIBILITIES 4 4.0 DEFINITIONS 4 5.0 GENERAL 5 6.0 IMPLEMENTATION 7 6.1 Fire Suppression Water System 7 6.2 Spray and/or Sprinkler Systems 12 6.3 High Pressure 002 Systems 14 6.4 Fire Hose Stations 15 6.5 Foam Systems 16 6.6 Fire Barrier Penetrations 19 6.7 Diesel Generator Building Basement Halon 21 6.8 Fire Detection Instrumentation 22 6.9 Public Address Page System 25 6.10 Fire Protection Coatings, Raceway Barriers, and Special Barriers 26 6.11 Fire Brigade 27 ATTACHMENTS 1 Required Water Spray/Sprinkler Systems 28 2 Required High Pressure CO 2 Systems 30 3 Required Fire Hose Stations 31 4 Required Fire Detection Instruments 34 5 Required Foam System Fire Detection Instruments 42 6 Sprinkler System I Isolation Valve Cross Reference 43 OPLP-01 .2 Rev. 39 Page 2 of 50

1.0 PURPOSE The purpose of this procedure is to outline the operability, action, and surveillance requirements for fire protection systems required for safe shutdown in the event of a fire, It also addresses the surveillance requirements for these systems which fall under the requirements of the Nuclear Electric Insurance Limited (NEIL) Loss Prevention Program.

R15 This procedure is required to implement license renewal commitments and supports the License Renewal Aging Management Program.

2.0 REFERENCES

2.1 FSAR (updated), Section 9.5.1 2.2 OFPP-020, Impairment Notification 2.3 OAP-033, Fire Protection Program Manual 2.4 OFPP-005, Fire Watch Program 2.5 OFPP-030, Backup and Alternate Fire Suppression 2.6 OPLP-01.1, Fire Protection Commitment Document 2.7 OFPP-031, Fire Brigade Staffing Roster 2.8 001-01.01, BNP Conduct of Operations Supplement 2.9 001-01.02, Operation Unit Organization and Operating Practices 2.10 ESR 97-00375, Fire Detection Testing Frequency 2.11 ESR 94-00109, CO 2 Piping in the Control Room 2.12 ESR 99-00328, Penetration Seal Statistical Sampling Program 2.13 Nuclear Electric Insurance Limited (NEIL) Loss Control Manual 2.14 ESR 00-00180, Decommission Refuel Floor Fire Detection R151 2.15 BSEP 04-0006, Letter from BSEP to US Nuclear Regulatory Commission, dated October 18, 2004, Application for Renewal of Operating License R161 2.16 BNP-LR-611, License Renewal Aging Management Program Description of the Fire Water System Program (AR 100627, Al-29)

R171 2.17 BNP-LR-612, License Renewal Aging Management Program Description of the Fire Protection Program (AR 100627, Al-30) 2.18 OPS-NGGC-1 000, Fleet Conduct of Operations 2.19 F-03897, Fire Detection System Block Diagram OPLP-01 .2 Rev. 39 Page 3 of 50

3.0 RESPONSIBILITIES 3.1 The Manager BESS, through the Fire Protection Program Manager shall be responsible for the promulgation and maintenance of this procedure.

3.2 The Shift Manager or his designee shall be responsible for the administration of this procedure.

4.0 DEFINITIONS 4.1 OperablelOperability A system, subsystem, train, component, or device shall be OPERABLE or have OPERABILITY when it is capable of performing its specified function(s). Implicit in this definition shall be the assumption that all necessary attendant instrumentation, controls, normal or emergency electric power sources, cooling and seal water, lubrication, and other auxiliary equipment that are required for the system, subsystem, train, component, or device to perform its function(s) are also capable of performing their related support function(s).

4.2 Action Actions are those additional requirements specified as corollary statements to each specification and shall be part of the specifications.

4.3 Channel Functional Test A Channel Functional Test shall be:

4.3.1 Analog channels the injection of a simulated signal into the channel as close to the primary sensor as practicable to verify OPERABILITY including alarm and/or trip functions.

4.3.2 Bistable channels the injection of a simulated signal into the channel sensor to verify OPERABILITY including alarm and/or trip functions.

OPLP-O1 .2 Rev. 39 Page 4 of 50

5.0 GENERAL 5.1 The operability of the fire protection systems ensures that adequate fire protection capability is available to confine and extinguish fires occurring in any portion of the facility where safety-related/safe-shutdown equipment is located. The fire protection system consists of the water supply system, water suppression systems (sprinklers and standpipes), 002 systems, foam systems and halon systems, fire coatings, and fire barriers.

5.2 In the event a system or portions of a system become inoperable, applicable ACTION requirements shall be implemented and continue until the inoperable equipment is restored to operability.

5.3 In the event an inoperable system is returned to operable status prior to expiration of the specified time interval, completion of the ACTION statement is not required.

5.4 Surveillances do not have to be performed on inoperable equipment.

5.5 In the event an inoperable system cannot be returned to service within the time constraints contained in this procedure (7, 14, or 30 days, as applicable), a report will be prepared and submitted to the Plant General Manager within the next 30 days outlining the action taken, the cause of the inoperability, and the plans and schedule for restoring the system to operable status. Additionally a Nuclear Condition Report (NCR) will be issued to determine the failure mode for not returning the system to service within the time required.

5.5.1 If a condition report has already been generated for the equipment failure, an Action Request, Type IMPR (Improvement Request) is sufficient to notify the Plant General Manager and determining the failure mode for not returning the equipment to service within the time required.

5.5.2 The Plant General Manager shall be the approval authority for all action items related for returning the equipment to service. This applies to both completion and due date extensions.

OPLP-01 .2 Rev. 39 Page 5 of 50

5.0 GENERAL 5.6 Operability of any system may be interrupted to allow for scheduled periodic testing without implementation of compensatory action provided the inoperable system is not left unattended during the test and the system is returned to OPERABLE status within the appropriate time limit (7, 14, or 30 days, as applicable). The Unit CRS shall document the interrupted operability of the system in accordance with 001-01 .01. In the event the periodic test will exceed the time allowed inoperable, an impairment and the required compensatory actions shall be initiated to allow performance of the test.

NOTE: The following includes support functions such as electric power, halon system boundaries (e.g. ERFIS computer door, simulator room doors) etc.

5.7 For a fire protection system which is not covered by the requirements in Section 6.1 through 6.11 which is not OPERABLE (i.e. not able to fulfill its fire protection function), establish a tracking impairment in accordance with 001-0 1 .01. For a fire protection system or component which has the automatic fire detection reporting function and/or automatic fire suppression function not operable, establish a periodic fire watch of one round per shift.

Ensure NEIL notification requirements are reviewed in accordance with 001-01.01 and OFPP-020.

5.8 For surveillance requirements for systems not covered by this procedure, refer to the NEIL Loss Control Manual (accessible through the Progress Energy lntranet.)

5.9 Surveillance results for systems which are tracked under a performance based system will be tracked by the System Engineer. Failure rates greater than the established acceptance criteria will require a shortening of the test interval.

5.10 Fire detection and suppression systems that are monitored by the Edwards EST3 Fire Detection System (Fireworks Software) are identified on Drawing F-03897, Fire Detection System Block Diagram.

