Text

Initial Exam 2011-302 Draft Simulator Scenarios 1 of 4
	ML12073A242
Person / Time
Site:	Watts Bar
Issue date:	04/29/2011
From:	; Operator Licensing and Human Performance Branch
To:	; Tennessee Valley Authority
References
	50-390/11-302
	Download: ML12073A242 (171)
	v • d • e

ppendix D Scenario Outline Form ES-D-1 Facility: Watts Bar October 2011 Scenario No. 1 Op Test No.: 2 Examiners: Operators: SRO RO BOP Initial Conditions: 100% power, BOL. RCS boron is 1031 ppm. Control Bank D is at 220 steps.

Turnover: Train A/Channel I Work Week. iA-A RHR Pump is out-of-service for motor winding inspection.

LCO 35.2 and 3.6.6 were entered 10 hours1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months ago. lA-A RHR pump is expected to be returned to service in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months . Protected equipment signs have been posted for 1 B-B RHR pump.

Event MaIf. No. Event Type* Event Description No.

1 rx26g C.. BOP 1-PT-i -27A, SG 4 STM PRESS fails low.

TS-SRO 2 rx07a l-RO 1-PT-68-340A, PZR PRESS fails high.

TS-SRO 3 cvO9 C-RO 1-LT-62-130 VCT LEVEL fails high.

4 rx24 1-BOP 1-PT-3-1 #1 HTR INLET PRESS fails low.

5 fwl6b N-BOP/SRO Intermediate Feedwater Heater B-4 develops a leak, causing the fw67b R-RO heater string to isolate.

6 fw23d M-ALL Feedwater line break inside containment on #4 SG ramps in to 100% over 2 minutes.

7 rpo2b C-RO Automatic safety injection fails to actuate.

8 edOl C-RO After the reactor trip a total loss of offsite power occurs. iA DG ego2a trips when started and the 1 B DG fails to automatically start.

siOSj 9 ms06a 100 M-ALL MSIVs fail in the open position. Requires transition from E-2, ms06b 100 Faulted Steam Generator Isolation, to ECA-2.1, Uncontrolled msO6c 100 Depressurization of All Steam Generators.

mso6d 100 (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Appendix D Watts Bar Examination October 2011 NUREG 1021 Revision 9

ppendix D Scenario Outline Form ES-D-1 Scenario I - Summary Initial Condition 100% power, BOL. RCS boron is 1031 ppm. Control Bank D is at 220 steps.

Turnover Train A/Channel I Work Week. lA-A RHR Pump is out-of-service for motor winding inspection. LCO 3.5.2 and 3.6.6 were entered 10 hours1.157407e-4 days 0.00278 hours 1.653439e-5 weeks 3.805e-6 months ago. lA-A RHR pump is expected to be returned to service in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months . Protected equipment signs have been posted for I B-B RHR pump.

Event 1 1-PT-i -27A, SG 4 STM PRESS fails low over 10 seconds. Requires manual control of SG 4 main feedwater regulating valve. Requires entry into AOl-i 6, Loss of Normal Feedwater, Section 3.5, Main FW Reg or Bypass Reg Valve Control Failure.Requires Tech Spec evaluation and entry into LCD 3.3.2 and 3.3.3.

Event 2 1-PT-68-340A, PZR PRESS fails high. Requires the RD to take IMMEDIATE OPERATOR ACTION to place 1-PIC-68-340A, PZR PRESS MASTER CONTROL in MANUAL and restore pressure to normal. Requires entry into AOl-i 8, Malfunction of Pressurizer Pressure Control System, Section 3.1, Pressure Transient Due to Instrument or Controller Malfunction. Requires a Tech Spec evaluation and entry into LCO 3.3.1, 3.3.2 for multiple Actions.

Event 3 1 -LT-62-i 30 VCT LEVEL fails high. Requires entry into ARI 109-A, VCT LEVEL Hl/LO. Requires the RD to place 1-LCV-62-1 18, LETDOWN DIVERT TO HUT in the VC TK position. RO uses ICS terminal to assist in the diagnosis of the VCT level transmitter failure.

Event 4 1-PT-3-1 #1 HTR INLET PRESS fails low. Requires the BOP to place 1-PC 20, MFPT A&B MASTER SPEED CONTROL in MANUAL to restore MFP AP to program. Requires entry into AOl-i 6, Requires entry into AOl-I 6, Loss of Normal Feedwater, Section 3.6, Failure Of MEW Pump Control. Requires manual operation for the duration of the scenario.

Event 5 Intermediate Eeedwater Heater B-4 develops a leak, causing the heater string to isolate. Requires entry into AOI-47, Heater Drains Malfunction. Requires a rapid plant shutdown using AOI-47 steps.

Event 6 Feedwater line break inside containment on #4 SG ramps in to 100% over 2 minutes causing a reactor trip and safety injection to occur.

Event 7 Automatic safety injection fails to actuate. RO must manually actuate using i-HS 63-1338 SI ACTUATE TRA & B on panel i-M-4 or 1-HS-63-133A SI ACTUATE TR A & B on panel 1-M-6.

Event 8 After the reactor trip a total loss of offsite power occurs. 1A DG trips when started and the 1 B DG fails to automatically start. Requires emergency start of the lB DG by the RO during the performance of IMMEDIATE OPERATOR ACTIONS.

Event 9 MSIVs fail in the open position. Requires transition from E-2, Faulted Steam Generator Isolation, to ECA-2.1, Uncontrolled Depressurization of All Steam Generators.

Appendix D Watts Bar Examination October 2011 NUREG 1021 Revision 9

ppendix D Scenario Outline Form ES-D-1J Scenario I - Critical Task Summary Critical Task 1 Energize at least one AC emergency bus before placing safeguards equipment handswitches in the stop, pull-to-lock position.

Critical Task 2 Manually actuate at least one train of safety injection before transition from E-O, Reactor Trip or Safety Injection.

Appendix D Watts Bar Examination October 2011 NUREG 1021 Revision 9

Watts Bar Nuclear Plant 10-2011 NRC Examination Scenario I Simulator Console Operators Instructions SIMULATOR SETUP INFORMATION ENSURE Examination Security has been established.

2. RESET to Initial Condition 300 by performing the following actions:

a. Select lCManager on the THUNDERBAR menu (right hand side of Instructor Console Screen).

b. Locate IC# 300.

c. Right click on lC# 300.

d. Select Reset on the drop down menu.

e. Right click on RESET.

f. Enter the password for IC 300.

g. Select Yes on the INITIAL CONDITION RESET pop-up window.

h. Perform SWITCH CHECK.

3. SELECT Director on the THUNDERBAR menu (right hand side of Instructor Console Screen).

4. ENSURE the following information appears on the Director Screen:

Key Description Type Event Delay Inserted Ramp Initial Final Value

[ rhl2 fail cnt sump to rhr pmp a fcv-63-72 to any position M 00:00:00 00:00:00 00:00:00 0 0 rhOla rhrpumpatrip M 00:00:00 00:00:00 00:00:00 Active Active rpo2b auto si initiation signal failure M 00:00:00 00:00:00 00:00:00 Active Active hs-74-1 Oa hs-74-1 Oa rhr pump a-a motor sw 0 00:00:00 00:00:00 00:00:00 ptlock ptlock hs-63-72a-1 01170 rhrpmp aa suctfrcntsmp(green) 0 00:00:00 00:00:00 00:00:00 0ff Off hs-74-10a-1 01230 hr pump a-a motor switch(green) 0 00:00:00 00:00:00 00:00:00 0ff Off hs-74-03a-1 01110 hr pump a-a suction(green) 0 00:00:00 00:00:00 00:00:00 0ff Off hs-74-03a hs-74-03a rhr pump a-a suction sw 0 00:00:00 00:00:00 00:00:00 close close Page 1 of 5

Watts Bar Nuclear Plant 10-2011 NRC Examination Scenario I Simulator Console Operators Instructions SIMULATOR SETUP INFORMATION Key Description Type Event Delay Inserted Ramp Initial Final Value IE ms06a msiv fails to close fcv-1-4 M 00:00:00 00:00:00 00:00:00 Active Active ms06b msiv fails to close fcv-l-1 1 M 00:00:00 00:00:00 00:00:00 Active Active mso6c msiv fails to close fcv-1-29 M 00:00:00 00:00:00 00:00:00 Active Active ms06d msiv fails to close fcv-1-22 M 00:00:00 00:00:00 00:00:00 Active Active ego2a diesel generator trip dg la-a M 00:00:00 00:00:00 00:00:00 Active Active si08j failure of auto si and blackout signals dg 1 b-b M 00:00:00 00:00:00 00:00:00 Active Active rx26g stm gen pres transmitter failure, chnl i pt-l-27a M 1 00:00:00 00:00:10 0 77.6592 edOl total loss of offsite power M 19 00:00:00 00:00:00 Active InActive rx07a pzr pressure transmitter fails to position chnl 1 68-340 M 2 00:00:00 00:00:00 100 66.8742 cvO9 vct level transmitter fails to position; 130-a M 3 00:00:00 00:00:00 100 31 .0205 rx24 feed water header pressure transmitter pt-3-1 fail to position M 4 00:00:00 00:00:00 0 75.539

, fwl 6b intermediate pressure heater tube failure b-4 M 5 00:00:00 00:00:00 100 0 fw67b lv htr isolation on htr b2 hi IvI switch 1-ls-6-43d failure M 5 00:00:00 00:00:00 100 0 fw23d main feed water break inside containment sg-4 M 6 00:00:00 00:00:00 50 0

5. Place simulator in RUN and acknowledge any alarms.

6. ENSURE I-HS-74-74-IOA RHR PMP A (ECCS) is in the STOP, PULL-TO-LOCK position with a RED Hold Order tag. RED Hold order tags are placed on I-HS-74-3A, RHR PMP A SUCTION and I-HS-63-72A, CNTMT SUMP TO RHR PMP A SUCT. A Pink PROTECTED EQUIPMENT TAG is hung on the lB RHR pump handswitch.

7. -

ENSURE the Train A Week Channel 1 sign is placed on 1-M-30.

8. Place simulator in FREEZE.

0. ENSURE Watts Bar Nuclear Plant Unit I Reactivity Briefing Book BOL (Beginning Of Life) is provided to the crew as part of the Turnover Package, and that the BOL placards are on I-M-6, below the Boric Acid and Primary Water Integrators.

10. WHEN prompted by the Chief Examiner, place the Simulator in RUN.

Page 2 of 5

Watts BarNuclear Plant 10-2011 NRC Examination Scenario I Simulator Console Operators Instructions Exam Simulator Event Event Description/Role Play No. No.

I I 1-PT-I -27A, SG 4 STM PRESS fails low.

ROLE PLAY: When contacted as Work Control, the Console Operator will acknowledge the request for a repair package for 1-PT-1-27A, SG 4 STM PRESS.

2 2 1-PT-68-340A, PZR PRESS fails high.

ROLE PLAY: When contacted as Work Control, repeat back request for removing 1-PT-68-340A, PZR PRESS channel from service.

ROLE PLAY: When contacted as Work Control, repeat back request for troubleshooting and repair package for 1-PT-68-340A, PZR PRESS.

3 3 1-LT-62-130 VCT LEVEL fails high.

ROLE PLAY: When dispatched to observe level on local 1-LT-62-130 VCT LEVEL, state that level is off-scale high.

ROLE PLAY: When contacted as Work Control, the Console Operator will acknowledge the request for a repair package for 1-LT-62-130, VCT Level.

ROLE PLAY: When dispatched to observe RCP Filter Al, wait 5 minutes and report that Al is indicating normally at 5 psid.

4 4 1-PT-3-1 #1 HTR INLET PRESS fails low.

ROLE PLAY: When contacted as Work Contro4 acknowledge the request for a repair package for 1-PT-3-1, #1 HTR INLET PRESS.

ROLE PLAY: If/when dispatched as the TB AUO, repeat back request to inspect 1-PT-3-1 for leaks.

Report back that there are no leaks visible.

Page3of5

Watts Bar Nuclear Plant 10-2011 NRC Examination Scenario I Simulator Console Operators Instructions Exam Simulator Event Event Description/Role Play No. No.

. 5 5 Intermediate Feedwater Heater B-4 develops a leak, causing the heater string to isolate.

ROLE PLAY: When dispatched to monitor heater levels, ensure that INSIGHT heater levels is OPEN to monitor levels in the feedwater heaters. Report heater levels as displayed.

ROLE PLAY: When contacted as Chemistry, repeat back request to perform power change sampling.

ROLE PLAY: When contacted as the Load Coordinator;, repeat back the information provided.

ROLE PLAY: When contacted as the AUO to open 1-lB V-5-501 HTR B4 EXTR STM INLET 1-FCV 62, the Console Operator will repeat back the request.

ROLE PLAY: When contacted as Work Control to request a troubleshooting and repair package for the intermediate feedwater heaters, repeat back the information.

6-9 n/a Feedwater line break inside containment on #4 SG, and MSIVs fail to close ROLE PLAY: When contacted as an AUO to place the MSlVhandswitches in the AUX position in the Aux Control Room, the console operator will enter remote function msr26. These actions are contained in E-2, Attachment 1.

ROLE PLAY: ECA-2. I Appendix A will be requested later which contains the same actions. After entering msr26, contact the BOP and state that the switches have been transferred. The BOP may then request that fuses for the MSIVs be pulled.

ROLE PLAY: If AUO dispatch to close #1 FW Htr outlet valves, Console operator will acknowledge the request.

ROLE PLAY: When contacted as an AUO to perform Attachment I of E-O, wait 5 minutes and report back that power has been removed from all Ice Condenser Air Handling units.

ROLE PLAY: When contacted as an AUO to perform shutdown Upper and Lower CNTMT rad monitors in E-O, wait 5 minutes and report back that Upper and Lower CNTMT rad monitors have been shutdown.

Page4of5

Watts BarNuclear Plant 10-2011 NRC Examination Scenario I Simulator Console Operators Instructions Exam Simulator Event Event DescriptionlRole Play No. No.

ROLE PLAY: If contacted as an AUO to perform Attachment 4 of E-0, wait 10 minutes and report back that Attachment 4 is complete.

ROLE PLAY: When contacted as the Shift Manager to evaluate EPIP-1, repeat back the information.

ROLE PLAY: If contacted as Chemistry, repeat back the request to sample SGs for activity. Wait 10 minutes, then report back that activity is normal.

ROLE PLAY: If contacted as Rad Protection, repeat back the request to perform surveys of the secondary plant. Wait 10 minutes and report back that there are no indications of abnormal radiation levels.

ROLE PLAY: When dispatched as an AUO to perform Appendix B of ECA-2.1, CLA Breaker Operation, input remote sirOl and report back that Appendix B of ECA-2. I is complete.

ROLE PLAY: When contacted as an AUO, repeat back request to inspect the IA DG since it failed to start. Report back that the IA DG (generator) has been damaged. There is smoke in the building, but no fire.

Page 5 of 5

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario # 1 Event # 1 Page 1 of 30 Event

Description:

1-PT-i-27A, SC 4 STM PRESS fails low over 10 seconds. Requires manual control of 1-FCV-3-103 SC 4 MEW REG VLV. Requires entry into AOl-16, Loss of Normal Feedwater, Section 3.5, Main EW Reg or Bypass Reg Valve Control Failure.

Requires Tech Spec evaluation.

Time Position Applicants Actions or Behavior Indications:

58-B SC FEEDWATER FLOW HI 63-C SG 4 STM-FW FLOW MISMATCH 63-F SG LEVEL DEVIATION 123-A SC 4 PRESS NEG RATE 119-ASG PRESS LO 1-FCV-3-103 SG 4 MFW REG VLV indicates valve is closing BOP Diagnoses and announces the failure of 1-PT-I -27A, SC 4 STM PRESS low.

May place I-FIC-3-103 SG 4 MFW REG VLV in MANUAL to BOP -

stabilize SG level.

May place I-PC-46-20, MFPT A & B MASTER SPEED CONTROL in BOP MANUAL to stabilize MFW pump speed.

Enters and directs actions of AOl-i 6, Loss of Normal Feedwater, SRO Section 3.5, Main FW Reg or Bypass Reg Valve Control Failure.

The following actions are taken from Aol-I 6, Loss of Normal AOI-16 Feedwater, Section 3.5, Main FW Reg or Bypass Reg Valve Control Failure.

1. CONTROL failed MFW reg or bypass reg valve in MANUAL to maintain S/G level.

BOP places 1-FIC-3-103 SG 4 MFWREG VLV1n MANUAL by BOP lifting the toggle switch up from the AUTO position to the MANUAL position.

BOP matches steam and feedwater flow to SG 4 by moving the toggle switch to the right.

2. EVALUATE placing control rods in MANUAL.

SRO SRO may direct RO to place 1-RBSS ROD BANK SELECT in MANUAL.

3. CHECK MEW pumps recirc valves CLOSED.

BOP BOP checks 1-FIC-3-70 MFWP A RECIRC CONTROL and 1-FIC-3-84 MFWP B RECIRC CONTROL CLOSED by observing valve position demand indications.

NOTES

Bypass reg. valve may be manually positioned upto 0.85 x 106 lb/hr flow to dampen oscillations in feedwater flow in loop of affected main reg valve.

A power tilt in the affected core quadrant may occur due to arise in bypass flow. Flows above 84,500 Ibm/hr in the bypass line will invalidate the value of computer point Ui 118.

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: 2 Scenario # 1 Event # 1 Page 2 of 30 Event

Description:

1-PT-i -27A, SG 4 STM PRESS fails low over 10 seconds. Requires manual control of 1-FCV-3-103 SG 4 MEW REG VLV. Requires entry into AOl-16, Loss of Normal Feedwater, Section 3.5, Main FW Reg or Bypass Reg Valve Control Failure.

Requires Tech Spec evaluation.

Time Position Applicants Actions or Behavior

4. CHECK SG levels on bypass reg valve control.

GO TO Step 6.

BOP BOP determines that the bypass valves are in MANUAL and that this step is N/A.

6. CHECK SIG levels returning to PROGRAM.

BOP BOP determines that SG levels are returning to program by observing trend on 1-FR-3-103, SG 4.

BOP 7. MONITOR TDMFW Pump speed normal for current power level.

7. RESPONSE NOT OBTAINED:

PLACE TDMFW Pump Master Speed Control to MANUAL, THEN ADJUST speed as necessary.

BOP places 1-PC-46-20, MFPTA & B MASTER SPEED CONTROL in MANUAL by lifting the toggle switch from the AUTO position, and then moving to the right to raise MFP IA and lB speed.

NOTE A LO FW FLOW WTR HAMMER annunciation [59-C) will be received when any main feedwater flow drops to less than 0.75 x 106 lb/hr.

BOP 8. CHECK ALL S/G MEW flows greater than 0.55 x 106 lb/hr.

CAUTION Power range N41 controls SIG I and SIG 4 MFW reg valves. Power range N42 controls SIG 2 and SIG 3 MFW reg valves.

NOTE All power range monitors input to auctioneered high anticipatory circuit for bypass EW reg valves.

9. CHECK power range N41 through N44 NORMAL.

RO observes NIS Power Range channels on panel l-M-4 and RO determines from I-Nl-41B, PR FLUX % POWER, l-Nl-42B, PR FLUX % POWER, 1-Nl-43B, PR FLUX % POWERI-Nl-44B, PR FLUX % POWER that NIS power range all indicate the same power and are normal.

NOTE Steps 10 & 11 should end up having the same channel (A or B) selected for steam flow and feed flow on each S/G to ensure a loss of voltage to any one channel will have minimal effect on the affected S/G level.

10. CHECK controlling steam flow Channels NORMAL.

BOP BOP observes that I-Fl-1-28A SG 4 STEAM FLOW is indicating off-scale low.

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario # 1 Event # 1 Page 3 of 30 Event

Description:

1-PT-i -27A, SG 4 STM PRESS fails low over 10 seconds. Requires manual control of 1-FCV-3-i03 SG 4 MFW REG VLV. Requires entry into Aol-i 6, Loss of Normal Feedwater, Section 3.5, Main FW Reg or Bypass Reg Valve Control Failure.

ReQuires Tech Spec evaluation.

Time Position N Applicants Actions or Behavior

10. RESPONSE NOT OBTAINED:

a. SELECT operable channel.

BOP rotates 1-XS-1-28D, SG 4 STM FLOW CONTROL CHANNEL SELECT from Fl-1-28A position to the right to the 1-Fl-1-28B position.

b. EVALUATE effect of the failed channel on the MFPs Speed BOP Control and ADJUST in MANUAL as necessary while continuing this section.

BOP determines a steam flow input to the MFP speed control circuit is failed and that both MFPs are reducing speed.

The BOP may have already placed the 1-PC-46-20, TDMFW Pump Master Speed Controller in MANUAL and may make adjustments to raise speed.

1. CHECK controlling FW flow channels NORMAL.

BOP BOP observes that FW flow channels are normal.

12. CHECK press compensation channel(s) NORMAL.

BOP BOP observes that 1-PI-1-27A SG 4 PRESS is indicating off-scale low.

12. RESPONSE NOT OBTAINED:

REFER TO Tech Specs:

3.3.2, Engineered Safety Feature Actuation System (ESFAS)

Instrumentation.

Function 1.e, Safety Injection Steam Line Pressure Low, -

Condition D, With one channel inoperable, place the channel in trip within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR be in Mode 3 within 78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months AND be in Mode 4 in 84 hours9.722222e-4 days 0.0233 hours 1.388889e-4 weeks 3.1962e-5 months .

SRO Function 4.d. 1, Steamline Isolation, Condition D, With one channel inoperable, place the channel in trip within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR be in Mode 3 within 78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months AND be in Mode 4 in 84 hours9.722222e-4 days 0.0233 hours 1.388889e-4 weeks 3.1962e-5 months .

3.3.3, Post Accident Monitoring (PAM) Instrumentation.

Function 24, SG Pressure, Condition A. With one or more Functions with one required channel inoperable, restore the required channel to OPERABLE status within 30 days.

3.3.4, Remote Shutdown System.

13. ENSURE same channel (A or B) selected for steam flow and feed flow on each SIG.

BOP BOP ensures that the B channel for steam flow and feedwater flow inputs to the SGWLC circuits are selected.

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: 2 Scenario# 1 Event# 1 Page 4 of 30 Event

Description:

1-PT-1-27A, SG 4 STM PRESS fails low over 10 seconds. Requires manual control of 1-FCV-3-103 SG 4 MEW REG VLV. Requires entry into AOl-i 6, Loss of Normal Feedwater, Section 3.5, Main EW Reg or Bypass Reg Valve Control Failure.

Requires Tech Spec evaluation.

Time Position Applicants Actions or Behavior

14. IF affected SIG controlling channel and level NORMAL, THEN

a. RETURN MFW reg valve to AUTO.

Returns 1-FIC-3-103, SG 4- REG VLV to AUTO after balancing input signals. Automatic is selected by lowering the toggle switch from the MANUAL position to the AUTO position.

BOP

b. RETURN TDMFWP Speed Control to AUTO (if in MANUAL).

If placed in MANUAL, the BOP returns 1-PC-46-20, TDMFW Pump Master Speed Controller to AUTO after balancing input signals. Automatic is selected by lowering the toggle switch from the MANUAL position to the AUTO position.

15. WHEN conditions allow auto rod control, THEN

a. (p) ENSURE T-avg and T-ref within I F.

b. ENSURE zero demand on control rod position indication SRO [1 -M-4.

c. PLACE rods in AUTO.

After adjusting control rods to match Tavg and Tref within 1°F, RO places 1-RBSS ROD BANK SELECT in AUTO.

16. INITIATE repairs to failed equipment.

SRO When contacted as Work Controi the Console Operator will acknowledge the request for a repair package for 1-PT-1-27A, SC 4 STM PRESS.

SRO 17. RETURN TO Instruction in effect.

EXAMINER: The crew briefing is optional. The next event may be entered prior to the brief.

Crew Brief would typically be conducted for this event as time SRO allows prior to the next event.

Notifications should be addressed as applicable if not specifically addressed by the procedure or in the crew brief.

Operations Management Typically Shift Manager.

SRO Maintenance Personnel Typically Work Control Center (WCC).

(Note: Maintenance notification may be delegated to the Shift Manager).

Cue Console Operator to insert Event 2, if not previously inserted.

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario # 1 Event # 2 Page 5 of 30 Event

Description:

1-PT-68-340A, PZR PRESS fails high. Requires the RO to take IMMEDIATE OPERATOR ACTION to place 1-PIC-68-340A, PZR PRESS MASTER CONTROL in MANUAL and restore pressure to normal. Requires entry into AOl-18, Malfunction of Pressurizer Pressure Control System, Sub section 3.1, Pressure Transient Due to Instrument or Controller Malfunction. Requires a Tech Spec evaluation.

Time Position Applicants Actions or Behavior Indications:

90-A, PZR PRESS HI 124-B PZR PRESS HI Will perform IMMEDIATE ACTION step of AOl-i 8, Malfunction of Pressurizer Pressure Control System, Section 3.1, Pressure RO transient due to Instrument or Controller Malfunction. to PLACE PZR master controller 1-PIC-68-340A in MANUAL and RESTORE press to normal.

Enters and direct actions of AOl-i 8, Malfunction of Pressurizer SRO Pressure Control System, Section 3.1, Pressure transient due to Instrument or Controller Malfunction.

The following actions are taken from AOl-I 8, Malfunction of AOI-18 Pressurizer Pressure Control System, Section 3.1, Pressure transient due to Instrument or Controller Malfunction.

NOTE Step 1 is an IMMEDIATE ACTION step.

1. CHECK PZR pressure STABLE or TRENDING to desired pressure:

RO 1-Pi-68-340A pressure indicator will be indicating 2500 psig, and the remaining pressure indicators will indicate pressure.

dropping.

1. RESPONSE NOT OBTAINED:

PLACE PZR master controller 1 -PIC-68-340A in MANUAL and RESTORE press to normal.

These actions may have already been taken by the RO to stabilize PZR pressure.

Places 1-PIC-68-340A, PZR PRESS MASTER CONTROL in RO MANUAL by lifting the toggle switch up from the AUTO position to the MANUAL position.

Since the failure caused the controller output to lower in AUTO, the output must be raised by moving the toggle switch to the left and observing pressure response.

IF PZR pressure drop due failed PORV!Safety or Spray valve, THEN **GO TO Section 3.2.

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: 2 Scenario # 1 Event # 2 Page 6 of 30 Event

Description:

1-PT-68-340A, PZR PRESS fails high. Requires the RO to take IMMEDIATE OPERATOR ACTION to place 1-PIC-68-340A, PZR PRESS MASTER CONTROL in MANUAL and restore pressure to normal. Requires entry into AOI-18, Malfunction of Pressurizer Pressure Control System, Sub section 3.1, Pressure Transient Due to Instrument or Controller Malfunction. Requires a Tech Spec evaluation.

Time Position Applicants Actions or Behavior

2. ENSURE 1-XS-68-340D selected to OPERABLE channels for control and backup:

PT-68-340 & 334 OR

PT-68-334 & 323 RO OR

PT-68-340 & 322 RO determines that 1-XS-68-340D is selected to the PT-68-340 &

334 position, and that 1-PT-68-340 has failed.

RO selects PT-68-334 B323 position on 1-XS-68-340D, PZR PRESS CONTROL CHANNEL SELECT.

3. CHECK PZR press STABLE or RISING.

RO RO checks PZR press STABLE or RISING.

4. DETERMINE if PZR heaters and sprays are operating properly:

RO a. CHECK master control controlling sprays and heaters.

b. CHECK PZR press greater than 2250 psig.

4.b. RESPONSE NOT OBTAINED:

RO WHEN PZR press is greater than 2250 psig, THEN PERFORM Step 4.c.

c. ENSURE all PZR heaters OFF

d. ENSURE PZR sprays maintain RCS press on program.

RO RO verifies PZR heaters and sprays responding properly to manual control of PZR press master controller.

5. ENSURE operable channel selected for recording with RO 1-XS-68-340B.

Selector switch 1-XS-68-340B does not have to be repositioned.

6. ENSURE TR-68-2A placed to operable channel using 1-XS-68-2B, AT RCDR TR-68-2A LOOP SELECT [1-M-5j.

RO Selector switch 1-XS-68-2B must be moved from the Loop I position to any other Loop position.

7. CHECK PZR level at or trending to PROGRAM.

RO RO CHECKS PZR level is on program.

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario# 1 Event# 2 Page 7 of 30 Event

Description:

i-PT-68-340A, PZR PRESS fails high. Requires the RO to take IMMEDIATE OPERATOR ACTION to place i-PIC-68-340A, PZR PRESS MASTER CONTROL in MANUAL and restore pressure to normal. Requires entry into Aol-i 8, Malfunction of Pressurizer Pressure Control System, Sub section 3.1, Pressure Transient Due to Instrument or Controller Malfunction. Requires a Tech Spec evaluation.

Time Position Applicants Actions or Behavior

8. NOTIFY Work Control to remove any failed channel from service and repair any failed controllers.

SRO SRO contacts Work Control and Console Operator repeats back request for removing 1-PT-68-340A, PZR PRESS channel from service.

9. WHEN pressurizer pressure stable and equipment status supports returned to normal, THEN ENSURE the following in AUTO:

PZR Master controller

PZR spray controllers

All heater groups SRO RO will stabilize RCS pressure, then request permission to return 1-PIC-68-340A to AUTO.

Returns 1-PIC-68-340A, PZR PRESS MASTER CONTROL to AUTO. Automatic is selected by lowering the toggle switch from the MANUAL position to the AUTO position.

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario # 1 Event # 2 Page 8 of 30 Event

Description:

1-PT-68-340A, PZR PRESS fails high. Requires the RO to take IMMEDIATE OPERATOR ACTION to place 1-PIC-68-340A, PZR PRESS MASTER CONTROL in MANUAL and restore pressure to normal. Requires entry into AOI-18, Malfunction of Pressurizer Pressure Control System, Sub section 3.1, Pressure Transient Due to Instrument or Controller Malfunction. Requires a Tech Spec evaluation.

Time N Position N Applicants Actions or Behavior

10. REFER TO the following Tech Specs:

a. 3.3.1, RTS Instrumentation.

Function 6, OTT, Condition W, With one channel inoperable, place the channel in trip within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR be in Mode 3 within 78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months .

Function 8.a, Low Pressure, Condition X, With one channel inoperable, place the channel in trip within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR reduce THERMAL POWER to <P-7 within 78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months .

Function 8.b, High Pressure, Condition W (see above).

b. 3.3.2, Engineered Safety Feature Actuation System (ESFAS)

Instrumentation.

Function 1.d, Pressurizer Pressure Low, Condition D, With one channel inoperable, place the channel in trip within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR be in Mode 3 within 78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months AND be in Mode 4 in 84 hours9.722222e-4 days 0.0233 hours 1.388889e-4 weeks 3.1962e-5 months .

Function 8.b, P-Il, SRO (1) Unblock (Auto Reset of SI Block)

(2) Enable Manual Block of SI Condition L, With one P-Il interlock channel inoperable, verify the interlock is in required state for existing unit conditions OR be in Mode 3 in 7 hours8.101852e-5 days 0.00194 hours 1.157407e-5 weeks 2.6635e-6 months AND be in Mode 4 in 13 hours1.50463e-4 days 0.00361 hours 2.149471e-5 weeks 4.9465e-6 months .

c. 3.3.4, Remote Shutdown System. Not Applicable

d. 3.4.1, RCS Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits.

Applicable if the initial transient caused a pressure drop to less than 2214 psig.

e. 3.4.3, RCS Pressure and Temperature (PIT) Limits. Not Applicable

f. 3.4.9, Pressurizer. Not Applicable

g. 3.4.10, Pressurizer Safety Valves. NotApplicable

h. 3.4.11, Pressurizer Power Operated Relief Valves. Not Applicable 1 1. INITIATE repairs to failed equipment.

SRO When contacted as Work Control the Console Operator will repeat back request to prepare a package to troubleshoot and repair 1-PT-68-340A.

SRO 12. RETURN TO Instruction in effect.

EXAMINER: The crew briefing is optional. The next event may be entered prior to the brief.

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: 2 Scenario # 1 Event # 2 Page 9 of 30 Event

Description:

1-PT-68-340A, PZR PRESS fails high. Requires the RO to take IMMEDIATE OPERATOR ACTION to place 1-PIC-68-340A, PZR PRESS MASTER CONTROL in MANUAL and restore pressure to normal. Requires entry into AOI-18, Malfunction of Pressurizer Pressure Control System, Sub section 3.1, Pressure Transient Due to Instrument or Controller Malfunction. Requires a Tech Spec evaluation.

Time Position Applicants Actions or Behavior Crew Brief would typically be conducted for this event as time allows SRO prior to the next event.

Notifications should be addressed as applicable if not specifically addressed by the procedure or in the crew brief.

Operations Management Typically Shift Manager.

SRO Maintenance Personnel Typically Work Control Center (WCC).

(Note: Maintenance notification may be delegated to the Shift Manager).

Cue Console Operator to insert Event 3, if not already entered.

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: 2 Scenario# 1 Event# 3 Page 10 of 30 Event

Description:

1-LT-62-130 VCT LEVEL fails high. Requires entry into ARI 109-A, VCT LEVEL HI/LO. Requires the RO to place 1-LCV-62-1 18, LETDOWN DIVERT TO HUT in the VC TK position.

L Time Position Applicants Actions or Behavior Indications:

109-A, VCT LEVEL HI/LO 1-HS-62-118A, LETDOWN DIVERT TO HUT RED indicating light below the HUT label LIT 1 -LI-62-1 29, VCT LEVEL indication slowly dropping.

RO Diagnoses and announces failure of 1-LT-62-130, VCT LEVEL.

May place 1-HS-62-1 18A in the VC TK position to stop VCT level RO from dropping.

RO Performs actions of ARI 109-A, VCT LEVEL HI/LO.

SRO May enter and direct actions of ARI 109-A, VCT LEVEL HI/LO.

The following actions are taken from ARI 109-A, VCT LEVEL HIILO.

CAUTIONS

1) If either VCT level transmitter fails high, then auto swap over to RWST on low level is disabled.

2) 1 -LT-62-1 29A failing high will divert letdown flow but will NOT prevent auto makeup. 1 -LI 129 will indicate offscale high; however computer point LOl 1 2A will indicate actual level.

3) 1 -LT-62-1 30A failing high will divert letdown and prevent auto makeup, however, I -Ll-62-1 29 will indicate actual level.

[1] IF high level, THEN:

[1.1] ENSURE 1-LCV-62-118 diverted to HUT and OPEN.

RO [1.2] ENSURE NO VCT makeup in progress.

RO determines from the RED indicating light for the HUT is LIT on 1-HS-62-118A, LETDOWN DIVERT TO HUT that letdown is diverted to the HUT.

[2] IF low level, THEN:

ENSURE 1-LCV-62-118 aligned to VCT.

INITIATE makeup in accordance with SOl-62.02, BORON RO CONCENTRATION CONTROL.

ENSURE suction to the Centrifugal Charging Pump swaps over to the RWST at 7% VCT level.

Level is failed high, so step is N/A.

[3] VERIFY letdown and charging in service and that Reactor RO Coolant Filter is NOT clogged.

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario # 1 Event # 3 Page 11 of 30 Event

Description:

1-LT-62-130 VCT LEVEL fails high. Requires entry into ARI 109-A, VCT LEVEL HI/LO. Requires the ROto place 1-LCV-62-118, LETDOWN DIVERT TO HUT in the °VC TK position.

L Time Position Applicants Actions or Behavior

[4] IF 1-LCV-62-1 18 diverted to HUT due to instrument failure, THEN:

[4.1] PLACE 1-HS-62-118 in VCT position until repairs complete.

RO rotates 1-HS-62-118, LETDOWN DIVERT TO HUT to the left to the VC TK position, and observes the RED indicating light RO for the VCT is LIT and the RED indicating for the HUT is DARK.

[4.2] PLACE 1 -HS-62-1 18 in P-AUTO position once repairs completed.

1-HS-62-118, LETDOWN DIVERT TO HUT will be maintained in the VCT position for the duration of the scenario.

[5] IF RCS leakage is suspected, THEN GO TO AOl-6, SMALL RO REACTOR COOLANT SYSTEM LEAK.

Leakage is not indicated, so this step is N/A.

EXAMINER: The crew briefing is optional. The next event may be entered prior to the brief.

Crew Brief would typically be conducted for this event as time SRO allows prior to the next event.

Notifications should be addressed as applicable if not specifically addressed by the procedure or in the crew brief.

SRO Operations Management Typically Shift Manager.

Maintenance Personnel Typically Work Control Center (WCC).

(Note: Maintenance notification may be delegated to the Shift Manager).

Cue Console Operator to insert Event 4, if not already entered.

2011-10 Watts Bar NRC Examination

I Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario # 1 Event # 4 Page 12 of 30 Event

Description:

1-PT-3-1 #1 HTR INLET PRESS fails low. Requires the BOP to place 1-PC-46-.20, MFPT A&B MASTER SPEED CONTROL in MANUAL to restore MFP zP to program. Requires entry into AOl-i 6, Requires entry into AOl-16, Loss of Normal Feedwater, Section 3.6, MEW pump speed control circuit failure. Requires manual operation for the duration of the scenario Time Position Applicants Actions or Behavior .

Indications:

57-B #1 FW HTR INLET SUPPLY PRESS HI 63-E SG LEVEL DEVIATION 1-PI-3-1 #1 HTR INLET PRESS dropping 1-Sl-46-20A MEPT A SPEED rising 1-Sl-46-20B MFPT B SPEED rising ALL Main Feedwater Reg valves closing Diagnoses and announces the failure of 1-PT-3-1, #1 HTR INLET BOP PRESS low.

BOP may place 1-PC-46-20, MEPT A & B MASTER SPEED BOP CONTROL, in MANUAL and lower MFPT speed.

Enters and directs actions of AOl-i 6, Loss of Normal Feedwater, Section 3.6, MEW pump speed control circuit failure.

The following actions are taken from Aol-I 6, Loss of Normal Feedwater, Section 3.6, MFW pump speed control circuit failure.

1. CONTROL MFP speed using MANUAL control of master controller or individual controller(s) as required.

BOP BOP places 1-PC-46-20, MFPTA & B MASTER SPEED CONTROL in MANUAL by lifting the toggle switch from the AUTO position, and then move to the left to lower MFP IA and lB speed

2. PLACE control rods in MANUAL.

SRO SRO directs the RO to place I-RBSS ROD BANK SELECT in MANUAL.

3. CHECK MEW pumps recirc valves CLOSED.

BOP BOP checks I-FIC-3-70 MFWP A RECIRC CONTROL and 1-FIC-3-84 MFWP B RECIRC CONTROL CLOSED by observing valve position demand indications.

4. (p) ENSURE T-avg and T-ref within 3°.

BOP RO observes Tref-Auct Tavg on I-TR-68-2B and determines that Auct T-avg and T-ref are within 3°F.

5. MAINTAIN MEWP discharge press on PROGRAM.

BOP BOP may adjust l-PC-46-20, MFPTA & B MASTER SPEED CONTROL in MANUAL to return MFWP discharge pressure to program (I-FC-46-20 provides program.)

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario# 1 Event# 4 Page 13 of 30 Event

Description:

1-PT-3-1 #1 HTR INLET PRESS fails low. Requires the BOP to place 1-PC.46-20, MFPT A&B MASTER SPEED CONTROL in MANUAL to restore MFP AP to program. Requires entry into AOl-i 6, Requires entry into AOl-16, Loss of Normal Feedwater, Section 3.6, MEW pump speed control circuit failure. Requires manual operation for the duration of the scenario Time Position Applicants Actions or Behavior

6. ENSURE SIG levels return to PROGRAM.

BOP BOP observes SG I through SG 4 levels on 1-M-4 instruments and determines that levels are returning to normal.

7. CHECK steam dump mode in TAVG position.

BOP BOP determines that I-HS-I-103D STEAM DUMP MODE is in the T A VG position.

8. INITIATE repairs to failed equipment.

SRO When contacted as Work Control, the Console Operator will acknowledge the request for a repair package for I-PT-3-I,

1 HTR INLET PRESS.

9. WHEN conditions allow auto rod control, THEN

a. (p) ENSURE T-avg and T-ref within 1°F.

RO observes T-avg and T-ref within I F on I-TR-68-2B, TREF &

AUCT TAVG °F. -

b. ENSURE zero demand on control rod position indication

[1-M-4].

SRO RO observes that there is a zero demand indicated on the PASSIVE SUMMER ROD DEMAND on both CERPI displays.

c. PLACE rods in AUTO.

RO rotates 1-RBSS from the MANUAL position to the right to the AUTO position.

10. WHEN MFP pump control repairs completed, THEN PLACE MFP speed control in AUTO.

SRO SRO determines that I-PC-46-20, MFPTA & B MASTER SPEED CONTROL must remain in MANUAL.

11. RETURN TO Instruction in effect.

BOP SRO determines that the procedure section will remain open until repairs are complete.

EXAMINER: The crew briefing is optional. The next event may be entered prior to the brief.

Crew Brief would typically be conducted for this event as time SRO allows prior to the next event.

Notifications should be addressed as applicable if not specifically addressed by the procedure or in the crew brief.

Operations Management Typically Shift Manager.

SRO Maintenance Personnel Typically Work Control Center (WCC).

(Note: Maintenance notification may be delegated to the Shift Manager).

2011-10 Watts Bar NRC Examination

[pppendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario # 1 Event # 4 Page 14 of 30 Event

Description:

1-PT-3-1 #1 HTR INLET PRESS fails low. Requires the BOP to place 1-PC46-20, MFPT A&B MASTER SPEED CONTROL in MANUAL to restore MFP P to program. Requires entry into AOl-i 6, Requires entry into AOl 16, Loss of Normal Feedwater, Section 3.6, MFW pump speed control circuit failure. Requires manual operation for the duration of the scenario Time Position Applicants Actions or Behavior Cue Console Operator to insert Event 5, if not previously inserted.

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario # I Event # 5 Page 15 of 30 Event

Description:

Intermediate Feedwater Heater B4 develops a leak, causing the heater string to isolate. Requires entry into AOl-47, Heater Drains Malfunction. Requires a rapid plant shutdown using AOl-47 steps.

Time Position Applicants Actions or Behavior Indications:

36-B HEATER A2 LEVEL HI/LO 37-A HP HEATER 81 LEVEL HI/LO 37-C HEATER B-4 LEVEL HI/LO 38-B HEATER C2 LEVEL HI/LO 63-F SG LEVEL DEVIATION BOP Diagnoses and announces B4 heater level high.

Diagnoses and announces the isolation of the B string of BOP intermediate pressure heaters.

BOP May dispatch AUO to investigate B4 heater level.

Enters and directs actions of AOl-47, Heater Drains Malfunctions, SRO Section 3.2, Intermediate Heater String Isolation Above 76%

Power.

ARI 37-C The following actions are taken from ARI 37-C HEATER B-4 LEVEL HIILO.

CAUTION Intermediate Heater String Isolation above 76% power may result in unit trip if actions of AOI-47 are not performed promptly.

NOTE Heater B2, 83 and B4 isolation will occur if level reaches 34 above normal for 5 seconds, as seen by 1-LS-6-147D. If this occurs, Condensate inlet to 84 heater and outlet from B2 will close, extraction steam isolation valves to B2, 83 and B4 heaters will close and the extraction steam non-return valve to all #2, all #3 and B4 heaters will unload. Level control valve from 81 heater to B2 will close and #3 heater drain pumps discharge valve to B2 heater will close.

[1] IF heater string isolation occurs above 76% power, THEN SRO IMMEDIATELY GO TO AOI-47, Heater Drain Malfunction.

AOI-47 The following actions are taken from AOl-47, Heater Drains Malfunction, Section 3.2, Intermediate Heater String Isolation Above 76% Power.

CAUTION

The Standby Main Feed Pump (SBMFP) should be removed from service as soon as practicable to preclude MFP suction pressure dropping below 250 psig (with no operator action this could occur in as little as 1.5 minutes).

Unit load should be lowered without delay due to the potential loss of all normal feedwater upon automatic isolation of the remaining heater strings.

2011-10 Watts Bar NRC Examination

Lppendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario # 1 Event# 5 Page 16 of 30 Event

Description:

Intermediate Feedwater Heater B4 develops a leak, causing the heater string to isolate. Requires entry into AOl-47, Heater Drains Malfunction. Requires a rapid plant shutdown using AOl-47 steps.

Time I Position Applicants Actions or Behavior

1. ENSURE affected heater string isolation complete.

Condensate inlet isolation valve CLOSED BOP observes that 1-HS-2-130A B4 HEATER INLET is CLOSED by RED indicating light DARK and GREEN indicating light is LIT.

Condensate outlet isolation valve CLOSED BOP observes that 1-HS-2-147A B2 HEATER OUTLET is BOP CLOSED by RED indicating light DARK and GREEN indicating light is LIT.

Extraction steam isolation valve CLOSED.

BOP observes that 1-HS-5-32A HEATER B2 EXTRACTiON STM, 1-HS-5-42A B3 HEATER EXTRACTION STM, and 1-HS-5-62A, B4 HEATER EXTRACTION STM, are CLOSED by RED indicating lights DARK and GREEN indicating lights is LIT.

2. MONITOR that ONLY ONE heater string isolation, has been initiated.

BOP BOP observes that the A and C intermediate heater strings remain in service.

3. CHECK both MFPs in operation.

BOP BOP observes that both MFPs are in service.

4. VERIFY SBMFP shutdown.

BOP BOP observes that the SBMFP was not in service.

NOTE Condenser Backpressure limits may be displayed on ICS, turn-on code AOll 1.