OPLP-01 .2 Rev. 39 Page 6 of 50

6.0 IMPLEMENTATION 6.1 Fire Suppression Water System 6.1.1 Operability The fire suppression water system shall be OPERABLE at all times with:

1. Two OPERABLE fire pumps, one Electric and one Diesel, each with a flow rate of at least 2000 gpm, at a pump discharge head of greater than or equal to 125 psig with their discharges aligned to the fire suppression yard main;

2. The fire protection water tank, with a minimum contained volume of 232,500 gallons (corresponding to a level of 24 9 1/2), and the demineralized water tank, with a minimum contained volume of 90,000 gallons (corresponding to a level of 14 0); and

3. An OPERABLE flow path capable of taking suction from each of the water supplies and transferring the water through the yard main and distribution piping with OPERABLE ring header sectionalizing control or isolation valves up to, but not including, the yard hydrant curb valves and the first valve ahead of each sprinkler and hose standpipe system required to be OPERABLE.

6.1.2 Actions

1. With one pump and/or water supply inoperable, restore the inoperable equipment to OPERABLE status within 7 days.

2. With the isolation capability of one ring header sectionalizing control or isolation valve inoperable, demonstrate that the affected portion of piping can be isolated by cycling adjacent ring header valve(s) through one complete cycle of full travel within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

OPLP-01 .2 Rev. 39 Page 7 of 50

6.1.2 Actions

3. With the isolation capability of two or more ring header sectionalizing control or isolation valves inoperable:

a. Demonstrate that the affected portion of piping can be isolated by cycling OPERABLE adjacent ring header valve(s) through one complete cycle of full travel within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, and

b. Restore the inoperable valves to OPERABLE status within 7 days.

4. With two or more ring header sectionalizing control or isolation valves closed, declare any isolated sprinkler and/or hose standpipe system(s) inoperable.

5. With the fire suppression water system otherwise inoperable:

a. Establish a backup fire suppression water system within 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />, or

b. Be in at least HOT SHUTDOWN within the next 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> and in COLD SHUTDOWN within the following 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br />.

R16 6.1.3 Surveillance R17 The fire suppression water system shall be demonstrated OPERABLE:

a. At least once per 7 days by verifying the contained water supply volume is at least the minimum specified.

b. At least once per 31 days by starting each pump and operating it for at least the time specified below:

1. 15 minutes for the Electric Fire Pump,

2. 20 minutes for the Diesel Fire Pump.

c. At least once per 92 days by verifying that each valve (manual, power-operated, or automatic) in the flow path is in its correct position.

OPLP-01 .2 Rev. 39 Page 8 of 50

6.1.3 Surveillance

d. At least once per 12 months by cycling each testable valve in the flow path through at least one complete cycle of full travel.

e. At least once per 18 months by performing a system functional test which includes simulated automatic actuation of the system throughout its operating sequence, and:

1. Verifying that each pump develops at least 2000 gpm at a pump discharge head of greater than or equal to 125 psig;

2. Cycling each valve in the flow path that is not testable during plant operation through at least one complete cycle of full travel; and

3. Verifying that each fire pump starts sequentially to maintain the fire suppression water system pressure greater than or equal to 125 psig.

f. At least once per 3 years by performing a flow test of the system in accordance with Chapter 5, Section 11 of the Fire Protection Handbook, 14th edition, published by the National Fire Protection Association.

g. To ensure operability of the Fire Water System during the period of extended operation and based on Regulatory Commitments associated with License Renewal, non-intrusive baseline pipe thickness measurements shall be taken at various locations, prior to the expiration of the current license and trended through the period of extended operation.

Engineering evaluation of the inspection results shall be used to establish the inspection intervals. Results of the inspections of the above grade fire protection piping shall be extrapolated to evaluate the condition of below grade fire protection piping.

The activity is the responsibility of the Fire Protection System Engineer.

OPLP-01 .2 Rev. 39 Page 9 of 50

6.1.3 Surveillance

2. The fire pump diesel engine shall be demonstrated OPERABLE:

a. At least once per 31 days by verifying:

1. The fuel storage tank contains at least 500 gallons of fuel, and

2. The diesel starts from ambient conditions and operates for at least 20 minutes.

b. At least once per 92 days by verifying that a sample of diesel fuel from the fuel storage tank, obtained in accordance with ASTM-D4057-06, is within the acceptable limits specified in Table 1 of ASTM-D975-06b when checked for viscosity, water, and sediment.

c. At least once per 18 months, by:

1. Subjecting the diesel to an inspection in accordance with procedures prepared in conjunction with its manufacturers recommendations for the class of service, and

2. Verifying the diesel starts from ambient conditions on the auto-start signal and operates for greater than or equal to 20 minutes while loaded with the fire pump.

3. The fire pump diesel starting 24-volt battery bank and charger shall be demonstrated OPERABLE:

a. At least once per 7 days by verifying that:

1. The electrolyte level of each battery is above the plates, and

2. The overall battery voltage is greater than or equal to 24 volts.

b. At least once per 92 days by verifying that the specific gravity is appropriate for continued service of the battery.

c. At least once per 18 months by verifying that:

1. The batteries, cell plates, and battery racks show no visual indication of physical damage or abnormal deterioration, and

2. The battery-to-battery and terminal connections are clean, tight, free of corrosion, and coated with anti-corrosion material.

OPLP-01 .2 Rev. 39 Page 10 of 50

6.1.4 Bases The OPERABILITY of the fire suppression systems ensures that adequate fire suppression capability is available to confine and extinguish fires occurring in any portion of the facility where safety-related equipment is located. The fire suppression system consists of the water system, spray and/or sprinklers, 002, and fire hose stations. The collective capability of the fire suppression systems is adequate to minimize potential damage to safety-related equipment and is a major element in the facility fire protection program.

In the event that portions of the fire suppression system are inoperable, alternate backup fire fighting equipment is required to be made available in the affected areas until the inoperable equipment is restored to service.

In the event of a line break, the design of sectionalizing control or isolation valves allows a portion of the ring header to be isolated while maintaining the remainder of the ring header and associated fire suppression systems in an OPERABLE status. Individual compensatory actions for any isolated sprinkler or hose standpipe system will ensure that alternative fire suppression measures are implemented. A line break that can not be isolated will prevent the ring header from functioning as designed, causing the fire suppression water system to become inoperable.

In the event the fire suppression water system becomes inoperable, immediate corrective measures must be taken since this system provides the major fire suppression capability of the plant. Prompt evaluation of the corrective measures to provide adequate fire suppression capability for the continued protection of the nuclear plant must be made by the Shift Manager or designee.

OPLP-O1 .2 Rev. 39 Page 11 of 50

6.2 Spray andlor Sprinkler Systems 6.2.1 Operability The spray and/or sprinkler systems shown in Attachment 1 shall be OPERABLE whenever the equipment in the areas protected by the spray and/or sprinkler system is required to be OPERABLE, and is capable of performing its intended function.

6.2.2 Actions

1. Verify the operability of the fire barriers and fire detection in the area and determine if the spray and/or sprinkler is classified as High Safety Significant (HSS) or Low Safety Significant (LSS)

a. With one or more of the HSS spray and/or sprinkler systems shown in Attachment I inoperable, establish a continuous fire watch with backup fire suppression equipment for the unprotected area(s) within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> and restore the system to OPERABLE status within 14 days.

b. With one or more of the LSS spray and/or sprinkler system inoperable concurrent with a fire detection system or fire barrier in the area inoperable, establish a continuous fire watch with backup fire suppression equipment for the unprotected area(s) within I hours and restore the system to OPERABLE status within 14 days.

c. With one or more of the LSS spray and/or sprinkler systems shown in Attachment I inoperable with the fire barriers and fire detection in the area OPERABLE, establish an hourly fire watch with backup fire suppression equipment for the unprotected area(s) within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> and restore the equipment to OPERABLE status within 14 days.

d. Re-evaluate Steps 6.6.2.1 a, 6.8.2.1 .a and 6.10.2.1 for each inoperable fire barrier, fire detection and cable coating in the area and implement revised fire watch requirements to include consideration of the inoperable spray and/or sprinkler system.