2011-10 Watts Bar NRC Examination

I Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario# I Event# 5 Page 17 of 30 Event

Description:

Intermediate Feedwater Heater 34 develops a leak, causing the heater string to isolate. Requires entry into AOl-47, Heater Drains Malfunction. Requires a rapid plant shutdown using AOl-47 steps.

Time N Position N Applicants Actions or Behavior

5. ESTABLISH a turbine load reduction, to less than or equal to 76%

power, at a rate greater than or equal to 2%/rn in, and less than 5%/mm:

a. PLACE turbine in IMP IN.

BOP depressed the IMP IN pushbutton and observes the transfer from IMP OUT to IMP IN control complete.

b. SET a desired load in the SETTER with the REFERENCE CONTROL.

BOP depresses the reference control V (down) button to BOP reduce the setter display to less than 76% load as directed by the SRO.

c. SET the LOAD RATE at greater than or equal to 2%/mm, and less than 5%/mm.

BOP selects the load reduction rate directed by the SRO using the LOAD RATE % PER MIN thumbwheel selector. It is expected that a load reduction rate of 2-4%/minute will be used.

d. DEPRESS GO pushbutton.

BOP depresses the REFERENCE CONTROL GO button.

EXAMINER: A copy of the Reactivity Briefing Sheet which addresses the boration flow rate and volume is contained in Attachment 1.

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ESD-2 Op Test No.: 2 Scenario # I Event # 5 Page 18 of 30 Event

Description:

Intermediate Feedwater Heater B4 develops a leak, causing the heater string to isolate. Requires entry into AOl-47, Heater Drains Malfunction. Requires a rapid plant shutdown using AOl-47 steps.

Time Position Applicants Actions or Behavior

6. INITIATE a manual boration:

a. DETERMINE recommended boration flow rate and volume from Reactivity Briefing Sheet:

RO determines the recommended boration flow rate to be 40 gpm and the volume to add to be 369 gallons of boron.

b. INITIATE normal boration:

1) ADJUST BA flow controller, I -FC-62-1 39, to desired flow rate.

RO adjusts 1-FC-62-139 to the value corresponding to the flow rate for the selected load reduction rate.

2) ADJUST BA batch counter I -FQ-62-1 39 to required quantity.

RO adjusts 1-FQ-62-139 BA BATCH COUNTER as follows:

1. Depresses and holds the black pushbutton.

RO 2. While holding the pushbutton, the applicant raises the red translucent cover.

3. While still holding the pushbutton, the applicant enters 000369 in the display.

4. While still holding the pushbutton, the applicant lowers the red translucent cover, and then releases the pushbutton.

3) PLACE mode selector 1-HS-62-140B to BOR.

RO rotates 1-HS-62-140B VCT MAKEUP MODE from AUTO to the right to BOR position.

4) (p) PLACE VCT makeup control 1-HS-62-140A, to START.

RO rotates 1-HS-62-140A,VCT MAKEUP CONTROL to the right to the START position.

5) VERIFY desired boric acid flow indicated on 1 -FI-62-1 39.

RO observes the appropriate flow rate on 1-Fl-62-139, BA TO BLENDER FLOW.

7. DISPATCH personnel to monitor levels for #1, #2, and #4 FWHTs, and #3 HDT.

BOP When the BOP dispatches AUOs to monitor heater and heater drain tank levels, the Console Operator will use INSIGHT file heaters, and THUNDER VIEW page fw6 to observe levels.

8. WHEN reactor power less than or equal to less than or equal to SRO 910 MWe (76%), THEN STOP load reduction.

9. WHEN rated thermal power change exceeds 15% in one hour, THEN NOTIFY Chemistry to initiate 1 -Sl-68-28.

SRO When the SRO contacts Chemistry, the Console Operator will repeat back the request.

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D2 Op Test No.: 2 Scenario # 1 Event # 5 Page 19 of 30 Event

Description:

Intermediate Feedwater Heater B4 develops a leak, causing the heater string to isolate. Requires entry into AOI-47, Heater Drains Malfunction. Requires a rapid plant shutdown using AOl-47 steps.

Time Position Applicants Actions or Behavior

10. NOTIFY the Load Coordinator of the required load reduction and expected ramp rate.

SRQ When the SRO contacts Load Coordinator, the Console Operator will repeat back the information provided.

SRO may contact the ShIft Manager to make notifications.

11. MONITOR rod position: Rods above Lo-Lo insertion limit AFD RO within Target Band

12. MONITOR Tavg and Tref:

RO Tavg trending to Tref.

Mismatch less than 5°F.

13. MAINTAIN SG levels on program or trending toward program BOP levels.

NOTE The bypass around the extraction steam isolation valve is opened to prevent water hammer caused by condensate accumulating in the line above it. However, it is not opened if the #4 FWHT has a high level.

14. CHECK affected isolated #4 FWHT level stable or trending to less than 15 inches on local sightgauge.

BOP When the BOP contacts the AUO for #4 feedwater heater leveI the Console Operator will report current level displayed on the INSIGHT file.

15. LOCALLY OPEN the bypass around the extraction isolation valve for the affected isolated #4 FWHT:

1-IBV-5-500, CNDS HTR A4 EXTR STM INLET 1-FCV-5-54 BYP [Ti F/729]

1-IBV-5-501, CNDS HTR B4 EXTRSTM INLET i-FCV-5-62 BOP BYP [T2G1729j

1-IBV-5-502, CNDS HTR C4 EXTR STM INLET 1-FCV-5-70 BYP [T2F1729]

When the BOP contacts the AUO to locally open 1-lB V-5-501, HTR B4 EXTR STM INLET 1-FCV-5-62, the Console Operator will repeat back the request.

16. EVALUATE use of normal level control valves bypass valves (X)

BOP operation to assist in maintaining #2 FWHT levels (refer to SQl 5&6.Oi as necessary).

17. IF SBMFP was stopped in this AOl, THEN PERFORM applicable section and steps SOI-2&3.0i, to ensure SBMFP is returned to SRO standby.

Since the SBMFP was not stopped, the SRO determines the step is not applicable and continues.

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: 2 Scenaiio # 1 Event # 5 Page 20 of 30 Event

Description:

Intermediate Feedwater Heater B4 develops a leak, causing the heater string to isolate. Requires entry into AOI-47, Heater Drains Malfunction. Requires a rapid plant shutdown using AOl-47 steps.

Time Position Applicants Actions or Behavior

18. INITIATE repairs.

When the SRO contacts Work Control to request a SRO troubleshooting and repair package for the intermediate feedwater heaters, the Console Operator will repeat back the information.

19. PERFORM either:

Applicable steps of SOl-5&6.01, section for Removing Intermediate Pressure Heater String from Service at Power, for SRO the affected string.

OR

SOI-5.01, Returning Intermediate String Feedwater Heaters to Service Following High Level Isolation.

SRO 20. RETURN TO Instruction in effect.

EXAMINER: Cue Console Operator to enter Event 6 after power has been dropped to 76%.

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario # 1 Event # 6,7,8 and 9 Page 21 of 30 Event

Description:

6) Feedwater line break inside containment on #4 SG ramps in to 100%. 7) Auto safety injection fails to occur. 8) After the reactor trip a total loss of offsite power occurs. 1A DG trips when started and the lB DG fails to automatically start.

Requires emergency start of the 1 B DG by the RO during the performance of IMMEDIATE OPERATOR ACTIONS. 9) MSIVs fail to close. Requires transition from E-2, Faulted Steam Generator Isolation, to ECA-2.1, Uncontrolled Depressurization of All Steam Generators.

Time I Position Applicants Actions or Behavior Indications:

95-F RCS LOOSE PARTS ALARM 144-A ICE COND INLET DOOR OPEN 58-B SG FEEDWATER FLOW HI Diagnoses and announces the feedwater line break inside BOP containment.

May direct the RO to perform a manual reactor trip and safety SRO injection.

Enters and directs the actions of E-O, Reactor Trip or Safety SRO Injection.

The following actions are taken from E-O, Reactor Trip or Safety Injection.

NOTE Steps 1 thru 4 are IMMEDIATE ACTION STEPS.

Status Trees I SPDS should be monitored when transitioned to another instruction.

1. ENSURE reactor trip:

Reactor trip and bypass breakers OPEN.

RO checks 1-52RTB, RX TRIP BKR A GREEN indicating light LIT on panel 1-M-4.

RO checks 1-52RTB, RC TRIP BKR B GREEN indicating light LIT on panel 1-M-4 RO checks l-52BYA, BYPASS BKR A lights DARK RO checks 1-52BYB, BYPASS BKR B lights DARK RO

RPIs at bottom of scale.

RO observes 1-MON 85 5000/1 CERPI Monitor I and 1-MON-85 5000/2 CERPI MONITOR 2 for indication that all SHUTDOWN and CONTROL bank rods are inserted.

Neutron flux DROPPING.

RO observes neutron flux trending down on 1-NR-92-145, NEUTRON FLUX LEVEL RECORDER. May also observe levels decreasing on I-Nl-92-135A, CH I NEUTRON MON % PWR and 1-NI-92-136A, CH II NEUTRON MON % PWR.

2. ENSURE Turbine Trip:

All turbine stop valves CLOSED.

RO RO observes that indicating lights on 1-XX-47-1000 EHC CONTROL for individual throttle and governor valves are GREEN.

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario # I Event # 6,7,8 and 9 Page 22 of 30 Event

Description:

6) Feedwater line break inside containment on #4 SG ramps in to 100%. 7) Auto safety injection fails to occur. 8) After the reactor trip a total loss of offsite power occurs. IA DG trips when started and the 1 B DG fails to automatically start.

Requires emergency start of the I B DG by the RO during the performance of IMMEDIATE OPERATOR ACTIONS. 9) MSIVs fail to close. Requires transition from E-2, Faulted Steam Generator Isolation, to ECA-2.1, Uncontrolled Depressurization of All Steam Generators.

[Time Position Applicants Actions or Behavior

3. CHECK 6.9 kV shutdown boards:

a. At least one board energized from:

RO CSST (offsite),

OR D/G (blackout).

Critical Task I Energize at least one AC emergency bus before placing safeguards equipment handswitches in the stop, pull-to-lock position.

Critical 3. RESPONSE NOT OBTAINED:

Task I RESTORE power to at least one train of shutdown boards:

1) EMERGENCY START DIG [1-M-1j.

RO or BOP rotates 1-HS-82-15, DG EMERG START IA-A 2A-A lB-B 2B-B to the right to the EMER START position OR depresses 1-HS-82-46A, EMERGENCY START pushbutton at RO Panel O-M-26.

2) IF both trains shutdown boards remain de-energized, THEN PLACE 6.9kV SD Bd transfer switch in MAN [1-M-1j, and CLOSE supply breaker from energized source. IF power can NOT be restored to at least one train of shutdown boards, THEN GO TO ECA-0.0, Loss of Shutdown Power.

After the IA-A DG is started, the SRO determines that a transition to ECA-O.O is not warranted.

4. CHECK SI actuated:

a. Any SI annunciator LIT.

RO b. Both trains SI ACTUATED.

1 -XX-55-6C

I -XX-55-6D 2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: 2 Scenario# 1 Event# 6,7,8 and9 Page 23 of 30 Event

Description:

6) Feedwater line break inside containment on #4 SG ramps in to 100%. 7) Auto safety injection fails to occur. 8) After the reactor trip a total loss of offsite power occurs. IA DG trips when started and the 1 B DG fails to automatically start.

Requires emergency start of the 1 B DG by the RD during the performance of IMMEDIATE OPERATOR ACTIONS. 9) MSIVs fail to close. Requires transition from E-2, Faulted Steam Generator Isolation, to ECA-2.1, Uncontrolled Depressurization of All Steam Generators.

Time Position Applicants Actions or Behavior Critical Task 2 Manually actuate at least one train of safety injection before transition from E-O, Reactor Trip or Safety Injection.

Critical 4. RESPONSE NOT OBTAINED:

Task2 DETERMINE if SI required:

a. IF ANY of the following exists:

SIG press less than 675 psig, OR

RCS press less than 1870 psig, RD OR

Cntmt press greater than 1 .5 psig THEN ACTUATE SI manually.

RO rotates 1-HS-63-133B SI ACTUATE TR A&B (1-M-4) or 1-HS 133a SI ACTUATE TR A&B (1-M-6) to the right to the ACTUATE position.

EXAMINER: E-O, Reactor Trip or Safety Injection, Appendixes A and B are included as Attachment 2.

5. PERFORM Appendixes A and B, E-0, pages 16-30.

BOP BOP is assigned to perform actions contained in the Appendices.

A separate copy of the Appendices is contained in this package for Examiner use.

SRO 6. ANNOUNCE reactor trip and safety injection over PA system.

7. ENSURE secondary heat sink available with either:

Total AFW flow greater than 410 gpm, OR RD It is expected that Adverse Containment (>2.81 psig) conditions will exist soon after the entry into E-O. When announced the crew will use the bracketed parameter values.

At least one S/G NR level greater than 29% [39% ADVJ.

EXAMINER: The feedwater line break may cause RCS temperature to rise. The applicants may not implement Step 8 RNO actions at this time.

8. MONITOR RCS temperature stable at or trending to 557°F using:

RCS Loop T-avg with any RCP running, RD OR

RCS Loop T-cold with RCPs out-of-service.

2011-10 Watts Bar NRC Examination

LAppendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario # 1 Event # 6,7,8 and 9 Page 24 of 30 Event

Description:

6) Feedwater line break inside containment on #4 SG ramps in to 100%. 7) Auto safety injection fails to occur. 8) After the reactor trip a total loss of offsite power occurs. IA DG trips when started and the lB DG fails to automatically start.

Requires emergency start of the 1 B DG by the RO during the performance of IMMEDIATE OPERATOR ACTIONS. 9) MSlVs fail to close. Requires transition from E-2, Faulted Steam Generator Isolation, to ECA-2.1, Uncontrolled Depressurization of All Steam Generators.

Time Position Applicants Actions or Behavior

8. RESPONSE NOT OBTAINED IF temp less than 557F, THEN ENSURE steam dumps and SIG PORVs CLOSED.

IF cooldown continues, THEN CONTROL total AFW flow to maintain greater than 410 gpm UNTIL NR level in at least one SIG greater than 29% [39% ADVj.

BOP takes manual control of AFWLCVs and reduces AFW flow.

IF cooldown continues after AFW flow is controlled, THEN

PLACE steam dump controls OFF.

BOP rotates 1-HS-1-103A, STEAM DUMP FSVA, and 1-HS-103B STEAM DUMP FSV B to the left to the OFF RESET position.

CLOSE MSIVs.

Recognizes failure of AUTO closure and attempts to MANUALLY close MSIVs from the MCR handswitches. May dispatch an AUO to the Aux Control Room to place the MSIV handswitches to the AUX position.

ENSURE MSIV bypasses CLOSED.

IF RCS temp greater than 564F, THEN ENSURE either steam dumps or SIG PORVs OPEN.

9. ENSURE excess letdown valves CLOSED:

1 -FCV-62-54 RO

1 -FCV-62-55 RO observes GREEN indicating lights LIT on handswitches 1-HS-62-54A, EXCESS LTDN ISOL, and 1-HS-62-55A, EXCESS LTDN.

10. CHECK pzr PORVs and block valves:

a. Pzr PORVs CLOSED.

b. At least one block valve OPEN.

RO observes 1-HS-68-340AA, PZR PORV34OA, CLOSED, GREEN indicating light is LIT, RED indicating light is DARK.

RO RO observes 1-HS-68-334A, PZR PORV 334, CLOSED, GREEN indicating light is LIT, RED indicating light is DARK.

RO observes 1-HS-68-333A, BLOCK VLV FOR PORV34OA, OPEN GREEN indicating light is DARK, RED indicating light is LIT.

RO observes 1-HS-68-332A, BLOCK VLV FOR PORV 334, OPE GREEN indicating light is DARK, RED indicating light is LIT.

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario # 1 Event# 6,7,8 and 9 Page 25 of 30 Event

Description:

6) Feedwater line break inside containment on #4 SG ramps in to 100%. 7) Auto safety injection fails to occur. 8) After the reactor trip a total loss of offsite power occurs. 1A DG trips when started and the 1 B DG fails to automatically start.

Requires emergency start of the 18 DG by the RD during the performance of IMMEDIATE OPERATOR ACTIONS. 9) MSIVs fail to close. Requires transition from E-2, Faulted Steam Generator Isolation, to ECA-2.1, Uncontrolled Depressurization of All Steam Generators.

Time Position Applicants Actions or Behavior

11. CHECK pzr safety valves CLOSED:

EVALUATE tailpipe temperatures and acoustic monitors.

RO observes response of 1-TI-68-330, SAFETY 68-563 TAILPIPE RO TEMP, l-TI-68-329, SAFETY 68-564 TAILPIPE TEMP, and 1-TI 328, SAFETY 68-565, stable at approximately 110 CF.

BOP may observe 1-Xl-68-363, PZR VALVES ACOUSTIC MONITOR indicating lights are DARK for 1-XI-68-363 (68-563), 1-Xl-68-364 (68-564) and 1-Xl-68-365 (68-565

12. CHECK pzr sprays CLOSED.

RD RO observes the pzr spray valves closed by GREEN indicating lights LIT for 1-Xl-68-340B, PZR SPRAY LOOP 2 and 1-Xl 340D, PZR SPRAY LOOP 1.

NOTE Seal injection flow should be maintained to all RCPs.

13. CHECK if RCPs should remain in service:

The RCPs tripped due to the loss of offsite power.

RD

a. Phase B signals DARK [MISSP].

b. RCS pressure greater than 1500 psig.

14. CHECK SIG pressures:

All S/G pressures controlled or rising.

RO observes PAM pressure instruments on SG I through 4 (black labels) and determines that pressures are dropping. May also RD observe trends on 1-PR-1-2, SG I & 2 PRESS P51G. and 1-PR-I-23, SG 3 & 4 PRESS PSIG to assess this step.

All S!G pressures greater than 120 psig.

RO observes PAM pressure instruments on SG I through 4 (black labels) and determines that pressures are greater than 120 psig.

14. RESPONSE NOT OBTAINED:

IF SIG pressure low OR dropping uncontrolled, THEN GO TO E-2, Faulted Steam Generator Isolation.

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ESD-2 Op Test No.: 2 Scenario # 1 Event # 6,7,8 and 9 Page 26 of 30 Event

Description:

6) Feedwater line break inside containment on #4 SG ramps in to 100%. 7) Auto safety injection fails to occur. 8) After the reactor trip a total loss of offsite power occurs. 1A DG trips when started and the lB DG fails to automatically start.

Requires emergency start of the 1 B DG by the RO during the performance of IMMEDIATE OPERATOR ACTIONS. 9) MSIVs fail to close. Requires transition from E-2, Faulted Steam Generator Isolation, to ECA-2.1, Uncontrolled Depressurization of All Steam Generators.

Time Position Applicants Actions or Behavior The following steps are taken from E-2, Faulted Steam I

Generator Isolation.

CAUTION If a faulted SIG is NOT needed for RCS cooldown, it should remain isolated during subsequent recovery actions.

BOP 1. ENSURE all MSIVs and MSIV bypasses CLOSED.

EXAMINER: E-2, Reactor Trip or Safety Injection, Attachment I is included as Attachment 3.

1. RESPONSE NOT OBTAINED Manually CLOSE valves.

IF valves can NOT be closed, THEN Locally REMOVE power to valves:

BOP

DISPATCH NAUO to perform Attachment 1 (E-2).

When contacted as the Control Building AUO to perform Attachment 1, the Console operator will enter msr26a, msr26b, msr26c, and msr26d to place the MSIV switches in the Aux Control Room in the AUX position. The Console Operator will report back that this has been done NOTE If it is known that a steam leak exists in the Turbine building, the following step should not be performed until the affected steam header is depressurized.

2. PLACE steam dump controls OFF:

1-HS-1-103A, STEAM DUMP FSVA.

BOP

1-HS-l-103B, STEAM DUMP FSVB.

Step already performed as part of E-O.

3. CHECK for at least one Intact SIG:

Any SIG pressure controlled or rising, RO OR

Any SIG pressure greater than P-sat for RCS incore temperature.

3. RESPONSE NOT OBTAINED SRO IF pressure in all four S!Gs dropping uncontrolled, THEN GO TO ECA-2.1, Uncontrolled Depressurization of All Steam Generators.

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: 2 Scenario # I Event # 6,7,8 and 9 Page 27 of 30 Event

Description:

6) Feedwater line break inside containment on #4 SG ramps in to 100%. 7) Auto safety injection fails to occur. 8) After the reactor trip a total loss of offsite power occurs. 1 A DG trips when started and the 1 B DG fails to automatically start.

Requires emergency start of the 1 B DG by the RO during the performance of IMMEDIATE OPERATOR ACTIONS. 9) MSIVs fail to close. Requires transition from E-2, Faulted Steam Generator Isolation, to ECA-2.1, Uncontrolled Depressurization of All Steam Generators.

Time Position Applicants Actions or Behavior The following steps are taken from ECA-2.1, Uncontrolled ECA-21 Depressurization of All Steam Generators.

CAUTION If, at any time, except during SI termination steps 14 through 24, any Intact SIG can be isolated from the break and re-pressurized, then recovery actions should continue with E-2, Faulted Steam Generator Isolation.

SRO 1. REFER TO EPIP-1, Emergency Plan Classification Flowchart.

CAUTION If the TD AFW pump is the only available source of feed flow to ANY SIG, the steam supply must be maintained available.

2. ENSURE secondary pressure boundary isolated:

ENSURE all MSIVs and MSIV bypasses CLOSED.

PLACE steam dump controls OFF.

ENSURE MEW reg and bypass reg valves CLOSED.

ENSURE MEW isolation and bypass isolation valves CLOSED.

RO S/G I and 3 MFW Iso! valves not be closed due to power loss.

IF both MD AFW pumps available, THEN ENSURE steam supply valves to TD AEW pump CLOSED.

ENSURE SIG PORVs CLOSED.

ENSURE SIG blowdown ISOLATED.

2. RESPONSE NOT OBTAINED Manually CLOSE valves to restore pressure boundary on at least one SIG.

IF valves can NOT be closed, THEN DISPATCH personnel to close valves locally, one loop at a time:

CLOSE MSIV and bypass valve as necessary USING Appendix A (ECA-2.1).

E-2, Attachment I has been implemented, and contains the SRO same actions as ECA-2. I Appendix A. The MSIVs will NOT be closed during the scenario.

ISOLATE 5/0 atmospheric relief valve as necessary.

CLOSE additional feedwater or condensate MOVs as necessary.

BOP may dispatch personnel to close #1 FWHtr outlet valves, Console operator will acknowledge the request.

ISOLATE blowdown locally as necessary.

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario # 1 Event # 6,7,8 and 9 Page 28 of 30 Event

Description:

6) Feedwater line break inside containment on #4 SG ramps in to 100%. 7) Auto safety injection fails to occur. 8) After the reactor trip a total loss of offsite power occurs. 1 A DG trips when started and the 1 B DG fails to automatically start.