2. Place signs at the backup fire suppression equipment to identify the proper hose to be used.

OPLP-01 .2 Rev. 39 Page 12 of 50

6.2.3 Surveillance Each of the required spray and/or sprinkler systems shown on Attachment I shall be demonstrated OPERABLE:

At least once per 12 months by cycling each testable valve in the flow path through at least one complete cycle of full travel.

R16 2. At least once per 18 months:

a. By performing a system functional test which includes simulated automatic actuation of the system; and:

1. Verifying that the automatic valves in the flow path actuate to their correct positions on a simulated actuation signal, and

2. Cycling each valve in the flow path that is not testable during plant operation through at least one complete cycle of full travel.

b. By inspection of the spray headers to verify their integrity; and

c. By inspection of each deluge nozzle to verify no blockage.

6.2.4 Bases Attachment 6 shows fire protection isolation valves that affect sprinkler / spray system operability. Note that a single isolation valve closure may affect multiple sprinkler systems. Example: Unit 2 RB valve 2-FP-V300 closure will isolate the South RHR sprinkler system and the 5 elevation Separation Zone Water Curtain.

2. Removal of the floor plugs above the HPCI mezzanine (by the 20 ft CRD Flow Control Stations) renders the 5 separation zone water curtain inoperable due to the potential to divert the flow of hot gases away from the sprinkler heads.

3. Sprinkler system flow indication is credited in the Fire Hazard Analysis as providing fire detection for the Diesel Generator cells (DG Bldg 23 elev.). Flow indication function is required for operability of the following spray and/or sprinkler systems:

- Diesel Generator #1 Sprinkler System (HSS)

- Diesel Generator #2 Sprinkler System (HSS)

OPLP-01 .2 Rev. 39 Page 13 of 50

6.2.4 Bases

- Diesel Generator #3 Sprinkler System (HSS)

- Diesel Generator #4 Sprinkler System (HSS)

All other spray and/or sprinkler systems listed in Attachment I do not require flow indication for system operability.

4. Standby Gas Treatment (SBGT) temperature switches associated with annunciators UA-35 2-9 (Unit 1) or UA-36 2-9 (Unit 2) are required for SBGT deluge system operability. SBGT deluge systems listed in Attachment 1 are manually actuated and the annunciators alert operators that a fire is active in a SBGT charcoal filter bed.

Without these annunciators, operators will not be alerted to manually initiate the deluge system.

Temperature switches for both SBGT A and B are annunciated REACTOR BLDG SBGT UNITS TEMP HIGH by UA-35 2-9 (Unit 1) or UA-36 2-9 (Unit 2). A non-fire condition that causes an annunciator to seal-in will result in deluge system inoperability for both SBGT A and B. An inoperable temperature switch (loss of control room annunciation) may result in deluge system inoperability for the associated SBGT train. Note that all SBGT Charcoal Filter Banks have redundant temperature switches and a single switch failure does not necessarily result in deluge system inoperability.

Reference IAPP-UA-35 or 2APP-UA-36 for specific details.

6.3 High Pressure CO 2 Systems 6.3.1 Operability The high pressure CO 2 systems shown in Attachment 2 shall be OPERABLE in Modes 1, 2 and 3, with a minimum contained weight of 67.5 lbs. of CO 2 in each cylinder of the in-service bank.

6.3.2 Actions

1. With one or more of the required high pressure CO 2 systems inoperable, establish a continuous fire watch and backup fire suppression equipment for the unprotected area(s) within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> and restore the system to OPERABLE status within 14 days and

2. Place signs at the backup fire suppression equipment to identify the proper hose to be used.

OPLP-O1 .2 Rev. 39 Page 14 of 50

6.3.3 Surveillance Each of the required high pressure CO2 systems shown in Attachment 2 shall be demonstrated OPERABLE:

1. At least once per 6 months by verifying that the high pressure CO2 cylinders contain at least the minimum specified weight of 002.

2. At least once per 18 months by verifying:

a. The system control heads and associated ventilation dampers actuate manually and automatically, as appropriate, upon receipt of a simulated actuation signal, and

b. Performance of a flow test through flooding system headers and nozzles to assure no blockage.

6.4 Fire Hose Stations 6.4.1 Operability The fire hose stations shown in Attachment 3 shall be OPERABLE whenever equipment in the areas protected by the fire hose stations is required to OPERABLE, and is capable of performing its intended function.

6.4.2 Actions With one or more fire hose stations shown in Attachment 3 inoperable:

1. Within one hour:

a. Provide an alternative means of fire suppression for the unprotected area(s), and/or

b. Route an additional equivalent capacity fire hose to the unprotected area(s) from an OPERABLE hose station located in another fire zone using a gated wye connection off that operable station.

2. Place signs at the backup fire suppression equipment to identify the proper hose to be used.

OPLP-O1 .2 Rev. 39 Page 15 of 50

6.4.3 Surveillance Each of the fire hose stations shown in Attachment 3 shall be demonstrated OPERABLE:

a. At least once per 31 days by visual inspection of the station to assure all required equipment is at the station.

b. At least once per 18.months by:

1. Removing the hose for inspection and re-racking, and

2. Replacement of all degraded gaskets in couplings.

c. At least once per 3 years by:

1. Partially opening each hose station valve to verify valve OPERABILITY and no flow blockage, and

2. Conducting a hose hydrostatic test at a pressure at least 50 psig greater than the maximum pressure available at that hose station.

6.5 Foam Systems 6.5.1 Operability The following foam systems shall be OPERABLE at all times:

a. The Diesel Generator Fuel Oil Tank Area Foam System with:

1. The concentrate proportioning and storage subsystem OPERABLE with 240 gallons of concentrate.

2. Each tank room subsystem OPERABLE with minimum required Fire Detection Instruments shown in Attachment 5 OPERABLE.

OPLP-01 .2 Rev. 39 Page 16 of 50

6.5.1 Operability

b. The Diesel Generator Air Filter Foam System with:

1. The concentration proportioning and storage subsystem OPERABLE with 40 gallons of concentrate.

2. Each air filter subsystem OPERABLE with minimum required Fire Detection Instruments shown in Attachment 5 OPERABLE.

6.5.2 Actions

1. With one or more tank room subsystems inoperable, establish a continuous fire watch, verify the availability of backup foam fire suppression equipment for the unprotected area(s) within one hour, and restore the system to OPERABLE status within 14 days.

2. With one or more air filter subsystems inoperable, establish a continuous fire watch, verify the availability of backup foam fire suppression equipment for the unprotected area(s) within one hour, and restore the system to OPERABLE status within 14 days.

3. With any Control Room annunciation circuit inoperable that does not prevent actuation of its associated deluge valve or local panel trouble alarm, verify the deluge valve or local panel trouble alarm, as appropriate for the condition, is not actuated at least once per 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br />.

4. Place signs at the backup foam hose reel(s) or backup fire suppression equipment to identify the proper hose to be used.

6.5.3 Surveillance

1. Each of the required foam systems shall be demonstrated OPERABLE:

a. At least once per 92 days by demonstrating that unsupervised Control Room annunciation circuits are OPERABLE for:

1. The circuit associated with each deluge valve (testing may be performed at the local junction box), and OPLP-01.2 Rev. 39 Page 17 of 50

6.5.3 Surveillance

2. The circuit associated with each local panel trouble alarm.

b. At least once per 12 months by:

1. Cycling each testable valve in the flow path through at least one complete cycle of full travel, and

2. Performing a Channel Functional Test of associated Fire Detection Instruments.

c. At least once per 18 months by:

1 Performing a system functional test which includes simulated automatic actuation of the system, and

a. Verifying that the automatic valves in the flow path actuate to their correct positions on a simulated actuation signal, and

b. Cycling each valve in the flow path that is not testable during plant operation through at least one complete cycle of full travel.

2. A visual inspection of the spray headers to verify their integrity.

3. A visual inspection of each nozzles spray area to verify that the spray pattern is not obstructed.

4. Conducting a performance evaluation of the concentrate.

OPLP-O1 .2 Rev. 39 Page 18 of 50

6.6 Fire Barrier Penetrations 6.6.1 Operability All fire barrier penetrations, including cable penetration barriers, fire doors, and fire dampers, in fire zone boundaries protecting safety-related areas shall be functional at all times.

6.6.2 Actions With one or more of the above required fire barrier penetrations nonfunctional:

a. Within one hour, establish a continuous fire watch on at least one side of the affected penetration, or verify the OPERABILITY of fire detectors (if installed) and a spray or sprinkler system (if installed) on at least one side of the nonfunctional fire barrier and establish an hourly fire watch patrol.

b. Re-evaluate Steps 6.2.2.1 .b and 6.8.2.1 .a for each inoperable spray and/or sprinkler system, fire detection and cable coating in the area and implement revised fire watch requirements to include consideration of the inoperable fire barrier.

c. Restore the nonfunctional fire barrier penetration(s) to functional status within 7 days.

R17 6.6.3 Surveillance The required fire barrier penetrations shall be verified to be functional:

a. At least once per 18 months by visually inspecting a statistical sample of penetration seals in each affected building (or group of buildings). Each sample shall be selected based on building seal population utilizing a multiple sampling program in accordance with ANSI/ASQC Zi .4-1993, Sampling Procedures and Tables for Inspection by Attributes, with an Acceptable Quality Level of 96%.

b. Prior to restoring a fire barrier penetration to functional status following repairs or maintenance by performance of a visual inspection of the affected fire barrier penetration.

OPLP-O1 .2 Rev. 39 Page 19 of 50

6.6.4 Bases The functional integrity of the fire barrier penetrations ensures that fires will be confined or adequately retarded from spreading to adjacent portions of the facility. This design feature minimizes the possibility of a single fire rapidly involving several areas of the facility prior to detection and extinguishment. The fire barrier penetrations are a passive element in the facility fire protection program and are subject to periodic inspections.

The barrier penetrations, including cable penetration barriers, fire doors, and dampers, are considered functional when the visually observed condition is the same as the as-designed condition. For those fire barrier penetrations that are not in the as-designed condition, an evaluation shall be performed to show that the modification has not degraded the fire rating of the fire barrier penetration.

During periods of time when the barriers are not functional, either;

1) a continuous fire watch is required to be maintained in the vicinity of the affected barrier, or 2) the fire detectors and spray/sprinkler systems (if installed) on at least one side of the affected barrier must be verified OPERABLE and an hourly fire watch patrol established until the barrier is restored to functional status.

Periodic surveillance of fire barrier penetrations using a statistical sampling method has been determined to be acceptable as discussed in ESR 99-00328, Penetration Seal Statistical Sampling Program.

OPLP-01 .2 Rev. 39 Page 20 of 50

6.7 Diesel Generator Building Basement Halon 6.7.1 Operability The following portions of the Diesel Generator Building basement halon systems shall be OPERABLE at all times:

a. As a minimum the fire detection instrumentation for each fire detection zone shown in Attachment 4 for Diesel Generator Building Halon.

b. Each halon cylinder shall have at least 95% of its liquid level and 90% of its full charge.

c. The nitrogen supply bottles shall be maintained to at least 95%

of their full charge.

6.7.2 Actions With the halon system inoperable, establish an hourly fire watch with backup fire suppression within one hour and restore the system to OPERABLE status within 14 days.

IR17 6.7.3 Surveillance The Diesel Generator Building halon system shall be demonstrated OPERABLE:

a. At least once per 6 months by verifying that the halon cylinders contain at least the minimum specified liquid level and both the halon cylinders and the nitrogen supply containers are maintained at the minimum specified pressure.

b. Each of the required fire detection instruments shall be demonstrated OPERABLE at least once per 12 months by performance of a functional test.

OPLP-01 .2 Rev. 39 Page 21 of 50

6.7.4 Bases The Diesel Generator Building Basement Halon System provides fire detection and automatic fire suppression protection for redundant safe shutdown functions in the area as an alternative to strict compliance with 100FR5O, Appendix R, Section IlI.G.2. The cross-zoned, supervised Halon 1301 suppression system is designed to provide rapid fire suppression in the Diesel Generator Building basement so that one train of systems necessary to achieve and maintain hot shutdown conditions is free of fire damage. The existence of a local sprinkler system provides additional fire suppression for the area.

In the event that the Halon system is inoperable, an hourly fire watch is required in addition to backup fire suppression. Sprinkler systems in the Diesel Generator Building basement, combined with a low combustible loading in the area, provide a reasonable basis for the use of an hourly fire watch.

6.8 Fire Detection Instrumentation R16 6.8.1 Operability As a minimum, the fire detection instrumentation for each fire detection zone shown in Attachment 4 shall be OPERABLE at all times.

2. The fire detection instrumentation in the Unit 1 and Unit 2 Turbine Building breezeway shall be OPERABLE with at least three of six detectors (50%) in each breezeway OPERABLE.

- Unit 1, these detectors are 1-FP-TB-2-1, 2-2, 2-3, 2-9, 2-13, and 2-14.

- Unit 2, these detectors are 2-FP-TB-2-1, 2-2, 2-3, 2-6, 2-12, and 2-15 OPLP-01 .2 Rev. 39 Page 22 of 50

6.8.2 Actions

1. With one or more of the required fire detection instrument(s) shown in Attachment 4 inoperable:

a. Within one hour verify the operability of fire barriers and cable coatings in the area covered by the affected zone and the operability of spray and/or sprinkler systems in the area covered by the affected zone and establish an hourly fire watch patrol.

b. Re-evaluate Steps 6.2.2.1.b, 6.6.2.1.a and 6.10.2.1 for each inoperable spray and/or sprinkler system, fire barrier and cable coating in the area and implement revised fire watch requirements to include consideration of the inoperable fire detection instrument(s).

Restore the instrument(s) to operable status within 14 days.

2. With less than three of six detectors (50%) in either Unit 1 or Unit 2 Turbine Building breezeway OPERABLE, within one hour establish an hourly fire watch for the unprotected area and restore the instrument(s) to operable status within 14 days.

6.8.3 Surveillance

1. Each of the Fire Detection Instruments shown in Attachment 4 shall be demonstrated OPERABLE by performance of a Channel Functional Test at the following intervals:

NOTE: Additional functional testing of smoke detectors in Control Building Zones 4 and 5 is addressed in the Technical Requirements Manual (TRMS 3.12).

This additional testing is independent of the functional testing described below.

a. Flame detectors: at least once per 12 months.

b. Smoke detectors: at least once per 12 months.

c. Heat detectors: at least once per 12 months.