Requires emergency start of the 1 B DG by the RO during the performance of IMMEDIATE OPERATOR ACTIONS. 9) MSIVs fail to close. Requires transition from E-2, Faulted Steam Generator Isolation, to ECA-2.1, Uncontrolled Depressurization of All Steam Generators.

Time Position Applicants Actions or Behavior CAUTION If total feed flow CAPABILITY of 410 gpm is available, FR-H.1, Loss of Secondary Heat Sink, should NOT be implemented.

NOTE Minimum detectable flow is assured by observing flow indicator response to valve movement.

3. CONTROL feed flow to minimize RCS cooldown and prevent SIG dryout:

BOP

a. CHECK T-cold cooldown rate less than 100°F in the last one hour.

EXAMINER: Step 3 RNO may not be required depending upon the progression of the scenario when this step is performed.

3. RESPONSE NOT OBTAINED

a. REDUCE feed flow to each SIG to minimum detectable to minimize cooldown.

BOP **

GO TO Substep 3c.

BOP will take manual control of all AFW level control valves and adjust flow to all SIGs until the related flow indicator deflects off the bottom scale.

c. IF any SIG NR level drops to 29% [39% ADV], THEN RO MAINTAIN at least minimum detectable flow to each SIG with low level.

4. MONITOR shutdown margin during RCS cooldown:

REFER TO 1-Sl-0-10, Shutdown Margin OR REACTINW SRO Computer Program.

SRO requests performance of 1-Sl-O-1O by the Surrogate STA.

SRO 5. MONITOR T-hot stable or dropping.

CAUTION The 1500 psig RCP trip criteria is NOT applicable if the pressure drop is caused by S/G depressurization as indicated by RCS temperature at T-sat for SIG pressure.

NOTE Seal injection flow should be maintained to all RCPs.

6. MONITOR if RCPs should remain in service:

a. Phase B DARK [MISSPj.

SRO

b. RCS pressure greater than 1500 psig.

RCPs tripped during the loss of offsite power event.

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario # 1 Event # 6,7,8 and 9 Page 29 of 30 Event

Description:

6) Feedwater line break inside containment on #4 SG ramps in to 100%. 7) Auto safety injection fails to occur. 8) After the reactor trip a total loss of offsite power occurs. IA DG trips when started and the lB DG fails to automatically start.

Requires emergency start of the 1 B DG by the RO during the performance of IMMEDIATE OPERATOR ACTIONS. 9) MSIVs fail to close. Requires transition from E-2, Faulted Steam Generator Isolation, to ECA-2.1, Uncontrolled Depressurization of All Steam Generators.

Time Position Applicants Actions or Behavior

7. MONITOR pzr PORVs and block valves:

a. Pzr PORVs CLOSED.

SRO

b. At least one block valve OPEN.

Actions previously performed.

8. CHECK secondary side activity levels:

SIG discharge rad monitors NORMAL.

Condenser vacuum exhaust rad monitors NORMAL.

SIG blowdown rad monitor recorders NORMAL trend prior to SRO isolation,

SIG sample results by Chemistry NORMAL.

BOP reports primary and secondary radiation during the performance of E-O, Appendix A. SRO may direct the BOP to recheck secondary radiation at this point, and call Chemistry to have SGs sampled for activity.

CAUTION If offsite power is lost after SI reset, manual action will be required to restart the SI pumps and RHR pumps due to loss of SI start signal.

9. DETERMINE if RHR pumps should be stopped:

a. CHECK RHR suction aligned to RWST.

b. CHECK RCS pressure greater than 150 psig.

c. CHECK RCS pressure stable or rising.

d. RESET SI, AND CHECK the following:

RO

SI ACTUATED permissive DARK.

AUTO SI BLOCKED permissive LIT.

e. STOP RHR pumps, AND PLACE in A-AUTO.

f. MONITOR RCS pressure greater than 150 psig.

RO will place IA-A RHR pump hand switch to stop and allow it to spring return to A-AUTO.

10. DETERMINE if cntmt spray should be stopped:

BOP

a. MONITOR cntmt pressure less than 2.0 psi .

9 10.a. RESPONSE NOT OBTAINED:

WHEN cntmt pressure is less than 2.0 psig, THEN PERFORM Substeps 1 Ob thru e. ** GO TO Step 11.

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario # 1 Event # 6,7,8 and 9 Page 30 of 30 Event

Description:

6) Feedwater line break inside containment on #4 SG ramps in to 100%. 7) Auto safety injection fails to occur. 8) After the reactor trip a total loss of offsite power occurs. 1A DG trips when started and the 1 B DG fails to automatically start.

Requires emergency start of the 1 B DG by the RO during the performance of IMMEDIATE OPERATOR ACTIONS. 9) MSIVs fail to close. Requires transition from E-2, Faulted Steam Generator Isolation, to ECA-2.1, Uncontrolled Depressurization of All Steam Generators.

Time N Position N Aoolicants Actions or Behavior

b. CHECK at least one cntmt spray pump RUNNING.

c. RESET cntmt spray signal.

d. STOP cntmt spray pumps, AND PLACE in A-AUTO.

e. CLOSE cntmt spray discharge valves 1-FCV-72-2 and 1-FCV-72-39.

RO 11. MONITOR RWST level greater than 34%.

12. DETERMINE if cold leg accumulators should be isolated:

a. ENSURE power to isolation valves restored USING Appendix RO B (ECA-2.1), CLA Breaker Operation.

b. CHECK RCS pressure less than 250 psig.

12.b RESPONSE NOT OBTAINED RO WHEN RCS pressure is less than 250 psig, THEN **

PERFORM Substeps 12c and 12d.

13. MONITOR modified SI termination criteria:

a. RCS subcooling greater than 65°F [85°F ADVj.

RO

b. RCS pressure stable or rising.

c. Pzr level greater than 15% [33% ADVj.

EXAMINER: When modified SI termination criteria has been checked in step 13, scenario may be terminated.

END OF SCENARIO 2011-10 Watts Bar NRC Examination

Scenano I SifiFT TURNOVER CRECKLIST Page 1 of2 SHIFT TURNOVER CHECKLIST Page 1 of 1 Q SM US/MCR Unit l 11 UO Unit Off-going Name

[] AUO Station STA (STA Function) On-coming Name Part 1 Completed by off-going shift / Reviewed by on-coming shift:

RCS Cb 1031 ppm

Abnoimal equipment lineup I conditions:

lA-A RHR Pump is out-of-service for motor winding inspection. LCO 3.5.2 and 3.6.6 were enteredlO hours ago.

lA-A RHR pump is expected to be returned to service in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months . Protected equipment signs have been posted for lB-B RHR pump.

SI/Test in progress/planned: (including need for conduct of evolution briefings)

Major Activities/Procedures in progress/planned:

Train A/Channel I Work Week. 100% power, RCS boron concentration 1031 ppm, Control Bank D is at 220 steps.

Maintain current plant conditions.

Radiological changes in plant during shift:

Part 2 Completed by on-coming shift prior to assuming duties D Review station rounds / Abnormal reading (AUOs only)

[] Review Narrative Logs (previous day and carry-over items)

Q Current qualification status Q Review the current controlling Reactivity Management Plans (N/A for AUOs)

Q Review current TSiTRM/ODCMIFPR Required Actions (N/A for AUO5)

[] Walkdown MCR Control Boards with off-going Operator (N/A for AUOs, as applicable for SM/STAs)

Q SR/PER reviews complete for previous shift (SM/US/STA)

Relief Time: Relief Date:

Part 3 Completed by on-coming shift. These items may be reviewed after assuming duties:

Q Review Operator Workarounds, Burdens and Challenges (applicable Unit/Station)

Q Review applicable ODMI actions (first shift of shift week)

D Review changes in Standing / Shift Orders (since last shift worked)

Review changes to TACFs issued (since last shift worked) (N/A for AUOs)

Review Control Room Deficiencies (first shift of shift week) (N/A for AUO5)

Q Review Component Deviation Log (N/A for AUO5)

TVA 40741 Page 1 of 1 OPDP-l-l [01-14-2011]

Scenano I SifiFT TURNOVER CHECKLIST Page 1 of2 SHIFT TURNOVER CHECKLIST Page 1 of 1 Q SM US/MCR Unit 1 UO Unit Off-going - Name 1i AUO Station Q STA (STA Function) On-coming - Name Part I - Completed by off-going shift / Reviewed by on-coming shift: RCS Cb 1031 ppm Abnormal equipment lineup / conditions:

lA-A RHR Pump is out-of-service for motor winding inspection. LCO 3.5.2 and 3.6.6 were enteredl 0 hours0 days 0 hours 0 weeks 0 months ago.

1 A-A RHR pump is expected to be returned to service in 6 hours6.944444e-5 days 0.00167 hours 9.920635e-6 weeks 2.283e-6 months . Protected equipment signs have been posted for lB-B RHR pump.

SI/Test in progress/planned: (including need for conduct of evolution briefings)

Major Activities/Procedures in progress/planned:

Train A/Channel I Work Week. 100% power, RCS boron concentration 1031 ppm, Control Bank D is at 220 steps.

Maintain current plant conditions.

Radiological changes in plant during shift:

Part 2 Completed by on-coming shift prior to assuming duties Review station rounds / Abnormal reading (AUOs only)

Review Narrative Logs (previous day and carry-over items)

[] Current qualification status C Review the current controlling Reactivity Management Plans (N/A for AUOs)

Q Review current TS/TRMJODCMIFPR Required Actions (N/A for AUOs)

Q Walkdown MCR Control Boards with off-going Operator (N/A for AUOs, as applicable for SM/STAs)

C SRJPER reviews complete for previous shift (SM/US/STA)

Relief Time: Relief Date:

Part 3 Completed by on-coming shift. These items may be reviewed after assuming duties:

Q Review Operator Workarounds, Burdens and Challenges (applicable Unit/Station)

Q Review applicable ODMI actions (first shift of shift week)

Q Review changes in Standing / Shift Orders (since last shift worked)

Q Review changes to TACFs issued (since last shift worked) (N/A for AUOs)

Q Review Control Room Deficiencies (first shift of shift week) (N/A for AUO5)

Review Component Deviation Log (N/A for AUOs)

TVA 40741 Page 1 of 1 OPDP-l-l [01-14-2011]

Scenario I Attachment I Reactivity Briefing Sheet for Runback to 75% Power.

WBN Administration Of The Tl-7.01 2 I Reactivity Briefing Sheets And Rev. 0004 Reactivity Control Plans Page 21 of 23 Appendix A (Page 1 of 1)

Reactivity Control Plan (Example Form)

Station: WBN Unit: 1 Cycle: 10 Burnup: 150 MWD/MTU Revision: 0 Preparer: I Reviewer: /

I Date RXE I Date Approver: Authorizer:

RXES or designee I Date Ops I Date RXE support required Onsite? lYes DNo Describe: Call out for Ramp Up plan Title of Reactivity Control Plan: 900 MW (7 5%) Runback Assumptions: 1. Reactor stable at full power prior to runback

2. Calculated volumes below assume Tavg maintained on Tref Major Steps: 1. Runback to 85%.

2. Rapid Load Reduction to 75%

Detailed

Description:

NOTE: See attached plots.

1. BORATE -369 gal of BA.

2. EXPECT the RIL Lo annunciator to alarm.

3. WHEN the runback is complete and as Tavg allows, THEN WITHDRAW CBD to 189 steps.

4. PLACE control rods in MANUAL for AFD control.

5. DILUTE -1018 gal PW during the Xenon buildin for the first 5 hours5.787037e-5 days 0.00139 hours 8.267196e-6 weeks 1.9025e-6 months following the runback to maintain Tavg near Tref.

6. BORATE the RCS as necessary to maintain Tavg near Tref as Xenon decays to an equilibrium value (732 gal BA).

Critical Parameter Limit Required Action Control Rod Height > RIL Lo If rods < RIL Lo, then ENSURE RCS borated amount specified in Step 1 and WITHDRAW rods.

Activated: I Terminated: I I SMorUS I Date SM or US I Date

Scenario I Attachment 2 EO, Reactor Trip or Safety Injection Appendix A and B Attach me nts I th ro u g h 5

WBN Reactor Trip or Safety Injection E-0 Unit I Rev. 0030 Appendix A (Page 1 of 9)

Equipment Verification Step [Action/Expected Response Response Not Obtained ENSURE PCBs OPEN: OPEN manually.

PCB 5084.

PCB 5088.

2. ENSURE AFW pump operation: ESTABLISH at least one train AEW operation.

Both MD AFW pumps RUNNING.

TDAFWpump RUNNING.

LCVs1nAUTO,OR controlled in MANUAL.

3. ENSURE MEW isolation: Manually CLOSE valves AND

MEW isolation and bypass isolation valves CLOSED. STOP pumps, as necessary.

0 MEW reg and bypass reg valves CLOSED. IF any valves can NOT be closed, THEN

MFP A and B TRIPPED.

Standby MFP STOPPED. CLOSE #1 heater outlet valves.

Cond demin pumps TRIPPED.

Cond booster pumps TRIPPED.

#3 HDT Pumps TRIPPED.

#7 HDT Pumps TRIPPED.

Page 16 of 31

WBN Reactor Trip or Safety Injection E-0 Unit I Rev. 0030 Appendix A (Page 2 of 9)

Equipment Verification Step _Action/Expected Response Response Not Obtained

4. MONITOR ECCS operation:

a. Charging pumps RUNNING. a. Manually START charging pumps.

b. Charging pump alignment: b. ENSURE at least one valve in each set aligned.

RWST outlets I -LCV-62-1 35 and I-LCV-62-136 OPEN.

VCT outlets 1-LCV-62-132 and 1 -LCV-62-1 33 CLOSED.

Charging 1-FCV-62-90 and 1-FCV-62-91 CLOSED.

c. RHR pumps RUNNING. c. Manually START RHR pumps.

d. SI pumps RUNNING. d. Manually START SI pumps.

e. BIT alignment: e. ENSURE at least one valve aligned, and flow thru BIT.

Outlets 1 -FCV-63-25 and 1-FCV-63-26 OPEN.

Flow thru BIT.

f. RCS pressure greater f. ENSURE SI pump flow.

than 1650 psig.

IF RCS press drops to less than 150 psig, THEN ENSURE RHR pump flow.

Page 17 of 31

WBN Reactor Trip or Safety Injection E-0 Unit I Rev. 0030 Appendix A (Page 3 of 9)

Equipment Verification Step LActb0fhE>pted Response Response Not Obtained

5. CHECK cntmt isolation: ACTUATE Phase A and

a. Phase A isolation: Cntmt Vent Isolation signal,

TrainAGREEN. OR

Train B GREEN.

Manually CLOSE valves and

b. Cntmt vent isolation: dampers as hecessary.

Train A GREEN.

Train B GREEN.

Page 18 of 31

WBN Reactor Trip or Safety Injection E-0 Unit I Rev. 0030 Appendix A (Page 4 of 9)

Equipment Verification ep Action/Expected Response Response Not Obtained

6. CHECK cntmt pressure: PERFORM the following:

Phase B DARK [MISSP]. 1) ENSURE Phase B actuated.

Cntmt Spray DARK [MISSP]. 2) ENSURE Cntmt Spray actuated.

Cntmt press less than 2.8 psig. 3) ENSURE cntmt spray pumps running.

4) ENSURE cntmt spray flow.

5) ENSURE Phase B isolation:

Train A GREEN.

Train B GREEN Manually CLOSE valves and dampers as necessary.

6) STOP all RCPs.

7) ENSURE MSIVs and bypasses CLOSED.

8) PLACE steam dump controls OFF.

9) WHEN 10 minutes has elapsed since Phase B actuated, THEN ENSURE air return fans start.

10) USE adverse cntmt [ADV] setpoints where provided.

7. DISPATCH AUO to perform Attachment 1 (E-0), Ice Condenser AHU Breaker Operation.

Page 19of31

WBN Reactor Trip or Safety Injection E-0 Unit I Rev. 0030 Appendix A (Page 5 of 9)

Equipment Verification Step _Action/Expected Response Response Not Obtained

8. CHECK plant radiation NORMAL: NOTIFY Unit Supervisor IMMEDIATELY.

SIG blowdown rad recorder 1-RR-90-120 NORMAL prior to isolation [M-12].

Condenser vacuum exhaust rad recorder 1-RR-90-119 NORMAL prior to trip [M-12].

I -RR-90-1 06 and 1 -RR-90-1 12 radiation recorders NORMAL prior to isolation [M-12].

SIG main steamline discharge monitors NORMAL [M-30].

Upper and Lower containment high range monitors NORMAL

[M-30].

NOTIFY Unit Supervisor conditions NORMAL.

9. ENSURE all D/Gs RUNNING. EMERGENCY START D/Gs

10. ENSURE ABGTS operation:

a. ABGTS fans RUNNING. a. Manually START fans.

b. ABGTS dampers OPEN: b. Locally OPEN dampers.

FCO-30-146A.

FCO-30-146B.

FCO-30-1 57A.

FCO-30-1 57B.

Page2Oof3l

WBN Reactor Trip or Safety Injection E-0 Unit I Rev. 0030 Appendix A (Page 6 of 9)

Equipment Verification Step Action/Expected Response Response Not Obtained

11. ENSURE at least four ERCW pumps Manually START pumps as necessary.

RUNNING, one on each shutdown board preferred.

12. ENSURE ERCW supply valves IF ERCW can NOT be OPEN to running DIGs. aligned to running DIG, THEN EMERGENCY STOP affected D/G.

13. ENSURE O-FCV-67-1 52, CCS HX C Manually OPEN O-FCV-67-152 ALT DISCH TO HDR B, is open to to position A.

position A.

14. CLOSE O-FCV-67-144, CCS HX C DISCH TO HDRA.

15. MONITOR EGTS operation: Manually START fans

EGTS fans RUNNING.

AND o ENSURE dampers OPEN o VERIFY filter bank dp between 5 OPEN dampers.

and 9 inches of water.

16. ENSURE CCS pumps RUNNING: Manually START pumps as necessary.

1A-ACCS pump.

lB-B CCS pump.

C-S or 2B-B CCS pump.

17. DISPATCH AUO to shutdown Upper and Lower CNTMT rad monitors USING SOl-90.02.Gaseous Process Radiation Monitors Page 21 of3l

WBN Reactor Trip or Safety Injection E-0 Unit I Rev. 0030 Appendix A (Page 7 of 9)

Equipment Verification Step Action/Expected Response Response Not Obtained

18. WHEN Attachment 1 is complete (Ice Condenser AHU Breakers OPEN),

THEN ENERGIZE hydrogen igniters

[1-M-1 0]:

1-HS-268-73 ON.

1-HS-268-74 ON.

NOTE The following equipment is located on 1-M-9.

19. CHECK CNTMT PURGE fans STOP fans AND STOPPED.

PLACE handswitch in PULL-TO-LOCK.

20. CHECK FUEL HANDLING EXH fans STOP fans AND STOPPED, Fuel and Cask loading dampers CLOSED: PLACE handswitch in PULL-TO-LOCK, THEN Manually CLOSE dampers.

21. ENSURE AB GEN SUPPLY and STOP fans AND EXH fans STOPPED.

PLACE handswitch in PULL-TO-LOCK.

NOTE Dampers 1-HS-30-158 and 2-HS-30-270 remain open during ABI.

22. ENSURE AB GEN SUP & EXH Manually CLOSE dampers.

dampers CLOSED.

Page22of3l

WBN Reactor Trip or Safety Injection E-0 Unit I Rev 0030 Appendix A (Page 8 of 9)

Equipment Verification Step _Action/Expected Response Response Not Obtained

23. ENSURE MCR & SPREAD RM Manually CLOSE dampers.

FRESH AIR dampers CLOSED:

FCV-31-3.

FCV-31-4.

24. ENSURE at least one CB EMER CLEANUP fan RUNNING and associated damper OPEN:

CB EMERG CLEANUP FAN A-A, Manually START fan.

OR

Fan B-B RUNNING..

FCO-31-8,OPEN. NOTIFY TSC if at least one damper NOT OPEN.

OR

FCO-31-7, OPEN

25. ENSURE at least one CB EMER PRESS fan RUNNING and associated damper OPEN:

CB EMERG PRESS FAN A-A, Manually START fan.

OR FAN B-B RUNNING.

FCO-31-6, OPEN. NOTIFY TSC if at least one damper NOT OPEN.

OR

FCO-31-5, OPEN.

Page 23 of 31

WBN Reactor Trip or Safety Injection E-0 Unit I Rev. 0030 Appendix A (Page 9 of 9)

Equipment Verification Step Action/Expected Response Response Not Obtained

26. ENSURE Control Building fans STOPPED and dampers CLOSED:

SPREADING ROOM SUPPLY Manually STOP fans AND and EXH FANS AND dampers.

NOTIFY TSC if any damper NOT

TOILET & LKR RM EXHAUST CLOSED.

FAN AND dampers.

27. INITIATE Appendix B (E-O), Phase B Pipe Break Contingencies.

Page 24 of3l

WBN Reactor Trip or Safety Injection E-0 Unit I Rev. 0030 Appendix B (Page 1 of I)

Phase B Pipe Break Contingencies Step _Action/Expected Response Response Not Obtained

1. CHECK PHASE B actuated. WHEN PHASE B actuation occurs,

[MISSP 1-XX-55-6C, -6D]

- THEN GOTOstep2.

2. ENSURE 1-FCV-32-11O CLOSED. DISPATCH AUO to perform

[CISP 1-XX-55-6E]

- Attachment 2 (E-O).

(A-train, window 13)

3. ENSURE 1-FCV-67-107 CLOSED. DISPATCH AUO to perform

[CISP 1-XX-55-6E]

- Attachment 3 (E-O).

(A -train, window 43)

4. ENSURE 1-FCV-70-92 CLOSED. DISPATCH AUO to perform

[CISP 1-XX-55-6E]

- Attachment 4 (E-O).

(A -train, window 73)

5. ENSURE 1-FCV-70-140 CLOSED. DISPATCH AUO to perform

[CISP 1-XX-55-6F}

- Attachment 5 (E-O).

(B -train, window 74)

Page25of3l

WBN Reactor Trip or Safety Injection E-0 Unit I Rev. 0030 Attachment I (Page 1 ofl)

Ice Condenser AHU Breaker Operation OPEN the following to remove power from ice condenser air handling units AND REPORT completion to UO:

BOARD COMPT NOMENCLATURE 480 V Reactor Vent 13D 1-BKR-232-A000/13D ICE COND Board 1 A-A 1 -AHU-61 -1/4/8/12/16/20/24/28 480 V Reactor Vent 14D 1-BKR-232-A000/14D ICE COND Board lA-A 1-AHU-61-3/7/1 1/1 5/1 9/23/27 480 V Reactor Vent I 3D 1 -BKR-232-B000/l 3D ICE COND Board 1 B-B 1-AHU-61-2/6/10114/18/22/26/30 480 V Reactor Vent 14D 1-BKR-232-B000/14D ICE COND Board lB-B l-AHU-61-5/9/13/17/21/25/29 Page 26 of 31

WBN Reactor Trip or Safety Injection E-0 Unit I Rev. 0030 Attachment 2 (Page 1 of 1)

Control Air Isolation A. CLOSE O-ISV-32-1013 CONTROL AIR EL 713 AB HDR ISOL

[A6/S EL. 713] (chain operated behind Fuel and Waste Handling Bd. A).