OPLP-01 .2 Rev. 39 Page 23 of 50

6.8.3 Surveillance

2. The unsupervised circuits between the local panels associated with the detector alarms of each of the required fire detection instruments from Attachment 4 and the Control Room shall be demonstrated OPERABLE at least once per 92 days in accordance with approved procedures.

3. Each Fire Detection Instrument in the Unit I and Unit 2 Turbine Building Breezeway shall be demonstrated OPERABLE at least once per 12 months by performance of a Channel Functional Test.

6.8.4 Bases Operability of the fire detection instrumentation ensures that adequate warning capability is available for the prompt detection of fires. This capability is required in order to detect and locate fires in their early stages. Prompt detection of fires will reduce the potential for damage to safety related equipment and is an integral element in the overall facility fire protection program. Control Room annunciation is required for operability of fire detection systems listed in Attachment 4.

Fireworks computer work stations I -FR-TER and 2-FP-TER are NOT required for control room annunciation of Unit I or Unit 2 fire detection systems.

In the event that a portion of the fire detection instrumentation is inoperable, increasing the frequency of fire patrols in the affected areas is required to provide detection capability until the inoperable instrumentation is restored to OPERABILITY.

The basis for fire detection instrumentation surveillance frequency is contained in ESR 97-00375.

OPLP-0I .2 Rev. 39 Page 24 of 50

6.9 Public Address Page System 6.9.1 Operability The Public Address Page system shall be OPERABLE at all times with speakers in all areas functioning.

69.2 Actions With the Public Address Page system inoperable, restore the system to OPERABLE status within 30 days. Notify Security if an inoperable speaker creates a dead zone.

6.9.3 Surveillance NOTE: Speakers that cannot be heard due to excessive background noise may be exempted from functional testing requirements provided each affected area has been classified as a dead zone by Security.

NOTE: Speakers located in locked high radiation areas may be exempted from functional testing requirements. Locked high radiation areas do not require classification as dead zones since they are not normally accessible.

The Public Address Page system shall be demonstrated OPERABLE at least quarterly (92 days) by a functional test of each PA speaker.

6.9.4 Bases The purpose of these requirements is to ensure that the alarm functions provided by the Public Address Page System are functional.

For this reason, the action requirements only apply to the speakers, not to the handsets or wall stations.

OPLP-01 .2 Rev. 39 Page 25 of 50

6.10 Fire Protection Coatings, Raceway Barriers, and Special Barriers 6.10.1 Operability All cable coatings, raceway barriers, and special fire protection barriers installed to comply with Branch Technical Position, 9.5-1, Appendix A and/or 1 OCFR5O Appendix R, shall be functional at all times.

6.10.2 Actions

1. With any of the above required fire coatings/barriers nonfunctional, within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> establish a continuous fire watch in the area or verify the operability of fire detectors (if installed) and a spray and/or sprinkler system (if installed) in the area of the nonfunctional coating/barrier and establish an hourly fire watch patrol.

2. Re-evaluate Steps 6.2.2.1 .b, and 6.8.2.1 .a for each inoperable spray and/or sprinkler system, fire barrier, and fire detection in the area and implement revised fire watch requirements to include consideration of the inoperable coating/barrier.

3. Restore the nonfunctional fire coating/barrier to functional status within 7 days.

6.10.3 Surveillance

1. Cable coatings, raceway barriers, and special fire protection barriers installed to comply with Branch Technical Position, 9.5-1, Appendix A and 10CFR5O Appendix R, shall be verified to be functional:

a. At least once per 18 months by a visual inspection, and

b. Prior to restoring the coating/barrier to functional status following repairs or maintenance by performance of a visual inspection of the affected coating/barrier.

OPLP-O1 .2 Rev. 39 Page 26 of 50

6.11 Fire Brigade 6.11.1 Operability A Fire Brigade of at least five members shall be maintained on site at all times. The Fire Brigade shall not include the minimum shift crew required by Technical Specifications or any personnel required for other essential functions during a fire emergency.

6.11.2 Actions

1. With Fire Brigade composition less than the minimum requirements due to unexpected absence, take immediate action to fill the required position(s).

2. Return Fire Brigade composition to minimum requirements within two hours.

6.11.3 Surveillance None Applicable 6.11.4 Bases BNP is required to have a five person fire brigade, organized as follows:

1. One Brigade Commander

2. Four Brigade Members, who are supposed to perform the actual fire fighting activities.

3. The qualifications for the fire brigade shall be as follows:

All initial and continuing classroom training, live-fire, and drill requirements shall be current.

Fire Brigade members shall be considered physically fit. Physically fit means that a qualified physician determines that there are no known physical or medical limitations that would interfere with the performance of strenuous heavy lifting and pulling or with the use of self-contained breathing apparatus that can be required during emergency response activities.

7.0 RECORDS There are no records generated by this procedure.

OPLP-O1 .2 Rev. 39 Page 27 of 50

ATTACHMENT I Page 1 of 2 Required Water Spray/Sprinkler Systems DIESEL GENERATOR BUILDING Diesel Generator #1 Sprinkler System (HSS)

Diesel Generator #2 Sprinkler System (HSS)

Diesel Generator #3 Sprinkler System (HSS)

Diesel Generator #4 Sprinkler System (HSS)

South Basement (2) Cable Spread Area Sprinkler System (HSS)

North Basement (2) Cable Spread Area Sprinkler System (HSS)

CONTROL BUILDING Unit I Cable Spread Area Sprinkler System (LSS)

Unit 2 Cable Spread Area Sprinkler System (LSS)

REACTOR BUILDING I North and South Core Spray Pump Rooms (LSS)

North (LSS) and South (HSS) RHR Rooms 5-O Separation Zone Water Curtain (HSS) 20 Southwest Sprinkler System (LSS) 20 Southwest Separation Zone Water Curtain (HSS) 20 East Separation Zone Water Curtain (HSS) 20 Railroad Bay Sprinkler System (LSS) 20 ECCS Room Sprinkler Head (HSS) 38 Separation Zone Water Curtain (HSS) 50 Sprinkler System (Near Elevator) (LSS) 50 Separation Zone Water Curtain (HSS) 80 Sprinkler System (LSS)

Two Standby Gas Treatment Train IA Deluge Systems (LSS)

Two Standby Gas Treatment Train 1 B Deluge Systems (LSS)

OPLP-01 .2 Rev. 39 Page 28 of 50

ATTACHMENT 1 Page 2of2 Required Water SpraylSprinkler Systems REACTOR BUILDING 2 North and South Core Spray Pump Rooms (LSS)

North (LSS) and South (HSS) RHR Rooms 5-O Separation Zone Water Curtain (HSS) 20 Southwest Sprinkler System (LSS) 20 East Separation Zone Water Curtain (HSS) 20 Railroad Bay Sprinkler System (LSS) 20 ECCS Room Sprinkler Head (HSS) 38 Separation Zone Water Curtain (HSS) 50 Sprinkler System (Near Elevator) (LSS) 50 Separation Zone Water Curtain (HSS) 80 Sprinkler System (LSS)

Two Standby Gas Treatment Train 2A Deluge Systems (LSS)

Two Standby Gas Treatment Train 2B Deluge Systems (LSS)

SERVICE WATER BUILDING Service Water Pump Area Sprinkler System (HSS)

Service Water Cable Spread Area Sprinkler System (HSS)

RADWASTE BUILDING Drumming Room Sprinkler System (LSS)

MAKEUP WATER TREATMENT BUILDING Makeup Water Treatment Area Sprinkler System (LSS)

OPLP-01 .2 Rev. 39 Page 29 of 50

ATTACHMENT 2 Page 1 of 1 Required High Pressure CO2 Systems Unit No. I HPCI CO 2 System Unit No. 2 HPCI CO 2 System OPLP-O1 .2 Rev. 39 Page 30 of 50

ATTACHMENT 3 Page 1 of 3 Required Fire Hose Stations LOCATION ELEVATION HOSE RACK NO.

AOG Building 23 2-AOG-57 23 2-AOG-58 23 2-AOG-59 23 2-AOG-60 37 2-AOG-62 49 2-AOG-61 Control Building 23 1-CB-1 49 1 -CB-2 23 2-CB-1 49 2-CB-2 70 2-CB-3 Diesel Generator Building 2 DGB-1 2 DGB-2 2 DGB-3 23 DGB 4 23 DGB-5 23 DGB-6 23 DGB-7 23 DGB-8 23 DGB-9 50 DGB-10 50 DGB-1 I 50 DGB-12 50 DGB-13 50 AFFF HR-2 50 AFFF HR-3 Diesel Generator Tank Area N/A AFFF HR-i Radwaste Building -3 RW-49

-3 RW-50

-3 RW-51 23 RW-52 23 RW-53 23 RW-54 23 RW-55 23 RW-56 Service Water Building 4 SW-i 20 SW-2 20 SW-3 OPLP-01 .2 Rev. 39 Page 31 of 50

ATTACHMENT 3 Page2of3 Required Fire Hose Stations LOCATION ELEVATION HOSE RACK NO.

Unit 1 Reactor Building -17 1-RB-19

-17 1-RB-20

-17 1-RB-24

-17 1-RB-25

-17 1-RB-26 20 1-RB-21 20 1 -RB-22 20 1-RB-23 20 1-RB-27 20 1 -RB-28

20. 1 -RB-29 50 1 -RB-30 50 1-RB-31 50 1 -RB-32 50 1 -RB-33 50 1 -RB-34 50 1 -RB-35 67 1 -RB-48A 80 1 -RB-36 80 1 -RB-39 80 1-RB-41 80 1 -RB-43 80 1 -RB-44 80 1 -RB-45 98 1 -RB-37 117 1 -RB-38 117 1 -RB-40 117 1-RB-42 117 1-RB-46 117 1-RB-47 117 1 -RB-48 OPLP-01 .2 Rev. 39 Page 32 of 50

ATTACHMENT 3 Page 3 of 3 Required Fire Hose Stations LOCATION ELEVATION HOSE RACK NO.

Unit 2 Reactor Building -17 2-RB-19

-17 2-RB-20

-17 2-RB-24

-17 2-RB-25

-17 2-RB-26 20 2-RB-21 20 2-RB-22 20 2-RB-23 20 2-RB-27 20 2-RB-28 20 2-RB-29 50 2-RB-30 50 2-RB-31 50 2-RB-32 50 2-RB-33 50 2-RB-34 50 2-RB-35 67 2-RB-48A 80 2-RB-36 80 2-RB-39 80 2-RB-41 80 2-RB-43 80 2-RB-44 80 2-RB-45 98 2-RB-37 117 2-RB-38 117 2-RB-40 117 2-RB-42 117 2-RB-46 117 2-RB-47 117 2-RB-48 OPLP-01 .2 Rev. 39 Page 33 of 50

ATTACHMENT 4 Page 1 of 8 Required Fire Detection Instruments MINIMUM INSTRUMENTS OPERABLE DETECTOR ZONE! BUILDING AREA FLAME HEAT SMOKE

1. Reactor Building #1

(-)17 N Core Spray Pump Room 0 0 1 Detectors 1-1, 1-2

(-)17 S Core Spray Pump Room 0 0 1 Detectors 3-1, 3-2

(-)17 N RHR/CRD Pump Area 0 0 4 Detectors 1-4, 1-5, 1-6, 1-8, 1-9

(-)17 S RHR Pump Area 0 0 4 Detectors 3-4, 3-5, 3-6, 3-7, 3-9, 3-10 20 N RHR HX Room 0 0 1 Detectors 1-10, 1-11 20SRHRHXRoom 0 0 1 Detectors 3-11, 3-12 20 South 0 0 10 Detectors 2-7, 2-11, 2-12, 1-13, 2-14, 2-15, 2-16, 2-17, 2-18, 2-19, 2-20, 2-21, 2-22, 2-23, 2-24 20North 0 0 6 Detectors 2-27, 2-28, 2-29, 2-30, 2-31, 2-32, 2-33, 2-35, 2-36 20East 0 0 8 Detectors 2-39, 2-40, 2-41, 2-42, 2-43, 2-44, 2-45, 2-46, 2-47, 2-48, 2-50, 2-51 20 Personnel Airlock 0 0 1 Detectors 2-8, 2-9 20 Pipe Tunnel North Half 0 0 1 Detectors 2-37, 2-38 20 Pipe Tunnel South Half 0 0 1 Detectors 2-25 20 Personnel Decon Room 0 0 1 Detectors 2-53, 2-54 OPLP-01 .2 Rev. 39 Page 34 of 50

ATTACHMENT 4 Page2of8 Required Fire Detection Instruments MINIMUM INSTRUMENTS OPERABLE DETECTOR ZONE! BUILDING AREA FLAME HEAT SMOKE

1. Reactor Building #1 (continued) 50 East 0 0 10 Detectors 6-1, 6-2, 6-3, 6-5, 6-6, 6-7, 6-8, 6-9, 6-10, 6-11, 6-12, 6-13, 6-15, 6-16 50North 0 0 5 Detectors 6-17, 6-18, 6-19, 6-20, 6-21, 6-22, 6-23 50West 0 0 3 Detectors 6-25, 6-26, 6-27, 6-28 50 South 0 0 4 Detectors 6-30, 6-31, 6-32, 6-33, 6-34, 6-35 80East 0 0 7 Detectors 5-13, 5-14, 5-15, 5-16, 5-17, 5-18, 5-19, 5-20, 5-21, 5-22 80West 0 0 7 Detectors 5-1, 5-2, 5-3, 5-5, 5-6, 5-7, 5-8, 5-9, 5-10, 5-11 80 Resin Room 0 0 1 Detector 5-24 80 CRD Room 0 0 1 Detectors 5-25, 5-26 98 Change Room 0 0 1 Detector 5-28 98 Contaminated Equip Room 0 0 1 Detector 5-29 117 4 Elevator Equipment Room 0 0 1 Detector 5-31 OPLP-01 .2 Rev. 39 Page 35 of 50

ATTACHMENT 4 Page 3of8 Required Fire Detection Instruments MINIMUM INSTRUMENTS OPERABLE DETECTOR ZONE! BUILDING AREA FLAME HEAT SMOKE

2. Reactor Building #2

(-)17 N Core Spray Pump Room 0 0 1 Detectors 1-1, 1-2

(-)17 S Core Spray Pump Room 0 0 1 Detectors 3-1, 3-2

(-)17 N RHR/CRD Pump Area 0 0 4 Detectors 1-4, 1-5, 1-6, 1-8, 1-9

(-)17SRHRPumpArea 0 0 4 Detectors 3-4, 3-5, 3-6, 3-8, 3-9 20NRHRRoom 0 0 1 Detectors 1-10, 1-11 20SRHRRoom 0 0 1 Detectors 3-10, 3-11 20 South 0 0 10 Detectors 2-1, 2-5, 2-6, 2-7, 2-8, 2-9, 2-10, 2-11, 2-12, 2-13, 2-14, 2-15, 2-16 20North 0 0 6 Detectors 2-19, 2-20, 2-21, 2-22, 2-23, 2-24, 2-26, 2-27, 2-28 20East 0 0 8 Detectors 2-31, 2-32, 2-33, 2-34, 2-35, 2-36, 2-37, 2-38, 2-39, 2-40, 2-41 20 Personnel Airlock 0 0 1 Detectors 2-2, 2-3 20 Pipe Tunnel North Half 0 0 1 Detectors 2-29, 2-30 20 Pipe Tunnel South Half 0 0 1 Detector 2-17 OPLP-01 .2 Rev. 39 Page 36 of 50