B. IF O-ISV-32-1013 CANNOT BE CLOSED, THEN OPEN and DISCONNECT C&SS air compressor breakers:

1. O-BKR-32-25 [480V SD BD 1A2-A, C/3D]

2. O-BKR-32-26 [480V SD BD 1B1-B, C/3D]

3. O-BKR-32-27 [480V AUX BLDG COM BD, CI6C]

4. O-BKR-32-4900A [480V TURB BLDG COM BD, C/6C]

Page 27 of3l

WBN Reactor Trip or Safety Injection E-0

Unit I Rev. 0030 Attachment 3 (Page 1 of 1)

ERCW Isolation UNLOCK AND CLOSE 1 -ISV-67-523B, LOWER CNTMT VENT CLR I B &1 D ERCW SUP ISOL [A2U/692] (U-i penetration room North of AB Pipe Chase Cooler lB-B in overhead)

Page28of3i

WBN Reactor Trip or Safety Injection E-0 Unit I Rev. 0030 Attachment 4 (Page 1 of I)

CCS Return Isolation CLOSE 1-ISV-70-700, RCP OIL COOLER CCS RETURN ISOLATION

[A4N EL. 710 U-I Penetration Room] (approximately 10 ft. North of Penetration Room Cooler lB-B on mezzanine above RHR Sump Valve Room)

Page29of3I

WBN Reactor Trip or Safety Injection E-0 Unit I Rev. 0030 Attachment 5 (Pagelofi)

CCS Supply Isolation CLOSE 1-.ISV-70-516, REACTOR BUILDING CCS SUPPLY ISOLATION

[A6IT EL. 737] (Behind Elevator approximately 2 ft. west on mezzanine above A CCS Heat Exchanger)

Page 30 of 31

Scenario I Attachment 3 E2 Faulted Steam Generator Isolation Attachment I, Isolation of MSIVs and MSIV Bypass Valves

WBN Faulted Steam Generator Isolation E-2 Unitl Rev.0012 Attachment I (Page 1 of 4)

Isolation of MSIVs and MSIV Bypass Valves 1.0 INSTRUCTIONS 1.1 Isolation of MSIVs and MSIV Bypass Valves A. IF any MSIV will NOT close, THEN GO TO Section 1.2 (Attachment 1).

B. IF any MSIV bypass valve will NOT close, THEN GO TO Section 1.3 (Attachment 1).

Page 9 of 12

WBN Faulted Steam Generator Isolation E-2 Unit I Rev. 0012 Attachment I (Page 2 of 4)

Isolation of MSIVs and MSIV Bypass Valves 1.2 MSIV Isolation A. PLACE affected MSIV transfer control switch in AUX position:

[Auxiliary Control Room, Panels 1-L-1 1A and 1-L-1 is]

SIG AUX (Circle AUX TRANSFER EQUIPMENT POSITION affected SWITCH SIG) 1 MSIV Loop 1, Train A, 1-FCV-1-4 1-XS-1-4A D MSIV Loop 1, Train B, 1-FCV-1-4 1-XS-1-4B 2 MSIV Loop 2, Train A, 1-FCV-1-11 1-XS-1-1IA MSIV Loop 2, Train B, 1-FCV-1-1 1 1-XS-1-1 1 B 3 MSIV Loop 3, Train A, 1-FCV-1-22 1-XS-1-22A D MSIV Loop 3, Train B, 1-FCV-1-22 l-XS-l-22B EJ 4 MSIV Loop 4, Train A, 1-FCV-1-29 1-XS-1-29A MSIV Loop 4, Train B, 1-FCV-1-29 1-XS-1-29B D B. CONSULT UO to verify affected MSIV closed.

Page 10 of 12

WBN Faulted Steam Generator Isolation E-2 Unit I Rev. 0012 Attachment I (Page 3 of 4)

Isolation of MSIVs and MSIV Bypass Valves 1.2 MSIV Isolation (continued)

C. IF affected MSIV still open OR Control power fuse removal desired, THEN REMOVE MSIV fuses:

(Circle FUSE LOCATION REMOVED affected EQUIPMENT (Two per circuit)

SIG)

MSIV Loop 1, Train A, 125V Vital Battery Bd I 1FCV14 CircuitA-46 D B-46 Circuit MSIV Loop 1, Train B, 125V Vital Battery Bd II 1FCV14 Circuit A-46 EJ Circuit B-46 D MSIV Loop 2, Train A, 125V Vital Battery Bd I 1FCV111 CircuitA-47 Circuit B-47 2

MSIV Loop 2, Train B, 125V Vital Battery Bd II 1FCV111 CircuitA-47 EJ Circuit B-47 MSIV Loop 3, Train A, 125V Vital Battery Bd I 1FCV122 Circuit A-48 Circuit B-48 EJ 3

MSIV Loop 3, Train B, 125V Vital Battery Bd II 1FCV122 CircuitA-48 Circuit B-48 EJ MSIV Loop 4, Train A, 125V Vital Battery Bd I 1FCV129 Circuit A-49 Circuit B-49 I:

4 MSIV Loop 4, Train B, 125V Vital Battery Bd II 1FCV129 CircuitA-49 Circuit B-49 D. NOTIFY UO upon completion.

Page 11 of 12

WBN Faulted Steam Generator Isolation E-2 Unit I Rev. 0012 Attachment I (Page 4of4)

Isolation of MSIVs and MSIV Bypass Valves 1.3 MSIV Bypass Isolation A. PLACE HS in OFF for MSIV bypass valves that will NOT close:

SIG NOMENCLATURE HSOFF LOCATION POSITION UNID SIG)

MAIN STEAM ISOL VLV 1 LOOP I BYP A3U/737 OFF 1-HS-1-147B WARMING VLV MAIN STEAM ISOL VLV 2 LOOP 2 BYP A4U/757 OFF 1-HS-1-148B D WARMING VLV MAIN STEAM ISOL VLV 3 LOOP 3 BYP A5U1757 OFF 1-HS-1-149B WARMING VLV MAIN STEAM ISOL VLV 4 LOOP 4 BYP A3U/737 OFF 1-HS-i-150B D WARMING VLV B. NOTIFY UO upon completion.

Page 12 of 12

ppendix D Scenario OutHne Form ES-D-1 Facility: Watts Bar October 2011 Scenario No. 2 Op Test No.: 2 Examiners: Operators: SRO RO BOP Initial Conditions: 100% power, RCS boron concentration 1031 ppm. Control Bank D at 220 steps.

Turnover: Train B/Channel II Work Week. I B-B RHR pump is out of service for motor winding inspection. LCD 3.5.2 and 3.6.6 were entered 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ago. I B-B RHR pump is expected to be returned to service in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . Protected equipment signs have been posted for lA-A RHR pump. A power reduction to 95% at 2%/mm using AOI-39, Rapid Load Reduction, is required to be performed to remove the 1 B Condensate Booster pump from service due to an oil leak.

Event MaIf. No. Event Type* Event Description No.

1 n/a R-RO Reduce power to 95% at 2%/mm using AOl-39, Rapid Load N-BOP/SRO Reduction.

2 rx02a I-RD Loop 1 RCS Cold Leg RTD fails high.

TS-SRO 3 rx2O 1-BOP 1-PT-i -33, MAIN STEAM PRESS fails high.

4 rc07a C-RD I -PCV-68-334, PZR PORV fails open TS-SRO 5 ccO4 C-BOP A leak develops on the RCP oil cooler supply header line inside containment.

6 rpOl c M-ALL Reactor fails to trip (ATWS). Requires entry into FR-S.1, Nuclear Power Generation/ATWS. RCPs are left in service until reactor power is reduced below 5%.

7 siO8g C-BOP ALL AFW pumps fail to automatically start. Requires the BOP to si08h manually start each AFW pump.

rp55c 8 msOl a M-ALL Main steam line break on Loop 1 inside containment.

(N)ormal, (R)eactivity, (I )nstrument, (C)omponent, (M)ajor Appendix D Watts Bar Examination October 2011 NUREG 1021 Revision 9

ppendix D Scenario Outline Form ES-D-1 Scenario 2 - Summary Initial Condition 100% power, RCS boron concentration 1031 ppm. Control Bank D at 220 steps.

Turnover Train B/Channel II Work Week. 1 B-B RHR pump is out of service for motor winding inspection. LCO 3.5.2 and 3.6.6 were entered 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ago. 1 B-B RHR pump is expected to be returned to service in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . Protected equipment signs have been posted for IA-A RHR pump. A power reduction to 95% at 2%/mm using AOI-39, Rapid Load Reduction, is required to be performed to remove the I B Condensate Booster pump from service due to an oil leak.

Event 1 Reduce power to 95% at 2%/mm using AOl-39, Rapid Load Reduction, to remove the 1 B Condensate Booster pump from service.

Event 2 Loop 1 RCS Cold Leg RTD fails high. Requires the RO to take IMMEDIATE OPERATOR ACTION to place to place rod control to MANUAL to stop rod motion. Requires entry into AOl-2, Malfunction of Reactor Control System.

Requires a Tech Spec evaluation and entry into multiple Actions of LCO 3.3.1.

Event 3 1-PT-i -33, MAIN STEAM PRESS fails high causing 1-PC-46-20, MFPT A & B MASTER SPEED CONTROL to raise MFP speed. Requires the BOP to place 1-PC-46-20 in MANUAL to control speed. Requires entry into AOl-I 6, Loss of Normal Feedwater, Section 3.6, MEW pump speed control circuit failure.

Event 4 1-PCV-68-334, PZR PORV fails open. Requires the RO to take IMMEDIATE OPERATOR ACTION to attempt to close I -HS-68-334A and/or to close 1 -HS 332A, BLOCK VALVE FOR PORV 334. Requires entry into AOl-i 8, Malfunction of Pressurizer Pressure Control System, Section 3.2, PZR Pressure Drop Due to Failed PORV/Safety or Spray Valve. Requires a Tech Spec evaluation and entry into LCO 3.4.11.

Event 5 A leak develops on the RCP oil cooler supply header line inside containment.

Requires entry into AOl-I 5, Loss of Component Cooling Water (CCS). After the RCP oil cooler flow path is isolated, a manual reactor trip to remove the RCPs from service is required.

Event 6 Reactor fails to trip (ATWS). Requires entry into FR-S.1, Nuclear Power Generation/ATWS. Per FR-S.1, the RCPs are left in service until reactor power is reduced below 5%.

Event 7 ALL AFW pumps fail to automatically start. Requires the BOP to manually start each AFW pump.

Event 8 Main steam line break on Loop 1 inside containment. Requires performance of E-0, Reactor trip or Safety Injection, and E-2, Faulted Steam Generator Isolation, after FR-Si, Nuclear Power Generation/ATWS, allows performance.

Appendix D Watts Bar Examination October 2011 NUREG 1021 Revision 9

ppendix D Scenario Outline Form ES-D-1 Scenario 2 Critical Task Summary Critical Task 1 Insert negative reactivity into the core by inserting control rods.

Critical Task 2 Isolate the faulted steam generator prior to exiting E-2, Faulted Steam Generator Isolation.

Appendix D Watts Bar Examination October2011 NUREG 1021 Revision 9

Watts Bar Nuclear Plant 10-2011 NRC Examination Scenario 2 Simulator Console Operators Instructions SIMULATOR SETUP INFORMATION ENSURE Examination Security has been established.

2. RESET to Initial Condition 301 by performing the following actions:

a. Select lCManager on the THUNDERBAR menu (right hand side of Instructor Console Screen).

b. Locate IC# 301.

c. Right click on IC# 301.

d. Select Reset on the drop down menu.

e. Right click on RESET.

f. Enter the password for IC 301.

g. Select Yes on the INITIAL CONDITION RESET pop-up window.

h. Perform SWITCH CHECK.

3. SELECT Director on the THUNDERBAR menu (right hand side of Instructor Console Screen).

4 ENSURE the following information appears on the Director Screen:

T Key Description Type Event Delay Inserted Ramp Initial Final Value rp55c failure of auto start on turbine driven aux feedpump M 00:00:00 00:00:00 00:00:00 Active Active hs-74-21a-1 01170 rhr pmp bb suct fr ctmt sm(green) 0 00:00:00 00:00:00 00:00:00 0ff Off hs-63-73a-1 01240 hr pmp b-v motor switch(green) 0 00:00:00 00:00:00 00:00:00 0ff Off siO8h failure of auto si and blackout signals afwp 1 b-b M 00:00:00 00:00:00 00:00:00 Active Active hs-74-20a-1 01240 hr pmp b-b motor switch(green) 0 00:00:00 00:00:00 00:00:00 Page 1 of 4

Watts Bar Nuclear Plant 10-2011 NRC Examination Scenario 2 Simulator Console Operators Instructions SIMULATOR SETUP INFORMATION Key Description Type Event Delay Inserted Ramp Initial Final Value

[ rhOib rhr pump btrip 0 00:00:00 00:00:00 00:00:00 Active Active rp0ic manual and automatic reactor trip signal failure (atws) M 00:00:00 00:00:00 00:00:00 Active Active sio8g failure of auto si and blackout signals afwp 1 a-a M 00:00:00 00:00:00 00:00:00 Active Active rx02a cold leg 1 rtd 1 failure M 2 00:00:00 00:00:00 100 54.96 rx2O main steam header pressure transmitter fails to pos pt-i -33 M 3 00:00:00 00:00:00 100 76.55 rc07a przr porv pcv-68-334 fail to any positiion M 4 00:00:00 00:00:00 100 0 ccO4 comp cool pipe break inside containment M 5 00:00:00 00:00:00 94.5 0 ms0ia main steam line break inside containment sg #1 M 7 00:00:15 00:00:45 6 0 rp5ib reactor trip breaker rtb trip M 6 00:00:00 00:00:00 Active InActive rp5i a reactor trip breaker rta trip M 6 00:00:00 00:00:00 Active InActive

5. Place simulator in RUN and acknowledge any alarms.

6. ENSURE 1-HS-74-20A, B RHR PMP (ECCS) is in Stop, Pull-to-Lock position and a Hold Notice (Red) Tag is placed on the handswitch. Place pink PROTECTED EQUIPMENT tag on 1-HS-74-IOA, RHR PMP A (ECCS.

ENSURE the Train B Week Channel II sign is placed on 1-M-30.

9. Place simulator in FREEZE.

ID. ENSURE Watts Bar Nuclear Plant Unit I Reactivity Briefing Book (Simulator Copy) BOL (Beginning Of Life) is provided to the crew as part of the Turnover Package, and that the BOL placards are on 1-M-6, below the Boric Acid and Primary Water Integrators.

11. WHEN prompted by the Chief Examiner, place the Simulator in RUN.

Page 2 of 4

Watts Bar Nuclear Plant 10-2011 NRC Examination Scenario 2 Simulator Console Operators Instructions xam Simulator Event Event DescriptionlRole Play No. No.

I n/a Power reduction to 95% at 2%/mm using AOI-39, Rapid Load Reduction.

ROLE PLAY: When contacted as Load Coordinator;, the repeat back the information provided.

(SRO may contact the SM to make notification.)

ROLE PLAY: If contacted as Cnds Demin AUO for notification of pump shutdowns, acknowledge the request.

ROLE PLAY: If contacted as Shift Manager to refer to EPIP-1, acknowledge the request.

2 2 Loop I RTD failure ROLE PLAY: When contacted as Maintenance/Work Control, repeat back request for performance of IMI-160.

ROLE PLAY: When contacted as Work Control, repeat back request to have a troubleshooting and repair package made up for Loop I RCS Temperature instrument.

3 3 1-PT-I -33, MAIN STEAM PRESS fails low.

ROLE PLAY: When contacted as Work Control, repeat back request for a troubleshooting and repair package for 1-PT-1-33, MAIN STEAM PRESS.

ROLE PLAY: If/when dispatched as the TB AUO, repeat back request to inspect 1-PT-1-33 for leaks. Report back that there are no leaks visible.

4 4 1-PCV-68-334 PZR PORV fails open.

ROLE PLAY: When contacted as Work Control, repeat back request to have power removed from 1-FCV-68-332 BLOCK VLV FOR PZR PORV334 within one hour.

ROLE PLAY: When contacted as Work Control, repeat back request for a troubleshooting and repair package for 1-PCV-68-334 PZR PORV.

Page 3 of 4

Watts Bar Nuclear Plant 10-2011 NRC Examination Scenario 2 Simulator Console Operators Instructions Exam Simulator vent Event Description/Role Play No.

j 5,6,7 5&7 CCS RCP Oil Cooler Leak/Reactor fails to trip (ATWS)/Loop I SLB Inside Containment.

and 8 ROLE PLAY: If contacted as Aux Bldg AUO to check for leakage in the CCS, state that there is no leakage indicated in the Aux Building.

ROLE PLAY: If contacted as Aux Bldg AUO to check lB CCP for start, state it checks Normal locally and is ready for start.

ROLE PLAY: When contacted as the Control Building AUO, repeat back request to open the reactor trip breakers and MG set output breakers locally. AFTER 2 minutes, delete malfunction rpOlc, and enter Event 6, which will open the reactor trip breakers.

ROLE PLAY: When contacted as the Turbine Building AUO, repeat back request to open breakers to the MG sets.

ROLE PLAY: When contacted as Shift Manager to refer to EPIP-1, acknowledge the request.

ROLE PLAY: When contacted as AUO to perform Attachment I of E-O, acknowledge the request and report complete.

ROLE PLAY: When contacted as the Auxiliary Building AUO, repeat back request to shutdown sample pumps for I-RM-90-106 and l-RMO-90-112.

ROLE PLAY: When contacted as Chemistry, repeat back request for SG samples for activity.

Page 4 of 4

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario # 2 Event # 1 Page 1 of 34 Event

Description:

Reduce power to 95% at 2%/mm using AOl-39, Rapid Load Reduction.

Time Position Applicants Actions or Behavior AOI-39 The following actions are taken from AOl-39, Rapid Load Reduction.

CAUTION Over boratiori may result in excessive rod withdrawal, T-avg lower than desired, and AFD oscillations.

NOTE

Rod Control should remain in automatic for T-avg Control

Reactivity Briefing Sheet, Thumb Rules (page 3), lists boration flows and volumes for different reduction rates.

Effect of boration will lag behind turbine load reduction and can be compensated for by temporarily increasing boric acid flow rate above recommended rate.

1. INITIATE a manual boration:

a. DETERMINE recommended boration flow rate and volume from Reactivity Briefing Sheet:

b. INITIATE normal boration:

1) ADJUST BA flow controller, 1 -FC-62-1 39, to desired flow rate.

RO adjusts 1-Fl-62-139, BA TO BLENDER FCV-62-140 CONTROL to approximately 78%, which corresponds to RD approximately 31 gpm.

2) ADJUST BA batch counter 1-FQ62-139 to required quantity.

RO sets the batch counter to 000160 to add 160 gallons of boron, based on the Reactivity Briefing Book Thumb Rule values.

3) PLACE mode selector 1 -HS-62-1 40B to BOR.

4) (p) PLACE VCT makeup control 1-HS-62-140A, to START.

5) VERIFY desired boric acid flow indicated on 1-Fl-62-139.

CAUTION

Condenser Backpressure limits are on page 5.

TURBINE MANUAL Operation requires continuous operator monitoring and control.

LOSS OF CONDENSER VACUUM may be made worse if steam dumps are actuated. AOl 11 requires T-ave and T-ref be maintained within 3°F.

NOTE If the initiating condition is corrected, the power reduction may be terminated 2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: 2 Scenario# 2 Event# 1 Page 2 of 34 Event

Description:

Reduce power to 95% at 2%/mm using AOl-39, Rapid Load Reduction.

Time Position Applicants Actions or Behavior

2. ESTABLISH a turbine load reduction rate less than or equal to 5%/mm:

a. PLACE turbine in IMP IN BOP depressed the IMP IN pushbutton and observes the transfer from IMP OUT to IMP IN control complete.

b. SET a desired load in the SETTER with the REFERENCE CONTROL.

BOP BOP depresses the reference control V (down) button to reduce the setter display to less than 95% load as directed by the SRO.

c. SET the LOAD RATE at less than or equal to 5%/rn in.

BOP selects the load reduction rate directed by the SRO using the LOAD RATE % PER MIN thumbwheel selector. It is expected that a load reduction rate of 2%/minute will be used.

d. (p) DEPRESS GO pushbutton.

BOP depresses the REFERENCE CONTROL GO button.

NOTE AFD green target band can be monitored using ICS Turn On code DOGHOUSE.

3. MONITOR rod position:

RO

Rods above Lo-Lo insertion limit

AFD within Target Band

4. REFER TO EPIP-1, Emergency Plan Classification Flowchart SRO SRO may request Shift Manager to Refer to EPIP-1 Console Operator will acknowledge the requesL

5. NOTIFY the Load Coordinator of the required load reduction and expected ramp rate.

SRO When the SRO contacts Load Coordinato,, the Console Operator will repeat back the information provided. SRO may contact the Shift Manager to make the notifications.

NOTE If reactor power is stabilized at a lower level a drop in T-avg will occur due to Xenon build up.

Dilution may be required to maintain power level.

6. MONITOR T-avg and T-ref:

RO

T-ave trending to T-ref.

Mismatch less than 5F.

7. CHECK rate of power reduction is rapid enough for existing plant SRO conditions.

2011-10 Watts Bar NRC Examination

I Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario # 2 Event # 1 Page 3 of 34 Event

Description:

Reduce power to 95% at 2%/mm using AOl39, Rapid Load Reduction.

Time Position Applicants Actions or Behavior

8. NOTIFY Cnds Demin AUO of impending pmp shutdowns.

BOP When Cnds Demin AUO is notified or impending pmp shutdowns, Console Operator will acknowledge the request.

9. WHEN rated thermal power change exceeds 15% in one hour, SRO THEN NOTIFY Chemistry to initiate 1-SI-68-28.

EXAMINER: When power has been dropped to 95%, cue the Console Operator to enter Event 2.

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D-?J Op Test No.: 2 Scenario # 2 Event # 2 Page 4 of 34 Event

Description:

Loop 1 RCS Cold Leg RTD fails high. Requires the RO to take IMMEDIATE OPERATOR ACTION to place to place rod control to MANUAL to stop rod motion.

Requires entry into AOl-2, Malfunction of Reactor Control System. Requires a Tech Spec evaluation.

Time Position Applicants Actions or Behavior Indications:

Loop 1 Tavg Indicator 1-Tl-68-2E [M-5] indicates high.