ATTACHMENT 4 Page 4 of 8 Required Fire Detection Instruments MINIMUM INSTRUMENTS OPERABLE DETECTOR ZONE! BUILDING AREA FLAME HEAT SMOKE

2. Reactor Building #2 (continued) 20 Personnel Decon Room 0 0 1 Detectors 2-43, 2-44 50 East 0 0 10 Detectors 6-1, 6-2, 6-3, 6-4, 6-6, 6-7, 6-8, 6-9, 6-10, 6-11, 6-13, 6-14, 6-15 50North 0 0 5 Detectors 6-16, 6-17, 6-18, 6-19, 6-20, 6-21, 6-23, 6-24 50West 0 0 3 Detectors 6-25, 6-26, 6-27, 6-28 50 South 0 0 4 Detectors 6-29, 6-31, 6-32, 6-33, 6-34, 6-35 80East 0 0 7 Detectors 5-15, 5-16, 5-17, 5-18, 5-19, 5-20, 5-21, 5-22, 5-24, 5-25 80West 0 0 8 Detectors 5-1, 5-2, 5-3, 5-4, 5-6, 5-7, 5-8, 5-9, 5-10, 5-11, 5-12, 5-13 80 Resin Room 0 0 1 Detectors 5-26 80 CRD Room 0 0 1 Detectors 5-27, 5-28 98 Change Room 0 0 1 Detector 5-30 98 Contaminated Equip Room 0 0 1 Detector 5-31 117 4 Elevator Equipment Room 0 0 1 Detector 5-33

[ OPLP-01 .2 Rev. 39 Page 37 of 50

ATTACHMENT 4 Page 5 of 8 Required Fire Detection Instruments MINIMUM INSTRUMENTS OPE RABLE DETECTOR ZONE FLAME HEAT SMOKE

3. Service Water Building 4 EL. Detectors 2-FP-SW-5-1, 5-2, 5-3, 5-4, 0 0 7 5-5, 5-7, 5-8, 5-9, 5-10, 5-11 20 El. Detectors 2-FP-SW-5-12, 5-13, 5-14, 0 0 6 5-15, 5-16,_5-17,_5-19,_5-20

4. AOG Building 20 Charcoal adsorber area Detectors 2-FP-OG-4-1, 4-2, 4-3, 4-4 0 0 2 20 Cooler condenser area & rad monitor room Detectors 2-FP-OG-4-5, 4-6, 4-7 0 0 2 20 Control panel room, change room, decon area Detectors 2-FP-OG-4-9, 4-10, 4-12, 4-13, 4-14, 0 6 1 4-15, 4-16, 4-17, 4-18 37 Mechanical equip room and plenum Detectors 2-FP-OG-4-20, 4-21, 4-22, 4-23, 0 4 2 4-24, 4-25, 4-26, 4-27 49 Liquid nitrogen storage Detectors 2-FP-OG-4-29, 4-30 0 2 0 OPLP-01 .2 Rev. 39 Page 38 of 50

ATTACHMENT 4 Page6of8 Required Fire Detection Instruments

5. Control Building Zonel 70 0 0 9 Zone 2 49 0 0 4 Zone3 491 0 0 4 Zone4 49 0 0 13 Zone 5 49 0 0 14 Zone 6 49 (See Note) 0 0 6 Zone7 23 0 0 3 Zone8 23 0 0 3 Zone9 23 0 0 25 Zone 10 23 0 0 24 Zonell 23 0 0 3 Zone 12 23 0 0 3 Zonel3 49 0 0 9 Zonel4 49 0 0 9 Zonel5 70 0 1 0 Zone 16 70 0 1 0 NOTE: Zone 6 Detects the Control Room Area with 9 detectors (C6-1 through C6-9), and the Operations Back Office with 10 detectors (C6-10 through C6-1 9). The minimum instruments operable for the Control Room Area is six. The minimum instruments operable for the Operations Back Office is zero.

OPLP-01 .2 Rev. 39 Page 39 of 50

ATTACHMENT 4 Page 7 of 8 Required Fire Detection Instruments MINIMUM INSTRUMENTS OPERABLE DETECTOR ZONE FLAME HEAT SMOKE

6. Diesel Generator Building 2 Basement 0 0 0 23 North Switchgear Area Detectors 1-7, 1-8, 1-9, 1-10, 1-11, 0 0 8 1-12, 1-13, 1-14, 1-15, 1-16, 1-17 23 South Switchgear Area Detectors2-7,2-8,2-9,2-10,2-11, 0 0 7 2-12, 2-13, 2-14, 2-15, 2-16, 2-17 23 Diesel Cell I Detectors 1-1, 1-2 1 0 0 23 Diesel Cell 2 Detectors 1-3, 1-4 1 0 0 23 Diesel Cell 3 Detectors2-1,2-2 1 0 0 23 Diesel Cell 4 Detectors 2-3, 2-4 1 0 0 50 Air Intake Area Detectors 4-2, 4-3, 4-4, 4-5, 4-6, 0 0 8 4-8, 4-9, 4-11, 4-12 50 Air Filter AFFF Room Detector 4-10 0 0 1 50 4160V Switchgear El Detectors 4-23, 4-24, 4-25 0 0 2 50 4160V Switchgear E2 Detectors 4-19, 4-20, 4-21, 4-22 0 0 3 50 4160V Switchgear E3 Detectors4-16,4-17,4-18 0 0 2 50 4160V Switchgear E4 Detectors 4-13,4-14,4-15 0 0 2 OPLP-01 .2 Rev. 39 Page 40 of 50

ATTACHMENT 4 Page8of8 Required Fire Detection Instruments DETECTORZONE NUMBEROF MINIMUM MAXIMUM DETECTORS DETECTORS ALLOWABLE INSTALLED REQUIRED INOPERABLE OPERABLE DETECTORS

7. Diesel Generator Building Halon Zonel 18 14 4 Zone2 18 14 4 Zone3 20 15 5 Zone4 20 15 5 Zone5 18 14 4 Zone6 18 14 4 NOTE: The fire detectors shown for Diesel Generator Building Halon apply to both Section 6.7 and Section 6.8 operability requirements.

OPLP-01 .2 Rev. 39 Page 41 of 50

ATTACHMENT 5 Page 1 of 1 Required Foam System Fire Detection Instruments MINIMUM INSTRUMENTS OPERABLE DETECTOR ZONE FLAME HEAT SMOKE

1. Diesel Generator Fuel Oil Tank Area Foam System Fuel Cell Subsystem No. 1 0 2 0 Fuel Cell Subsystem No. 2 0 2 0 Fuel Cell Subsystem No. 3 0 2 0 Fuel Cell Subsystem No. 4 0 2 0

2. Diesel Generator Air Filter Foam System DG Air Filter Subsystem No. 1 Upper Ring 0 2 0 Lower Ring 0 2 0 DG Air Filter Subsystem No. 2 Upper Ring 0 2 0 Lower Ring 0 2 0 DG Air Filter Subsystem No. 3 Upper Ring 0 2 0 Lower Ring 0 2 0 DG Air Filter Subsystem No. 4 Upper Ring 0 2 0 Lower Ring 0 2 0 NOTE: The fire detectors shown in Attachment 5 apply to Section 6.5, Foam Systems operability requirements.