93-A RCS LOOP AT DEVIATION 94-A TAVG-TREF DEVIATION 94-B TAVG-T AUCT DEVIATION 90-F EAGLE PROC PROT CHANNEL I RTD FAILURE 110-F PROT SET TROUBLE 123-C OVERTEMP AT TRIP ALERT 123-D OVERTEMP AT TURB RUNBACK & C-3 ROD BLOCK Will perform IMMEDIATE ACTION step of AOI-2, Malfunction of Reactor Control System, Section 3.2, Uncontrolled Rod Bank RO Movement, to PLACE control rods in MANUAL and to CHECK control rod movement has stopped.

May enter and perform initial actions of ARI-94-A, TAVG-TREF RO DEVIATION, and refer to AOI-2.

Enters and directs actions of AOI-2, Malfunction of Reactor Control SRO System, Section 3.2, Uncontrolled Rod Bank Movement.

ARI94-A The following steps are the first 4 steps from ARI 94-A, TAVG TREF DEVIATION.

RO [1] CHECK Loop Tavg on 1-TI-68-2E, -25E, -44E, and -67E [1-M-5].

[2] IF Tavg is less than or equal to 561 °F, THEN PERFORM 1-SI-RO 68-34 within 30 minutes.

RO [3] CHECK Tref & Auct Tavg recorder I -TR-68-2B [1 -M-5].

[4] IF control rods are in AUTO, THEN:

[4.1] PLACE control rods in MANUAL AND RESTORE Tavg to RO Tref using rods OR ADJUST turbine load to match Tavg with Tref.

[4.2] REFER TO AOI-2.

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: 2 Scenario # 2 Event # 2 Page 5 of 34 Event

Description:

Loop I RCS Cold Leg RTD fails high. Requires the RO to take IMMEDIATE OPERATOR ACTION to place to place rod control to MANUAL to stop rod motion.

Requires entry into AOl-2, Malfunction of Reactor Control System. Requires a Tech Spec evaluation.

Time Position j Applicants Actions or Behavior The following actions are taken from AOl-2, Malfunction of AOI-2 Reactor Control System, Section 3.2, Uncontrolled Rod Bank Movement.

NOTE Step I is an IMMEDIATE ACTION step

1. STOP uncontrolled rod motion:

a. PLACE control rods in MAN.

RO b. CHECK control rod movement STOPPED.

Since these are IMMEDIATE ACTION steps, the actions have already been taken.

EXAMINER: AOI-2, Attachment I is included in the scenario as Attachment I.

2. MAINTAIN T-ave on PROGRAM. (Reference Attachment 1)

(p) USE control rods.

RO OR

(p) ADJUST turbine load.

RO 3. CHECK loop T-ave channels NORMAL.

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario # 2 Event # 2 Page 6 of 34 Event

Description:

Loop I RCS Cold Leg RTD fails high. Requires the RO to take IMMEDIATE OPERATOR ACTION to place to place rod control to MANUAL to stop rod motion.

Requires entry into AOl-2, Malfunction of Reactor Control System. Requires a Tech Spec evaluation.

Time Position Applicants Actions or Behavior

3. RESPONSE NOT OBTAINED:

DEFEAT failed channels:

a. PLACE 1-XS-68-2D, T CHANNEL DEFEAT, to failed channel position, AND PULL.

RO will rotate 1-XS-68-2D to the LOOP I position and then pull out the selector switch.

b. PLACE 1-XS-68-2M, TAVG CHANNEL DEFEAT, in failed channel position AND PULL.

RO will rotate I-XS-68-2M to the LOOP I position and then pull out the selector switch.

ENSURE TR-68-2A placed to a Loop with operable T/OTAT/OPtiT channels using 1-XS-68-2B.

SInce I-XS-68-2B is selected to LOOP I, the RO will select any other loop as input to the recorder.

NOTIFY Maintenance to implement lMl-160 for failed channel.

RO SRO will contact Maintenance/Work Control and request performance of IMI-160. Console Operator will repeat back request.

WHEN at least 5 minutes have elapsed since failed T-ave channel is defeated AND auto rod control desired, THEN

a. ENSURE T-ave and T-ref within 1°F.

RO observes T-avg and T-ref within I F on I-TR-68-2B, TREF &

AUCTTAVG-°F.

b. ENSURE zero demand on control rod position indication

[1 -M-4].

RO observes that there is a zero demand indicated on the PASSIVE SUMMER ROD DEMAND on both CERPI displays.

c. PLACE rods in AUTO.

RO rotates I-RBSS from the MANUAL position to the right to the AUTO position.

4. CHECK Auct T-avg NORMAL on 1 -TR-68-2B.

RO After Step 3 is performed and the failed channel is defeated, Auct Tavg will indicate NORMAL on I-TR-68-2B.

5. CHECK NIS power range channels NORMAL.

RO RO observes all NIS channels are indicating the same values and are NORMAL.

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario# 2 Event# 2 Page 7 of 34 Event

Description:

Loop 1 RCS Cold Leg RTD fails high. Requires the RO to take IMMEDIATE OPERATOR ACTION to place to place rod control to MANUAL to stop rod motion.

Requires entry into AOl-2, Malfunction of Reactor Control System. Requires a Tech Spec evaluation.

Time Position Applicants Actions or Behavior

6. CHECK the following:

Turbine impulse pressure channel 1-Pl-1-73, NORMAL.

BOP observes that I-P1-1-73, % HP TURBINE POWER TR A is matched with 1-Pl-1-7Z % HP TURBINE POWER TR B and both RO are NORMAL.

T-ref and Auct T-avg NORMAL on 1 -TR-68-2B (Reference Attachment 1).

After failed loop AT and loop T-avg channels have been defeated in Step 3 RNO, TrefandAuct Tavg are NORMAL.

7. MONITOR core power distribution parameters:

Power range channels

t Flux Indicators SRO *T-ave

Loop1T

lncore TCs

Feed flow/Steam flow

8. INITIATE repairs to failed equipment.

SRO SRO contacts Work Control to have a troubleshooting and repair package made up for Loop I RCS Temperature instrument.

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: 2 Scenario# 2 Event# 2 Page 8 of 34 Event

Description:

Loop 1 RCS Cold Leg RTD fails high. Requires the RO to take IMMEDIATE OPERATOR ACTION to place to place rod control to MANUAL to stop rod motion.

Requires entry into AOI-2, Malfunction of Reactor Control System. Requires a Tech Spec evaluation.

Time I Position Applicants Actions or Behavior

9. REFER TO Tech Specs:

. 3.1.1, Shutdown Margin Not applicable.

. 3.1.5, Rod Group Alignment Limits Not applicable.

. 3.1 .6, Shutdown Bank Insertion Limits Not applicable.

. 3.1.7, Control Bank Insertion Limits Not applicable.

e 3.2.1, Heat Flux Hot Channel Factor Not applicable.

. 3.2.2, Nuclear Enthalpy Rise Hot Channel Factor Not -

applicable.

. 3.2.4, Quadrant Power Tilt Ratio Not applicable.

. 3.2.3, Axial Flux Difference Not applicable.

3.3.1-1, Rx Trip System (RTS)

SRO Function 6. Overtemperature AT Condition W. Place channel in trip within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR be in Mode 3 within 78 hours9.027778e-4 days 0.0217 hours 1.289683e-4 weeks 2.9679e-5 months .

Function 7. Overpower AT Condition W. Place channel in trip within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months OR reduce THERMAL POWER to <P-7.

SG level trip LCO is not applicable, since Loop I does not input into the TTD circuitry.

3.3.2-1, ESFAS Instrumentation.

AFW pump start logic LCO is not applicable, since Loop I does not input into the TTD circuitry.

10. NOTIFY Chemistry of any reactor power changes greater than 15% in one hour.

SRO Power change has not exceeded 15%, so this step is not applicable.

1 1. WHEN ready to restore repaired T and loop T-avg channels, THEN:

PUSH IN 1-XS-68-2D, LiT CHANNEL DEFEAT and SELECT AWAY from all channels.

SRO

PUSH IN 1-XS-68-2M, TAVG CHANNEL DEFEAT, and SELECT AWAY from all channels.

SRO determines that the conditions of this step are not met and continues to the next step.

CAUTION Allowing at least 5 minutes between any rod control input change (i.e., T-ave, T-ref, or NIS) and placing rods in AUTO, will help prevent undesired control rod movement.

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario # 2 Event # 2 Page 9 of 34 Event

Description:

Loop 1 RCS Cold Leg RTD fails high. Requires the RO to take IMMEDIATE OPERATOR ACTION to place to place rod control to MANUAL to stop rod motion.

Requires entry into AOl-2, Malfunction of Reactor Control System. Requires a Tech Spec evaluation.

Time Position Applicants Actions or Behavior

12. WHEN auto rod control desired, THEN:

a. ENSURE T-ave and T-ref within 1 °F.

RO withdraws control rods in MANUAL to match T-avg and T-ref within I F.

b. ENSURE zero demand on control rod position indication

[1-M-4j.

SRO RO observes that there is a zero demand indicated on the PASSIVE SUMMER ROD DEMAND on both CERPI displays.

c. PLACE rods in AUTO.

RO rotates I-RBSS from the MANUAL position to the right to the AUTO position.

13. WHEN conditions allow auto PZR level control, THEN ENSURE PZR level returned to normal program, AND PLACE 1-FCV 93 in AUTO.

SRO If action was taken earlier to take manual control of PZR level, the RO will place I-HIC-62-93A in AUTO after verifying level has been returned to program.

SRO 14. RETURN TO Instruction in effect.

EXAMINER: The crew briefing is optional. The next event may be entered prior to the brief.

Crew Brief would typically be conducted for this event as time allows SRO prior to the next event.

Notifications should be addressed as applicable if not specifically addressed by the procedure or in the crew brief.

Operations Management Typically Shift Manager.

SRO -

Maintenance Personnel Typically Work Control Center (WCC).

(Note: Maintenance notification may be delegated to the Shift Manager).

Cue Console Operator to insert Event 3, if not already entered.

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario # 2 Event # 3 Page 10 of 34 Event

Description:

1-PT-i -33, MAIN STEAM PRESS fails high causing 1-PC-46-20, MFPT A & B MASTER SPEED CONTROL to raise MFP speed. Requires the BOP to place 1-PC-46-20 in MANUAL to control speed. Requires entry into AOl-i 6, Loss of Normal Feedwater, Sub section 3.6, MEW pump speed control circuit failure.

Time N Position Applicants Actions or Behavior Indications:

57-B, #1 HEATERS FW SUPPLY PRESS HI 63-F SG LEVEL DEVIATION Diagnoses and announces the failure of 1-PT-1-33, MAIN STEAM BOP PRESS high.

May enter and take actions of ARI 57-B, #1 HEATERS FW BOP SUPPLY PRESS HI.

BOP May enter and take actions of ARI 63-F SG LEVEL DEVIATION.

Enters and directs actions of AOl-i 6, Loss of Normal Feedwater, SRO Section 3.6, MEW pump speed control circuit failure.

[4] ENSURE feedwater regulating valves are maintaining SG levels BOP on program.

[5] REFER TO SOl-2&3.01, CONDENSATE & FEEDWATER SRO SYSTEM, for operation of Feed Pump(s) in service.

SRO [6] INITIATE Service Request for corrective action, if necessary.

The following actions are taken from AOl-I 6, Loss of Normal AO1-16 Feedwater, Section 3.6, MEW pump speed control circuit failure.

1. CONTROL MFP speed using MANUAL control of master controller or individual controller(s) as required.

BOP BOP places 1-PC-46-20, MFPTA & B MASTER SPEED CONTROL in MANUAL by lifting the toggle switch from the AUTO position, and then move to the left to lower MFP IA and lB speed

2. PLACE control rods in MANUAL.

RO SRO directs the RO to place 1-RBSS ROD BANK SELECT in MANUAL.

3. CHECK MEW pumps recirc valves CLOSED.

BOP BOP checks I-FIC-3-70 MFWP A RECIRC CONTROL and 1-FIC-3-84 MFWP B RECIRC CONTROL CLOSED by observing valve position demand indications.

4. (p) ENSURE T-avg and T-ref within 30 RD RO observes Tref-Auct Tavg on I-TR-68-2B and determines that Auct T-avg and T-ref are within 3°F.

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario # 2 Event # 3 Page ii of 34 Event

Description:

1-PT-i -33, MAIN STEAM PRESS fails high causing 1-PC-46-20, MFPT A & B MASTER SPEED CONTROL to raise MFP speed. Requires the BOP to place I PC-46-20 in MANUAL to control speed. Requires entry into AOl-16, Loss of Normal Feedwater, Sub section 3.6, MEW pump speed control circuit failure.

Time Position Applicants Actions or Behavior

5. MAINTAIN MFWP discharge press on PROGRAM.

BOP BOP may adjust 1-PC-46-20, MFPTA & B MASTER SPEED CONTROL in MANUAL to return MFWP discharge pressure to program (1-FC-46-20 provides program.)

6. ENSURE S/G levels return to PROGRAM.

BOP BOP observes SG I through SG 4 levels on I-M-4 instruments and determines that levels are returning to normal.

7. CHECK steam dump mode in TAVG position.

BOP BOP determines that I-HS-103D STEAM DUMP MODE handswitch is in the TA VG position.

8. INITIATE repairs to failed equipment.

BOP SRO contacts Work Control and requests a troubleshooting and repair package for I-PT-I-33, MAIN STEAM PRESS.

9. WHEN auto rod control desired, THEN:

a. ENSURE T-ave and T-ref within 1 F.

RO observes T-avg and T-ref within I F on I-TR-68-2B, TREF &

AUCT TAVG °F. -

b. ENSURE zero demand on control rod position indication [1-M-4].

RO RO observes that there is a zero demand indicated on the PASSIVE SUMMER ROD DEMAND on both CERPI displays.

c. PLACE rods in AUTO.

RO rotates 1-RBSS from the MANUAL position to the right to the AUTO position.

10. WHEN MFP pump control repairs completed, THEN PLACE MFP speed control in AUTO.

BOP SRO determines that repairs will not be completed and directs the BOP to maintain I-PC-46-20 in MANUAL.

11. RETURN TO Instruction in effect.

SRO SRO determines that the procedure section will remain open until repairs are complete.

EXAMINER: The crew briefing is optional. The next event may be entered prior to the brief.

Crew Brief would typically be conducted for this event as time SRO allows prior to the next event.

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: 2 Scenario # 2 Event # 3 Page 12 of 34 Event

Description:

1-PT-i -33, MAIN STEAM PRESS fails high causing i-PC-46-20, MFPT A & B MASTER SPEED CONTROL to raise MFP speed. Requires the BOP to place 1-PC-46-20 in MANUAL to control speed. Requires entry into Aol-i 6, Loss of Normal Feedwater, Sub section 3.6, MFW pump speed control circuit failure.

Time 1 Position Applicants Actions or Behavior Notifications should be addressed as applicable if not specifically addressed by the procedure or in the crew brief.

Operations Management Typically Shift Manager.

SRO Maintenance Personnel Typically Work Control Center (WCC).

(Note: Maintenance notification may be delegated to the Shift Manager).

Cue Console Operator to insert Event 4, if not already entered.

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: 2 Scenario # 2 Event # 4 Page 13 of 34 Event

Description:

1-PCV-68-334, PZR PORV to open. Requires the RO to take IMMEDIATE OPERATOR ACTION to attempt to close 1-HS-68-334A and/or to close 1-HS 332A, BLOCK VALVE FOR PORV 334. Requires entry into AOl-I 8, Malfunction of Pressurizer Pressure Control System, Section 3.2, PZR Pressure Drop Due to Failed PORV/Safety or Spray Valve. Requires a Tech Spec evaluation.

Time Position Applicants Actions or Behavior Indications:

91-A PZR PORV/SAFETY OPEN 90-B PZR PRESS LO DEVN BACKUP HTRS ON Diagnoses and announces the failure open of 1-PCV-68-334, PZR RO PORV.

Performs IMMEDIATE OPERATOR ACTIONS of AOl-I 8, Malfunction of Pressurizer Pressure Control System, Section 3.2, RO PZR pressure drop due to failed PORV/Safety or spray valve.

RO CLOSES 1-HS-68-332A BLOCK VALVE FOR PORV 334.

Enters and directs actions of AOl-i 8, Malfunction of Pressurizer SRO Pressure Control System, Sub section 3.2, PZR pressure drop due to failed PORV/Safety or spray valve.

The following actions are taken from AOl-I 8, Malfunction Of AOI-18 Pressurizer Pressure Control System, Section 3.2, PZR pressure drop due to failed PORVISafety or spray valve.

NOTE Step 1 and 2 are IMMEDIATE ACTION steps

1. CHECK PZR spray valves CLOSED:

Green indicating lights LIT RO observes GREEN light LIT on 1-XI-68-340D. PZR SPRAY LOOP I and 1-XI-68-334B, PZR SPRAY LOOP 2.

RO

Pzr spray demand meters, 1 -PIC-68-334B and I -PIC-68-334D indicating ZERO [1 -M-4j RO observes position indications for I-PIC-68-334D, PZR SPRAY LOOP I, and 1-PIC-68-334B, PZR SPRAY LOOP 2.

2. CHECK PZR PORVs CLOSED

PORV indicating lights RO observes I-HS-68-334A RED indicating light is LIT, GREEN indicating light is DARK.

tailpipe temperature RO RO observes elevated temperature on 1-Tl-68-331, PORV 334A &

334 TAILPIPE TEMP.

acoustic monitoring BOP maybe sent to observe 1-XI-68-363, PZR VALVES ACOUSTIC MONITOR. If dispatched, the BOP observes 1-XI 334A indicating lights are LIT.

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario # 2 Event # 4 Page 14 of 34 Event

Description:

1-PCV-68-334, PZR PORV to open. Requires the RO to take IMMEDIATE OPERATOR ACTION to attempt to close 1-HS-68-334A and/or to close 1-HS 332A, BLOCK VALVE FOR PORV 334. Requires entry into AOI-18, Malfunction of Pressurizer Pressure Control System, Section 3.2, PZR Pressure Drop Due to Failed PORV/Safety or Spray Valve. Requires a Tech Spec evaluation.

Time Position Applicants Actions or Behavior

2. RESPONSE NOT OBTAINED:

IF PZR press is less than 2335, THEN CLOSE PORV OR CLOSE associated block valve.

RO Since this is an IMMEDIATE ACTION step, it is expected that 1-HS-68-334A may be in the CLOSE position AND 1-HS-68-332A will be in the CLOSED position.

3. VERIFY actions taken in Steps 1 and 2 have STOPPED press drop.

RO RO observes RCS pressure on 1-PI-68-334A, I-P1-68-334, 1-PI-68-323, 1-P1-68-322, PZR PRESS rising.

4. CHECK PZR Safeties CLOSED:

tailpipe temperatures RO RO observes elevated temperature on 1-TI-68-331, PORV 334A &

334 TAILPIPE TEMP.

acoustic monitor BOP BOP may be sent to observe 1-XI-68-363, PZR VALVES ACOUSTIC MONITOR. If dispatched, the BOP observes 1-XI 334 indicating lights are LIT.

5. ENSURE PZR heaters on as required:

RO

Control Group on at 2220 psig

Backup Groups on at 2210 psig

6. CHECK aux spray, 1-FCV-62-84, CLOSED.

RO RO observes handswitch I-HS-62-84, A UX SPRAY TO PZR, in the CLOSED position with the RED indicating light DARK and the GREEN indicating light LIT.

7. CHECK PZR press STABLE or RISING.

RO RO observes RCS pressure on 1-PI-68-334A, 1-Pl-68-334, 1-PI-68-323, 1-PI-68-322, PZR PRESS rising.

8. WHEN pressurizer pressure stable and equipment status supports returned to normal, THEN ENSURE the following in AUTO:

RO

PZR Master controller

PZR spray controllers

All heater groups 2011-10 Watts Bar NRC Examination

[ Appendix D Required Operator Actions Form ES-D-2 OpTestNo.: 2 Scenario # 2 Event # 4 Page 15 of 34 Event

Description:

1-PCV-68-334, PZR PORV to open. Requires the RD to take IMMEDIATE OPERATOR ACTION to attempt to close I -HS-68-334A andlor to close I -HS 332A, BLOCK VALVE FOR PORV 334. Requires entry into AOl-I 8, Malfunction of Pressurizer Pressure Control System, Section 3.2, PZR Pressure Drop Due to Failed PORV/Safety or Spray Valve. Requires a Tech Spec evaluation.

Time I Position Applicants Actions or Behavior

9. REFER TO the following Tech Specs:

3.3.1, RTS Instrumentation Not applicable

3.3.2, Engineered Safety Feature Actuation System (ESFAS)

Instrumentation Not applicable

3.3.4, Remote Shutdown System Not applicable

3.4.1, RCS Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits May be applicable, depending upon severity of pressure drop when the PORV opened.

3.4.3, RCS Pressure and Temperature (PIT) Limits Not SRO applicable

3.4.9, Pressurizer Not applicable

3.4.10, Pressurizer Safety Valves Not applicable

3.4.11, Pressurizer Power-Operated Relief Valves Condition B. One PORV inoperable and not capable of being manually cycled.

Close associated block valve within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months .

AND Remove power from associated block valve within 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months AND Restore PORV to OPERABLE status within 72 hours8.333333e-4 days 0.02 hours 1.190476e-4 weeks 2.7396e-5 months .

10. INITIATE repairs to failed equipment.

When SRO contacts Work control to have power removed from 1-FCV-68-333 BLOCK VLV FOR PZR PORV 334A, and for a troubleshooting and repair package for 1-PCV-68-334, repeat back request.

11. RETURN TO Instruction in effect.

EXAMINER: The crew briefing is optional. The next event may be entered prior to the brief.

Crew Brief would typically be conducted for this event as time SRO allows prior to the next event.

Notifications should be addressed as applicable if not specifically addressed by the procedure or in the crew brief.

Operations Management Typically Shift Manager.

SRO Maintenance Personnel Typically Work Control Center (WCC).

(Note: Maintenance notification may be delegated to the Shift Manager).

Cue Console Operator to insert Event 5, if not already entered.

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario # 2 Event # 5,6, 7 and 8 Page 16 of 34 Event

Description:

5) A leak develops on the RCP oil cooler supply header line inside containment.

Requires entry into Aol-i 5, Loss of Component Cooling Water (CCS). After the RCP oil cooler flow path is isolated, requires a manual reactor trip to remove the RCPs from service. 6) Reactor fails to trip (ATWS). Requires entry into FR-S.i, Nuclear Power Generation/ATWS. RCPs are left in service until reactor power is reduced below 5%. 7) ALL AFW pumps fail to automatically start. Requires the BOP to manually start each AFW pump. 8) Main steam line break on Loop 1 inside containment. Requires performance of E-0, Reactor trip or Safety Injection and E-2, Faulted Steam Generator Isolation, after FR-S.i, Nuclear Power Generation/ATWS, allows performance.

Time Position Applicants Actions or Behavior Indications:

237-C RCP I OIL CLRS RET FLOW LO 238-C RCP 2 OIL CLRS RET FLOW LO 239-C RCP 3 OIL CLRS RET FLOW LO 240-C RCP 4 OIL CLRS RET FLOW LO BOP Diagnoses and announces the leak on the RCP oil cooler line.

May enter and take actions of ARI 237(238, 239, 240)-C RCP 1 BOP (2, 3, 4) OIL CLRS RET FLOW LO.

Enters and directs actions of AOl-I 5, Loss of Component Cooling SRO Water (CCS).

The following actions are taken from ARI 237-C RCP I OIL CLRS ARI 237-C RET FLOW LO.

BOP [1] IF Phase B initiated, THEN GO TO Emergency Instructions.

[2] CHECK the following [0-M-27B], AND COMPARE with other RCPs:

BOP

1-FI-70-116, RCP 1 UPR OIL CLR FLOW

1 -FI-70-1 19, RCP 1 LWR OIL CLR FLOW

[3] ENSURE CCS isolation valves OPEN:

1-FCV-70-100 and -140, RCP OIL CLRS SUP CIV0B

1-FCV-70-89 and -92, RCP OIL CLRS RET CIVØB

[4] CHECK 1-PI-70-24A, CCS HX A SUP PRESS [0-M-27B], AND START CCS Pumps as necessary to maintain press between 40 and 108 psig.

[5] IF flow NOT restored, THEN:

[5.1] MONITOR RCP temps on computer.

[5.2] IF bearing temp greater than or equal to195°F, THEN GO TO AOI-24, RCP MALFUNCTIONS DURING PUMP OPERATION.

[5.3] REFER TO AOl-i 5, LOSS OF COMPONENT COOLING WATER (CCS).

[5.4] ADJUST 1 -THV-70-695A or 1 -THV-70-696A per Tl-31 .08, FLOW BALANCING VALVES SETPOINTS.

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D-2 J Op Test No.: 2 Scenario # 2 Event # 5,6, 7 and 8 Page 17 of 34 Event

Description:

5) A leak develops on the RCP oil cooler supply header line inside containment.

Requires entry into Aol-i 5, Loss of Component Cooling Water (CCS). After the RCP oil cooler flow path is isolated, requires a manual reactor trip to remove the RCPs from service. 6)Reactorfailstotrip(ATWS). Requires entry into FR-Si, Nuclear Power Generation/ATWS. RCPs are left in service until reactor power is reduced below 5%. 7) ALL AFW pumps fail to automatically start. Requires the BOP to manually start each AFW pump. 8) Main steam line break on Loop I inside containment. Requires performance of E-O, Reactor trip or Safety Injection and E-2, Faulted Steam Generator Isolation, after FR-S.i, Nuclear Power Generation/AWlS, allows performance.

Time Position Applicants Actions or Behavior AOI-15 The following actions are taken from AOl-I 5, Loss of Component Cooling Water (CCS), Section 3.2, Loss of CCS Flow.

1. CHECK CCS pumps status:

a. CHECK any CCS pump TRIPPED or running pump NOT pumping forward:

ERCW/CCS Motor tripout alarm, BOP

Low header pressure (Train A or B),

Multiple low flow alarms.

BOP observes and reports that the proper CCS pumps are in service and pumping forward.

1. RESPONSE NOT OBTAINED:

SRO

a. GO TO CAUTION prior to Step 2.

CAUTION A closed Surge Tank vent valve may cause a positive or negative tank pressure, giving an erroneous level indication.

2. CHECK i-FCV-70-66, Ui Surge Tank Vent, OPEN.

BOP BOP observes handswitch I-HS-70-66A, UI SURGE TANK VENT, RED indicating light is LIT and the GREEN indicating light is DARK.

3. IF Surge Tank level less than 57%, THEN ENSURE i-LCV-70-63, Ui Surge Tank Makeup LCV, OPEN (Refer to SOl-70.01 as required if makeup NOT available).

BOP BOP observes handswitch 1-HS-70-63A, UI SURGE TANK MAKEUP, RED indicating light is LIT and the GREEN indicating light is DARK.

BOP 4. MONITOR A and B side Surge Tank levels greater than 10%.

5. IF RHR Shutdown Cooling is inservice, THEN **

GO TO AOI-14, BOP Loss of RHR Shutdown Cooling.

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario # 2 Event # 5,6, 7 and 8 Page 18 of 34 Event

Description:

5) A leak develops on the RCP oil cooler supply header line inside containment.

Requires entry into AOl-i 5, Loss of Component Cooling Water (CCS). After the RCP oil cooler flow path is isolated, requires a manual reactor trip to remove the RCPs from service. 6) Reactor fails to trip (ATWS). Requires entry into FR-S.i, Nuclear Power GenerationlATWS. RCPs are left in service until reactor power is reduced below 5%. 7) ALL AFW pumps fail to automatically start. Requires the BOP to manually start each AFW pump. 8) Main steam line break on Loop 1 inside containment. Requires performance of E-0, Reactor trip or Safety Injection and E-2, Faulted Steam Generator Isolation, after FR-S.1, Nuclear Power Generation/ATWS, allows performance.

Time Position Applicants Actions or Behavior

6. MONITOR the following for Unit 1 CCS Train A:

U-i CCS Train A level

ERCW flow to CCS HX A BOP IF loss of either is imminent, THEN PERFORM the following:

SRO determines that although surge tank level is dropping, level loss is NOT IMMINENT and continues to the RESPONSE NOT OBTAINED column.

6. RESPONSE NOT OBTAINED:

GO TO Step 7.

7. MONITOR the following for Unit 1 CCS Train B:

U-i CCS Train B level

ERCW flow to CCS HX C IF loss of either is imminent, THEN STOP and LOCKOUT the following Train B equipment:

CCS pumps C-S & 2B-B,

CS pump lB-B,

RHR pump lB-B,

SI pump lB-B,

CCP lB-B.

SRO determines that Train B surge tank level loss is NOT IMMINENT and continues without stopping pumps.

8. CHECK all RCP upper and lower oil cooler flows NORMAL:

Upper cooler flow: 150 220 gpm.

Lower cooler flow: 5 10 gpm.

BOP observes upper and lower oil cooler flows and determines that all flows are low.

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Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario # 2 Event # 5,6, 7 and 8 Page 19 of 34 Event

Description:

5) A leak develops on the RCP oil cooler supply header line inside containment.

Requires entry into Aol-i 5, Loss of Component Cooling Water (CCS). After the RCP oil cooler flow path is isolated, requires a manual reactor trip to remove the RCPs from service. 6) Reactor fails to trip (ATWS). Requires entry into FR-S.i, Nuclear Power Generation/ATWS. RCPs are left in service until reactor power is reduced below 5%. 7) ALL AFW pumps fail to automatically start. Requires the BOP to manually start each AFW pump. 8) Main steam line break on Loop 1 inside containment. Requires performance of E-O, Reactor trip or Safety Injection and E-2, Faulted Steam Generator Isolation, after FR-S.i, Nuclear Power Generation/ATWS, allows performance.

Time Position Applicants Actions or Behavior

8. RESPONSE NOT OBTAINED:

IF oil cooler flow abnormally high or low indicating possible line break, THEN:

a. CLOSE RCP oil cooler isol valves:

1-FCV-70-100 or 1-FCV-70-140, RCP Oil Coolers Supply CIV.

BOP places at least 1-HS-70-IOOA, RCP OIL CLRS SUP CIV liB OR 1-HS-70-140A, RCP OIL CLRS SUP CIV /B in the CLOSED position.

1-FCV-70-89 or 1-FCV-70-92, RCP Oil Coolers Return CIV.

BOP places at least 1-HS-70-89A, RCP OIL CLRS RET CIV tB OR 1-HS-70-92A, RCP OIL CLRS RET CIV çtB in the CLOSED position.

CAUTION RCPs can be operated for up to 10 minutes after loss of CCS flow.

b. TRIP Reactor.

When the reactor trip is attempted, the trip is unsuccessful from both 1-RT-1 REACTOR TRIP (1-M-4) and 1-RT-2 REACTOR TRIP (1-M-6).

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Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: 2 Scenario # 2 Event # 5,6, 7 and 8 Page 20 of 34 Event

Description:

5) A leak develops on the RCP oil cooler supply header line inside containment.

Requires entry into Aol-i 5, Loss of Component Cooling Water (CCS). After the RCP oil cooler flow path is isolated, requires a manual reactor trip to remove the RCPs from service. 6) Reactor fails to trip (ATWS). Requires entry into FR-S.1, Nuclear Power Generation/ATWS. RCPs are left in service until reactor power is reduced below 5%. 7) ALL AFW pumps fail to automatically start. Requires the BOP to manually start each AFW pump. 8) Main steam line break on Loop 1 inside containment. Requires performance of E-0, Reactor trip or Safety Injection and E-2, Faulted Steam Generator Isolation, after FR-S.1, Nuclear Power Generation/ATWS, allows performance.

Time Position Applicants Actions or Behavior FR-S I When the applicants initiate a reactor trip, the trip fails. This requires entry into FR-S.1, Nuclear Power Generation/ATWS.

NOTE

Steps I thru 4 are IMMEDIATE ACTION STEPS.

. Status Trees I SPDS should be monitored when transitioned to another instruction.

Performs IMMEDIATE OPERATOR ACTIONS. Attempts to manually RO trip the reactor from 1 -M-4 and 1 -M-6. When actions are unsuccessful, the RO begins to insert the control rods.

Performs IMMEDIATE OPERATOR ACTIONS. Manually trips the BOP turbine from 1-M-2.

CAUTION RCPs should not be tripped UNTIL reactor power is less than 5%.

NOTE Steps 1 and 2 are IMMEDIATE ACTION steps.

EXAMINER: When the Console Operator receives the communication from the RO dispatching personnel to open the reactor trip breakers locally OR to open the MG set supply breakers, the Console Operator will wait 2 minutes, then will remove malfunction rpOlc to clear the ATWS, and enter malfunctions rp5la and rp5lb to open the reactor trip breakers.

Critical Task I Insert negative reactivity into the core by inserting control rods.

Critical 1. RESPONSE NOT OBTAINED:

Task I Manually TRIP reactor.

IF reactor will NOT trip, THEN INSERT control rods.

RO observes rods inserting at 72 steps per minute in RO AUTOMATIC. When the rod speed slows to 48 steps per minute, the RO transfers from AUOT to MAN on I-RBSS, ROD BANK SELECT. After selecting MAN, the RO inserts rods at 48 steps per minute by holding I-FLRM, ROD MOTION CONTROL to the IN position.

2. ENSURE Turbine Trip:

RO

All turbine stop valves CLOSED.

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Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario # 2 Event # 5,6, 7 and 8 Page 21 of 34 Event

Description:

5) A leak develops on the RCP oil cooler supply header line inside containment.

Requires entry into AOl-I 5, Loss of Component Cooling Water (CCS). After the RCP oil cooler flow path is isolated, requires a manual reactor trip to remove the RCPs from service. 6) Reactor fails to trip (ATWS). Requires entry into FR-S.1, Nuclear Power Generation/ATWS. RCPs are left in service until reactor power is reduced below 5%. 7) ALL AFW pumps fail to automatically start. Requires the BOP to manually start each AFW pump. 8) Main steam line break on Loop I inside containment. Requires performance of E-O, Reactor trip or Safety Injection and E-2, Faulted Steam Generator Isolation, after FR-Si, Nuclear Power Generation/AWlS, allows performance.

Time Position Applicants Actions or Behavior

3. CHECK AFW pumps operation:

a. Both MD AFW pumps RUNNING.

BOP

b. TD AFW pump RUNNING.

c. LCVs in AUTO or controlled in MANUAL.

3. RESPONSE NOT OBTAINED:

BOP Manually START pumps and open valves as necessary.

4. INITIATE RCS Boration:

a. ENSURE at least one centrifugal charging pump RUNNING.

b. OPEN RWST outlet valves 1-LCV-62-135 and 1-LCV-62-136.

c. CLOSE VCT outlet valves I -LCV-62-1 32 and 1 -LCV-62-1 33.

RO d. OPEN BIT outlet valves l-FCV-63-25 and 1-FCV-63-26.

e. CHECK BIT flow.

f. PLACE BA pumps in FAST speed.

g. Throttle OPEN emergency borate valve 1-FCV-62-138 to maintain boric acid flow greater than 35 gpm.

BOP 5. CHECK pzr pressure less than 2335 psig.

6. VERIFY Cntmt Vent Isolation:

SRO *TrainAGREEN.

Train B GREEN.

6. RESPONSE NOT OBTAINED:

PERFORM the following:

a. ENSURE containment purge supply and exhaust fans STOPPED. [M-9j RO Since purge was not in service, the containment purge supply and exhaust fans all be found in the STOP, PULL-TO-LOCK position.

b. CLOSE dampers. [M-9]

7. IF AFW flow established, THEN RO a. PLACE I-HS-3-45 to LONG CYCLE RECIRC.

b. PLACE MEW Bypass Reg Valves in AUTO.

SRO 8. IF SI actuated OR required, THEN PERFORM Steps 1 through 6 of E-O, Reactor Trip or Safety Injection, as time allows.

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Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario # 2 Event # 5,6, 7 and 8 Page 22 of 34 Event

Description:

5) A leak develops on the RCP oil cooler supply header line inside containment.

Requires entry into Aol-i 5, Loss of Component Cooling Water (CCS). After the RCP oil cooler flow path is isolated, requires a manual reactor trip to remove the RCPs from service. 6) Reactor fails to trip (ATWS). Requires entry into FR-S.i, Nuclear Power Generation/ATWS. RCP5 are left in service until reactor power is reduced below 5%. 7) ALL AFW pumps fail to automatically start. Requires the BOP to manually start each AFW pump. 8) Main steam line break on Loop 1 inside containment. Requires performance of E-0, Reactor trip or Safety Injection and E-2, Faulted Steam Generator Isolation, after FR-S.i, Nuclear Power Generation/ATWS, allows performance.

Time j Position Applicants Actions or Behavior

9. ENSURE the following trips:

RD

a. Reactor Trip.

9.a. RESPONSE NOT OBTAINED:

a. DISPATCH operator to locally trip reactor:

RD OPEN reactor trip breakers and MG set output breakers [MG set room].

OPEN breakers to MG sets [480V unit boards A and B].

BOP b. Turbine Trip.

RD 10. MAINTAIN rod insertion UNTIL rods fully inserted.

1 1. REFER TO EPIP-i, Emergency Plan Classification Flowchart for RD ATWS event.

EXAMINER: Cue the Console Operator to enter the Steam Line break at this time.

Containment conditions will degrade to the point that a safety injection signal will actuate.

12. MONITOR reactor subcriticality:

a. CHECK Power range channels less than 5%.

RD

b. CHECK Intermediate range startup rate NEGATIVE.

c. GOTOStep2l.

21. TERMINATE emergency boration:

a. PLACE BA transfer pumps in SLOW speed.

RD b CLOSE emergency borate valve 1-FCV-62-138.

c. IF alternate boration opened, THEN Locally CLOSE 1 -ISV-62-929.

NOTE If the reactor is verified to be subcritical, Status Trees may be implemented for other Red or Orange paths RD 22. IMPLEMENT other Red or Orange paths identified on Status Trees RD 23. IF SI actuated, THEN RETURN TO Instruction in effect.

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Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario # 2 Event # 5,6, 7 and 8 Page 23 of 34 Event

Description:

5) A leak develops on the RCP oil cooler supply header line inside containment.

Requires entry into AOl-I 5, Loss of Component Cooling Water (CCS). After the RCP oil cooler flow path is isolated, requires a manual reactor trip to remove the RCPs from service. 6) Reactor fails to trip (ATWS). Requires entry into FR-S.1, Nuclear Power Generation/ATWS. RCPs are left in service until reactor power is reduced below 5%. 7) ALL AFW pumps fail to automatically start. Requires the BOP to manually start each AFW pump. 8) Main steam line break on Loop I inside containment. Requires performance of E-O, Reactor trip or Safety Injection and E-2, Faulted Steam Generator Isolation, after FR-S.1, Nuclear Power Generation/ATWS, allows performance.

Time Position Applicants Actions or Behavior The following actions are taken from E-O, Reactor Trip or Safety Injection.

NOTE Steps 1 thru 4 are IMMEDIATE ACTION STEPS.

Status Trees I SPDS should be monitored when transitioned to another instruction.

1. ENSURE reactor trip:

Reactor trip and bypass breakers OPEN.

RO checks 1-52RTB, R)( TRIP BKR A GREEN indicating light LIT on panel 1-M-4.

RO checks 1-52RTB, RC TRIP BKR B GREEN indicating light LIT on panel 1-M-4 RO checks 1-52BYA, BYPASS BKR A lights DARK RO checks 1-52BYB, BYPASS BKR B lights dark RO

RPls at bottom of scale.

RO observes 1-MON 85 5000/1 CERPI Monitor I and 1-MON-85 5000/2 CERPI MONITOR 2 for indication that all SHUTDOWN and CONTROL bank rods are inserted.

Neutron flux DROPPING.

RO observes neutron flux trending down on 1-NR-92-145, NEUTRON FLUX LEVEL RECORDER. May also observe levels decreasing on 1-NI-92-135A, CH I NEUTRON MON % PWR, and 1-Nl-92-136A, CH II NEUTRON MON % PWR.

2. ENSURE Turbine Trip:

All turbine stop valves CLOSED.

RO RO observes that indicating lights on 1-XX-47-1000 EHC CONTROL for individual throttle and governor valves are GREEN.

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Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario # 2 Event # 5,6, 7 and 8 Page 24 of 34 Event

Description:

5) A leak develops on the RCP oil cooler supply header line inside containment.

Requires entry into Aol-I 5, Loss of Component Cooling Water (CCS). After the RCP oil cooler flow path is isolated, requires a manual reactor trip to remove the RCPs from service. 6) Reactor fails to trip (ATWS). Requires entry into FR-S.I, Nuclear Power Generation/ATWS. RCPs are left in service until reactor power is reduced below 5%. 7) ALL AFW pumps fail to automatically start. Requires the BOP to manually start each AFW pump. 8) Main steam line break on Loop I inside containment. Requires performance of E-0, Reactor trip or Safety Injection and E-2, Faulted Steam Generator Isolation, after FR-S.1, Nuclear Power GenerationlATWS, allows performance.

Time Position Applicants Actions or Behavior

3. CHECK 6.9 kV shutdown boards:

a. At least one board energized from:

CSST (offsite),

OR RD

D/G (blackout).

When observed by the RO during IMMEDIATE OPERATOR ACTIONS, both shutdown boards are energized, based on 1-El-57-39, 6.9 SDB IA-A VOLTS indicating approximately 7000 volts and 1-EI-57-66, 6.9 SDB lB-B VOLTS indicating approximately 7000 volts.

4. CHECK SI actuated:

a. Any SI annunciator LIT.

RO will announce that the window 70-A, SIACTUA TED is LIT.

RD May also announce that FIRST OUT 76-G SI MANUAL is LIT.

b. Both trains SI ACTUATED.

1 -XX-55-6C

I -XX-55-6D EXAMINER: E-O, Reactor Trip or Safety Injection, Appendixes A and B are included as Attachment 2.

5. PERFORM Appendixes A and B, E-O, pages 1 6-30 BOP SRO assigns BOP to perform Appendixes A and B. Handout for E-0 contains copy for EXAMINER assigned to BOP.

SRO 6. ANNOUNCE reactor trip and safety injection over PA system.

7. ENSURE secondary heat sink available with either:

Total AFW flow greater than 410 gpm, RD OR

At least one SIG NR level greater than 29% [39% ADVj.

8. MONITOR RCS temperature stable at or trending to 557°F using:

RCS Loop T-avg with any RCP running, RD OR

RCS Loop T-cold with RCPs out-of-service.

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Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario # 2 Event # 5,6, 7 and 8 Page 25 of 34 Event

Description:

5) A leak develops on the RCP oil cooler supply header line inside containment.

Requires entry into AOl-i 5, Loss of Component Cooling Water (CCS). After the RCP oil cooler flow path is isolated, requires a manual reactor trip to remove the RCPs from service. 6) Reactor fails to trip (ATWS). Requires entry into FR-S.1, Nuclear Power Generation/ATWS. RCPs are left in service until reactor power is reduced below 5%. 7) ALL AFW pumps fail to automatically start. Requires the BOP to manually start each AFW pump. 8) Main steam line break on Loop 1 inside containment. Requires performance of E-0, Reactor trip or Safety Injection and E-2, Faulted Steam Generator Isolation, after FR-Si, Nuclear Power Generation/ATWS, allows performance.

Time Position Applicants Actions or Behavior

8. RESPONSE NOT OBTAINED IF temp less than 557F, THEN ENSURE steam dumps and SIG PORVs CLOSED.

IF cooldown continues, THEN CONTROL total AFW flow to maintain greater than 410 gpm UNTIL NR level in at least one SIG greater than 29% [39% ADV].

RO takes manual control of AFW LCVs and reduces AFW flow.

RO IF cooldown continues after AFW flow is controlled, THEN

PLACE steam dump controls OFF.

RO rotates 1-HS-1-103A, STEAM DUMP FSVA, and 1-HS-103B STEAM DUMP FSV B to the left to the OFF RESET position.

CLOSE MSIVs.

ENSURE MSIV bypasses CLOSED.

IF RCS temp greater than 564F, THEN ENSURE either steam dumps or SIG PORVs OPEN.

9. ENSURE excess letdown valves CLOSED:

RO

I -FCV-62-54

1 -FCV-62-55 EXAMINER: PORV 334 will indicate open and its Block valve will indicate closed in the next step due to previous failure.

10. CHECK pzr PORVs and block valves:

a. Pzr PORVs CLOSED.

b. At least one block valve OPEN.

RO observes 1-HS-68-340AA, PZR PORV34OA, GREEN indicating light is LIT, RED indicating light is DARK.

RO RO observes 1-HS-68-334A, PZR PORV 334, RED indicating light is LIT, GREEN indicating light is DARK.

RO observes 1-HS-68-333A, BLOCK VLVFOR PORV34OA, GREEN indicating light is DARK, RED indicating light is LIT.

RO observes 1-HS-68-332A, BLOCK VLVFOR PORV 334, GREEN indicating light is LIT, RED indicating light is DARK.

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I Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario # 2 Event # 5,6, 7 and 8 Page 26 of 34 Event

Description:

5) A leak develops on the RCP oil cooler supply header line inside containment.

Requires entry into AOl-i 5, Loss of Component Cooling Water (CCS). After the RCP oil cooler flow path is isolated, requires a manual reactor trip to remove the RCPs from service. 6) Reactor fails to trip (ATWS). Requires entry into FR-S.1, Nuclear Power Generation/AIWS. RCPs are left in service until reactor power is reduced below 5%. 7) ALL AFW pumps fail to automatically start. Requires the BOP to manually start each AFW pump. 8) Main steam line break on Loop 1 inside containment. Requires performance of E-0, Reactor trip or Safety Injection and E-2, Faulted Steam Generator Isolation, after FR-S.1, Nuclear Power Generation/ATWS, allows performance.