0PLP-01 .2 Rev. 39 Page 42 of 50

ATTACHMENT 6 Page 1 of 7 Sprinkler System I Isolation Valve Cross Reference Unit 1 Reactor Building Sprinkler Systems 20 SW 20 East 5 Sep 20 38 Sep 50 Sep Sep Sep 20 SPRINKLER Z one 20 East Zone 50 Near Zone 80 NCS SCS NRHR SRHR Zone Zone ECCS SYSTEM Water SW Water Elevator Water System Water Water Room Curtain Bay Curtain Curtain Curtain Curtain V214 X X X X X X X X X X X X X X V366 X X X X X X X X X X X X X X V302 X V305 X V300 X X V301 X 0

i V326 X X V316 X X X X U)

V367 X X X X V1032 X V315 X X V324 X NOTES: 1. Reference drawings D-29099, Sheets 1 and 2

2. All valves prefixed 1-FP OPLP-O1 .2 Rev. 39 Page 43 of 50

ATTACHMENT 6 Page2of7 Sprinkler System I Isolation Valve Cross Reference Unit 2 Reactor Building Sprinkler Systems 5 Sep 20 East 20 38 Sep 50 Sep 20 SPRINKLER Zone 20 Sep Zone East Zone 50 Near Zone 80 NCS SCS NRHR SRHR ECCS SYSTEM Water SW Water RR Water Elevator Water System Room Curtain Curtain Bay Curtain Curtain V214 X X X X X X X X X X X X X V366 X X X X X X X X X X X X X V302 X V305 X V300 X X V301 X 0

j V326 X V316 X X X X U)

V367 X X X X V1032 X V315 X X V324 X NOTES: 1. Reference drawings D-02299, Sheets I and 2

2. All valves prefixed 2-FP OPLP-O1 .2 Rev. 39 Page 44 of 50

ATTACHMENT 6 Page3of7 Sprinkler System I Isolation Valve Cross Reference Service Water Building Sprinkler Systems Service Water Pump Area Service Water Cable Spread Area SPRINKLER (above 20 elevation) (below 20 elevation)

SYSTEM Unit I Side Unit 2 Side Unit I Side Unit 2 Side 1-FP-V219 X X 2-FP-V219 X X uJ 1-FP-V277 X X 2-FP-V277 X X 0

ii 1-FP-V95 X 0 2-FP-V263 X Cl) 1-FP-V96 X 2-FP-V96 X NOTE: 1. Reference drawing D-02304 OPLP-01 .2 Rev. 39 Page 45 of 50

ATTACHMENT 6 Page4of7 Sprinkler System I Isolation Valve Cross Reference Radwaste Building Sprinkler System Drumming Room SPRINKLER SYSTEM Sprinkler System z 2-FP-V705 X ow

<1

-J<

> 2-FP-V712 X NOTE: 1. Reference drawing D-02304 LP-O1 .2 Rev. 39 Page 46 of 50

ATTACHMENT 6 Page5of7 Sprinkler System I Isolation Valve Cross Reference Water Treatment Building Sprinkler System SPRINKLER Water Treatment SYSTEM Bldg.

z Qw

< 2-FP-V100 X NOTES: 1. Reference drawing D-02304

2. Hose station 2-FP-WT-HR-1 also isolated when 2-FP-V100 closed.

However, this is not a Section 6.4 required hose station.

Page 47 of 50 j OPLP-O1 .2 Rev. 39

ATTACHMENT 6 Page 6of7 Sprinkler System I Isolation Valve Cross Reference Diesel Generator Building Sprinkler Systems DG Bldg. DG Bldg SPRINKLER DG Cell #4 Basement Basement DG Cell #1 DG Cell #2 DG Cell #3 SYSTEM South North V225 X V278 X V226 X V279 . X V227 X V280 X 0

V228 X V281 X Cl)

V284 X V285 X V283 X V286 X NOTES: 1. Reference drawing D-02303 Sheets 1 and 2

2. All valves prefixed 2-FP OPLP-O1 .2 Rev. 39 Page 48 of 50

ATTACHMENT 6 Page 7 of 7 Sprinkler System I Isolation Valve Cross Reference Control Building Sprinkler Systems SPRINKLER Unit 1 Cable Unit 2 Cable SYSTEM Spread Room Spread Room 1-FP-V140 X

> 1-FP-V451 X z

0 2-FP-V140 X 0

22 2-FP-V451 x NOTE: 1. Reference drawing D-02058 Sheet 3B OPLP-O1 .2 Rev. 39 Page 49 of 50

REVISION

SUMMARY

Revision 39 updated the references section to add Reference 2.9 (F-03897, Fire Detection System Block Diagram), added a general note regarding identification of fire detection and suppression systems that are monitored by the Edwards EST3 Fire Detection System per PRR 568985, and added a Records Section per PRR 569034.

Revision 38 incorporates EC 83141, which identifies new labels and minimum required instruments for AOG and Service Water Buildings instruments.

Revision 37 Incorporated change described in EC 50934 (PRR 490879). Attachment 5 revised to show existing Diesel Generator Fuel Oil Tank Area Foam System flame and heat detectors replaced with all heat detectors.

Revision 36 Incorporated change described in EC 50933 (PRR 473626). Attachment 5 revised to show existing Diesel Generator Air Filter Foam System flame and heat detectors replace with all heat detectors.

Revision 35 Incorporated editorial changes associated with procedure OPS-NGGC 1000 described in PRR 367926. Specifically, reference to 001-01 .08 was replaced with 001-01.01 in Section 2.8, 5.6 and 5.7. Added procedures 001-01.02 and OPS-NGGC 1000 to Section 2, References. Incorporated PRR 387555 editorial change in Section 5.5.1, changed Priority 5 CR to Action Request type IMPR. Incorporated PRR 429886 by adding Attachment 6, Sprinkler System I Isolation Valve Cross Reference. Also Revised Steps 6.5.1 and 6.8.1.1 to require operability at all times. Notes were added to (page 7) and Attachment 5.

Revision 34 Added procedure OFPP-005 and OFPP-030 to Section 2, References.

(PRR 282292) Revised Section 6.8.4 to state Control Room annunciation required for fire detection system operability. (PRR 327461) Added Section 6.2.4.3 to describe SBGT deluge system operability as dependent on SBGT temperature switch status.

(PRR5 315353 and 318199) Revised the title Shift Superintendent in Step 3.2 to Shift Manage?.

Revision 33 Incorporated EC50932 Diesel Generator Building Fire Detection Modification, by rewording Step 6.7.4, changing DG Detectors in Attachment 4, and adding DG Halon detectors to Attachment 4.

Revision 32 Incorporated PRR 265840 by changing Section 5.7 to clarify when fire watch is required and to direct personnel to review NEIL notification requirements.

Incorporated PRR 249728 by revising Section 6.3.1 to describe when HPCI C02 is required operable by reference to reactor mode.

Revision 31 Incorporates EC 65825 by updating ASTM standards to 2006 edition in Section 6.1.3.2b.

OPLP-01 .2 Rev. 39 Page 50 of 50