Time Position Applicants Actions or Behavior 1 1. CHECK pzr safety valves CLOSED:

EVALUATE tailpipe temperatures and acoustic monitors.

RD RO observes response of 1-TI-68-330, SAFETY 68-563 TAILPIPE TEMP, l-TI-68-329, SAFETY 68-564 TAILPIPE TEMP. and l-Tl 328, SAFETY 68-565, stable at elevated temperatures due to the previous failure of 1-PC V-68-334.

12. CHECK pzr sprays CLOSED.

RD RO observes the GREEN indicating lights are LIT for 1-XI 334B, PZR SPRAY LOOP 2 and 1-Xl-68-334D, PZR SPRAY LOOP I NOTE Seal injection flow should be maintained to all RCPs.

13. CHECK if RCPs should remain in service:

a. Phase B signals DARK [MISSP].

RD SRO may have directed that the RCPs be shutdown when power was less than 5%, due to the loss of oil cooler flow.

a. RESPONSE NOT OBTAINED:

RD STOP all RCPs. GO TO Step 14.

14. CHECK S/G pressures:

All S/G pressures controlled or rising.

RO observes PAM pressure instruments on SG I through 4 (black labels) and determines that pressure on SG I is NOT controlled. May also observe trends on 1-PR-1-2, SG I & 2 RD PRESS P51G. and 1-PR-1-23, SG 3 & 4 PRESS PSIG to assess this step.

All S/G pressures greater than 120 psig.

RO observes PAM pressure instruments on SG I through 4 (black labels) and determines that pressure is low on SG 1.

14. RESPONSE NOT OBTAINED:

SRD IF S/G pressure low DR dropping uncontrolled, THEN GO TO E-2, Faulted Steam Generator Isolation.

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Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: 2 Scenario # 2 Event # 5,6, 7 and 8 Page 27 of 34 Event

Description:

5) A leak develops on the RCP oil cooler supply header line inside containment.

Requires entry into AOl-i 5, Loss of Component Cooling Water (CCS). After the RCP oil cooler flow path is isolated, requires a manual reactor trip to remove the RCPs from service. 6) Reactor fails to trip (ATWS). Requires entry into FR-S.1, Nuclear Power Generation/ATWS. RCPs are left in service until reactor power is reduced below 5%. 7) ALL AFW pumps fail to automatically start. Requires the BOP to manually start each AFW pump. 8) Main steam line break on Loop 1 inside containment. Requires performance of E-O, Reactor trip or Safety Injection and E-2, Faulted Steam Generator Isolation, after FR-Si, Nuclear Power Generation/ATWS, allows performance.

L Time Position Applicants Actions or Behavior The following actions are taken from E-2, Faulted Steam Generator Isolation.

CAUTION If a faulted SIG is NOT needed for RCS cooldown, it should remain isolated during subsequent recovery actions.

1. ENSURE all MSIVs and MSIV bypasses CLOSED.

RO RO determines that the MSIVs are CLOSED based on GREEN and BLUE indicating lights LIT on handswitches.

NOTE If it is known that a steam leak exists in the Turbine building, the following step should not be performed until the affected steam header is depressurized.

2. PLACE steam dump controls OFF:

i-HS-1-103A, STEAM DUMP FSV A.

BOP

1-HS-1-103B, STEAM DUMP FSVB.

SRO observes that the steam dump controls were placed in the OFF position during E-O performance.

3. CHECK for at least one Intact SIG:

Any S/G pressure controlled or rising, OR

Any SIG pressure greater than P-sat for RCS incore BOP tern perature.

BOP determines that SG I is FAULTED and that the remaining SGs are INTACT based on SG pressure response.

4. IDENTIFY Faulted SIG based on ANY of the following:

Any SIG pressure dropping in an uncontrolled manner, OR

Any SIG pressure less than 120 psig, OR S!G enclosure tern ps high:

1)TiOO2Afor2and3, BOP

2) TI 003A for 1 and 4.OR

Local indication of break in any of the following:

1) Main steam lines,

2) Main feedwater lines,

3) Other secondary piping.

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Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario # 2 Event # 5,6, 7 and 8 Page 28 of 34 Event

Description:

5) A leak develops on the RCP oil cooler supply header line inside containment.

Requires entry into Aol-I 5, Loss of component cooling Water (CcS). After the RCP oil cooler flow path is isolated, requires a manual reactor trip to remove the RcPs from service. 6) Reactor fails to trip (ATWS). Requires entry into FR-S.I, Nuclear Power Generation/A]WS. RCPs are left in service until reactor power is reduced below 5%. 7) ALL AFW pumps fail to automatically start. Requires the BOP to manually start each AFW pump. 8) Main steam line break on Loop I inside containment. Requires performance of E-O, Reactor trip or Safety Injection and E-2, Faulted Steam Generator Isolation, after FR-S.1, Nuclear Power Generation/ATWS, allows performance.

Time Position Applicants Actions or Behavior CAUTION

If the turbine-driven AFW pump is the only available source of feed flow, steam supply to the turbine-driven AFW pump must be maintained from one SG.

RCS cooldown requires the availability of at least one SIG.

Critical Task 2 Isolate the faulted steam generator (SG 1) prior to exiting E-2, Faulted Steam Generator Isolation.

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Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario # 2 Event # 5,6, 7 and 8 Page 29 of 34 Event

Description:

5) A leak develops on the RCP oil cooler supply header line inside containment.

Requires entry into AOl-i 5, Loss of Component Cooling Water (CCS). After the RCP oil cooler flow path is isolated, requires a manual reactor trip to remove the RCPs from service. 6) Reactorfailstotrip(ATNS). Requires entry into FR-Si, Nuclear Power Generation/ATWS. RCPs are left in service until reactor power is reduced below 5%. 7) ALL AFW pumps fail to automatically start. Requires the SOP to manually start each AFW pump. 8) Main steam line break on Loop 1 inside containment. Requires performance of E-O, Reactor trip or Safety Injection and E-2, Faulted Steam Generator Isolation, after FR-S.1, Nuclear Power Generation/ATWS, allows performance.

Time Position Applicants Actions or Behavior Critical 5. ISOLATE Faulted SIG:

Task 2 a. ISOLATE AFW flow to Faulted S!G.

BOP rotates 1-HS-3-164A, SG I SUPPLY LCV-3-164 CNTL from the AUTO position to the ACC. RESET MODULATE position.

The BOP then rotates I-HS-3-164A, SG I SUPPLY LCV-3-164 CNTL to the CLOSE position and PULLS the switch OUT.

BOP rotates 1-HS-3-174A, SG I SUPPLY LCV-3-I74 CNTL from the AUTO position to the ACC. RESET MODULATE position.

The BOP then rotates I-HS-3-174A, SG I SUPPLY LCV-3-I74 CNTL to the CLOSE position and PULLS the switch OUT.

b. ENSURE MEW ISOLATED to Faulted SIG:

MEW isolation and bypass isolation valves CLOSED.

BOP observes I-HS-3-33A, SG I MFWISOL VLV, I-HS-3-47A, SG2 MFWISOL VLV, 1-HS-3-87A, SG 3 MFWISOL VLVand 1-HS-3-IOOA, SG 4 MFWISOL VLV, RED indicating lights are DARK, GREEN indicating lights are LIT BOP observes 1-Xl-3-236, SG I MFWBYP ISOL VLV, I-XI-3-239, SG2 MFWBYP ISOL VLV, I-Xl-3-242, SG 3 MFWBYP ISOL VLV BOP and I-Xl-3-245, SG 4 MFWBYP ISOL VLV, RED indicating lights are DARK, GREEN indicating lights are LIT

MEW reg and bypass reg valves CLOSED.

BOP observes I-)O(-3-35 MFW REG, RED indicating lights are DARK, GREEN indicating lights are LIT.

BOP observes I-XX-3-35A BYP REG, RED indicating lights are DARK, GREEN indicating lights are LIT.

MFPs TRIPPED.

BOP observes I-HS-46-9A, MFPTA TRIP-RESET and 1-HS 36A, MFPT B TRIP-RESET RED indicating lights are DARK, GREEN indicating lights are LIT.

c. ENSURE Faulted S/G PORV CLOSED.

BOP may rotate I-HS-1-6, SG I PORV PCV-1-5 from the P AUTO position to the CLOSE position. BOP observes the RED indicating light is DARK, GREEN indicating light is LIT.

d. ENSURE Faulted S!G blowdown ISOLATED.

BOP may rotate I-HS-I-7/181 SG I BLOWDOWN VLVS from the P-AUTO position to the CLOSE position. BOP observes RED indicating light is DARK, GREEN indicating light is LIT.

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Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario # 2 Event # 5,6, 7 and 8 Page 30 of 34 Event

Description:

5) A leak develops on the RCP oil cooler supply header line inside containment.

Requires entry into AOl-I 5, Loss of Component Cooling Water (CCS). After the RCP oil cooler flow path is isolated, requires a manual reactor trip to remove the RCPs from service. 6) Reactor fails to trip (ATWS). Requires entry into FR-S.I, Nuclear Power Generation/ATNS. RCPs are left in service until reactor power is reduced below 5%. 7) ALL AFW pumps fail to automatically start. Requires the BOP to manually start each AFW pump. 8) Main steam line break on Loop I inside containment. Requires performance of E-0, Reactor trip or Safety Injection and E-2, Faulted Steam Generator Isolation, after FR-S.1, Nuclear Power Generation/ATWS, allows performance.

Time Position Applicants Actions or Behavior NOTE TD AFW pump steam supply should NOT be aligned from a SIG with a known primary to secondary leak if other AFW sources are available.

BOP 6. ENSURE TD AFW pump being supplied from Intact SIG.

BOP 7. MONITOR CST volume greater than 200,000 gal.

8. WHEN RCS temperature is stable or rising following Faulted SIG blowdown, THEN ADJUST Intact S/G PORV controllers in AUTO to:

BOP e P-sat for the highest RCS temp (one or more RCPs running)

OR

. P-sat for the highest T-cold temp (no RCPs running)

9. CHECK secondary side radiation:

S/G discharge monitors NORMAL.

Condenser vacuum exhaust rad monitors NORMAL.

BOP

S/G blowdown rad monitor recorders NORMAL trend prior to isolation.

S/G sample results by Chemistry.

10. CHECK SI termination criteria:

a. CHECK RCS subcooling greater than 65°F [85°F ADV].

b. CHECK secondary heat sink available with either:

Total feed flow to Intact S/Gs greater than 410 gpm, OR

At least one Intact S!G NR level greater than 29% [39%

ADV].

RO c. CHECK RCS pressure stable or rising.

d. CHECK pzr level greater than 15% [33% ADV].

It is possible that PZR level may not be greater than 33% when the crew reaches this step. If PZR level is less than 33%, the crew will transition to E-1, Loss of Reactor or Secondary Caolant, instead of ES-1.1, SI Termination. Both paths are acceptable, and are provided in the scenario.

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D-?J Op Test No.: 2 Scenario # 2 Event # 5,6, 7 and 8 Page 31 of 34 Event

Description:

5) A leak develops on the RCP oil cooler supply header line inside containment.

Requires entry into Aol-i 5, Loss of component Cooling Water (CCS). After the RCP oil cooler flow path is isolated, requires a manual reactor trip to remove the RCP5 from service. 6) Reactor fails to trip (ATWS). Requires entry into FR-S.1, Nuclear Power Generation/ATWS. RCPs are left in service until reactor power is reduced below 5%. 7) ALL AFW pumps fail to automatically start. Requires the BOP to manually start each AFW pump. 8) Main steam line break on Loop I inside containment. Requires performance of E-O, Reactor trip or Safety Injection and E-2, Faulted Steam Generator Isolation, after FR-S.i, Nuclear Power Generation/ATWS, allows performance.

Time N Position Applicants Actions or Behavior

d. RESPONSE NOT OBTAINED:

RESTORE pzr level:

SRO 1) ATTEMPT to stabilize RCS pressure with normal pzr sprays.

2) ** GO TO Step 11.

e. GO TO ES-i .1, SI Termination.

When the transition to ES-I. I, SI Termination, is directed by the SRO, inform the applicants that another crew will continue from this point.

SRO 1 1. GO TO E-1, Loss of Reactor or Secondary Coolant.

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario # 2 Event # 5,6, 7 and 8 Page 32 of 34 Event

Description:

5) A leak develops on the RCP oil cooler supply header line inside containment.

Requires entry into AOI1 5, Loss of Component Cooling Water (CCS). After the RCP oil cooler flow path is isolated, requires a manual reactor trip to remove the RCPs from service. 6) Reactor fails to trip (AIWS). Requires entry into FR-SI, Nuclear Power Generation/ATWS. RCPs are left in service until reactor power is reduced below 5%. 7) ALL AFW pumps fail to automatically start. Requires the BOP to manually start each AFW pump. 8) Main steam line break on Loop I inside containment. Requires performance of E-0, Reactor trip or Safety Injection and E-2, Faulted Steam Generator Isolation, after FR-Si, Nuclear Power Generation/ATWS, allows performance.

Time Position N Applicants Actions or Behavior The following actions are taken from E-1, Loss of Reactor or Secondary Coolant.

NOTE Seal injection flow should be maintained to all RCPs.

1. CHECK if RCPs should remain in service:

a. Phase B DARK [MISSP].

SRO

b. RCS pressure greater than 1500 psig.

RCPs should have been stopped prior to reaching this step.

SRO 2. REFER TO EPIP-1, Emergency Plan Classification Flowchart.

NOTE Time since initiation of event is defined by performance of Step 3.

3. RECORD current time to mark initiation of LOCA and determination of time for hot leg recirc.

4. CHECK SIG pressures:

All S/G pressures controlled or rising.

All S/Gs pressures greater than 120 psig.

4. RESPONSE NOT OBTAINED:

IF Faulted S/G has NOT been isolated, THEN **

GO TO E-2, Faulted Steam Generator Isolation.

The faulted SG isolation has already been addressed during performance of E-2, Faulted Steam Generator Isolation, so a transition is NOT required.

5. MAINTAIN Intact S/G NR levels:

a. MONITOR levels greater than 29% [39% ADVJ.

b. CONTROL intact S/G levels between 29% and 50% [39% and 50% ADVJ.

6. CHECK secondary radiation:

S/G discharge monitors NORMAL.

Condenser vacuum exhaust rad monitors NORMAL.

S/G blowdown rad monitor recorders NORMAL trend prior to isolation.

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario # 2 Event # 5,6, 7 and 8 Page 33 of 34 Event

Description:

5) A leak develops on the RCP oil cooler supply header line inside containment.

Requires entry into Aol-i 5, Loss of component cooling Water (CCS). After the RCP oil cooler flow path is isolated, requires a manual reactor trip to remove the RcPs from service. 6) Reactor fails to trip (ATWS). Requires entry into FR-S.i, Nuclear Power Generation/ATWS. RcPs are left in service until reactor power is reduced below 5%. 7) ALL AFW pumps fail to automatically start. Requires the BOP to manually start each AFW pump. 8) Main steam line break on Loopi inside containment. Requires performance of E-0, Reactor trip or Safety Injection and E-2, Faulted Steam Generator Isolation, after FR-S.i, Nuclear Power Generation/ATWS, allows performance.

Time Position Applicants Actions or Behavior

7. ENSURE cntmt hydrogen analyzers in service:

PLACE 1-HS-43-200A in ANALYZE [M-10].

PLACE 1-HS-43-210A in ANALYZE [M-10].

CHECK low flow lights NOT lit [M-10].

LOCALLY CHECK low analyzer temp lights NOT lit AND RESET local alarm panel. [North wall of Train A 480V SD Bd rm].

EXAMINER: PORV 334 will indicate open and its Block valve will indicate closed in the next step due to previous failure.

8. MONITOR pzr PORVs and block valves:

a. Pzr PORVs CLOSED.

b. At least one block valve OPEN.

RO observes 1-HS-68-340AA, PZR PORV34OA, GREEN indicating light is LIT, RED indicating light is DARK.

RO observes 1-HS-68-334A, PZR PORV 334, RED indicating light is LIT, GREEN indicating light is DARK.

RO observes 1-HS-68-333A, BLOCK VLV FOR PORV34OA, GREEN indicating light is DARK, RED indicating light is LIT RO observes 1-HS-68-332A, BLOCK VLVFORPORV334, GREEN indicating light is LIT, RED indicating light is DARK.

9. DETERMINE if cntmt spray should be stopped:

a. MONITOR cntmt pressure less than 2.0 psig.

b. CHECK at least one cntmt spray pump RUNNING.

c. RESET cntmt spray signal.

d. STOP cntmt spray pumps, AND PLACE in A-AUTO.

e. CLOSE cntmt spray discharge valves 1-FCV-72-2 and i-FCV 72-39.

10. ENSURE both pocket sump pumps STOPPED [M-15j:

1-HS-77-410.

1 -HS-77-41 1.

2011-10 Watts Bar NRC Examination

Appendix D Required Operator Actions Form ES-D-2 Op Test No.: 2 Scenario # 2 Event # 5,6, 7 and 8 Page 34 of 34 Event

Description:

5) A leak develops on the RCP oil cooler supply header line inside containment.

Requires entry into AOl-i 5, Loss of Component Cooling Water (CCS). After the RCP oil cooler flow path is isolated, requires a manual reactor trip to remove the RCPs from service. 6) Reactor fails to trip (ATWS). Requires entry into FR-Si, Nuclear Power Generation/ATWS. RCPs are left in service until reactor power is reduced below 5%. 7) ALL AFW pumps fail to automatically start. Requires the BOP to manually start each AFW pump. 8) Main steam line break on Loop I inside containment. Requires performance of E-0, Reactor trip or Safety Injection and E-2, Faulted Steam Generator Isolation, after FR-S.1, Nuclear Power Generation/ATWS, allows performance.

Time Position Applicants Actions or Behavior 1 1. CHECK SI termination criteria:

a. CHECK RCS subcooling greater than 65°F [85°F ADVI.

b. CHECK secondary heat sink available with either:

Total feed flow to Intact SIGs greater than 410 gpm, OR

At least one Intact SIG NR level greater than 29% [39% ADV].

c. CHECK RCS pressure stable or rising.

d. CHECK pzr level greater than 15% [33% ADVJ.

e. ** GO TO ES-1.1, SI Termination.

EXAMINER: When the transition to ES-1.1, SI Termination, is directed by the SRO, inform the applicants that another crew will continue from this point.

END OF SCENARIO 2011-10 Watts Bar NRC Examination

Scenano 2 SHIFT TURNOVER CHECKLIST Page 1 of2 SHIFT TURNOVER CHECKLIST Page 1 of 1 SM US/MCR Unit 1 Q UO Unit Off-going Name

[] AUO Station 1 STA (STA Function) On-coming Name Part 1 - Completed by off-going shift / Reviewed by on-coming shift: RCS Cb = 1031 ppm Abnormal equipment lineup / conditions:

lB-B R}{R pump is out of service for motor winding inspection. LCO 3.5.2 and 3.6.6 were entered 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ago. lB-B RHR pump is expected to be returned to service in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . Protected equipment signs have been posted for lA-A RI4R pump. lB Condensate Booster pump has an oil leak, and is being monitored every 30 minutes.

SI/Test in progress/planned: (including need for conduct of evolution briefings)

Major Activities/Procedures in progress/planned:

Train B/Channel II Work Week. 100% power, RCS boron concentration 1031 ppm. Control Bank D is at 220 steps.

A power reduction to 95% at 2%/mm using AOI-39, Rapid Load Reduction, is required to be performed to remove the lB Condensate Booster pump from service.

Radiological changes in plant during shift:

Part 2 Completed by on-coining shift prior to assuming duties D Review station rounds / Abnormal reading (AUOs only)

[J Review Narrative Logs (previous day and carry-over items)

Q Current qualification status Q Review the current controlling Reactivity Management Plans (N/A for AUOs)

Q Review current TS/TRM/ODCM/FPR Required Actions (N/A for AUOs)

Q Walkdown MCR Control Boards with off-going Operator (N/A for AUOs, as applicable for SM/STAs)

[] SR/PER reviews complete for previous shift (SM/US/STA)

Relief Time: Relief Date:

Part 3 Completed by on-coming shift. These items may be reviewed after assuming duties:

Q Review Operator Workarounds, Burdens and Challenges (applicable Unit/Station)

D Review applicable ODMI actions (first shift of shift week)

Q Review changes in Standing / Shift Orders (since last shift worked)

Q Review changes to TACFs issued (since last shift worked) (N/A for AUOs)

[] Review Control Room Deficiencies (first shift of shift week) (N/A for AUOs) 0 Review Component Deviation Log (N/A for AUOs)

TVA 40741 Page 1 of I OPDP-l-l [01-14-20111

Scenano 2 SHIFT TURNOVER CHECKLIST Page 1 of2 SHIFT TURNOVER CHECKLIST Page 1 of 1 Q SM Q US/MCR Unit 1 UO Unit Off-going Name AUO Station Q STA (STA Function) On-coming Name Part 1 Completed by off-going shift / Reviewed by oncoming shift:

- RCS Cb = 1031 ppm Abnormal equipment lineup / conditions:

lB-B RHR pump is out of service for motor winding inspection. LCO 3.5.2 and 3.6.6 were entered 1 hour1.157407e-5 days 2.777778e-4 hours 1.653439e-6 weeks 3.805e-7 months ago. lB-B RHR pump is expected to be returned to service in 12 hours1.388889e-4 days 0.00333 hours 1.984127e-5 weeks 4.566e-6 months . Protected equipment signs have been posted for lA-A RHR pump. lB Condensate Booster pump has an oil leak, and is being monitored every 30 minutes.

SI/Test in progress/planned: (including need for conduct of evolution briefings)

Major Activities/Procedures in progress/planned:

Train B/Channel II Work Week. 100% power, RCS boron concentration 1031 ppm. Control Bank D is at 220 steps.

A power reduction to 95% at 2%/mm using AOI-39, Rapid Load Reduction, is required to be performed to remove the lB Condensate Booster pump from service.

Radiological changes in plant during shift:

Part 2 Completed by on-coming shift prior to assuming duties D Review station rounds / Abnormal reading (AUOs only)

Review Narrative Logs (previous day and carry-over items)

C] Current qualification status C] Review the current controlling Reactivity Management Plans (N/A for AUOs)

C] Review current TS/TRMIODCM/FPR Required Actions (N/A for AUOs)

C] Wallcdown MCR Control Boards with off-going Operator (N/A for AUOs, as applicable for SM/STAs)

C] SR/PER reviews complete for previous shift (SM/US/STA)

Relief Time: Relief Date:

Part 3 Completed by on-coming shift. These items may be reviewed after assuming duties:

C] Review Operator Workarounds, Burdens and Challenges (applicable Unit/Station)

C] Review applicable ODMI actions (first shift of shift week)

C] Review changes in Standing / Shift Orders (since last shift worked)

C] Review changes to TACFs issued (since last shift worked) (N/A for AUO5)

C] Review Control Room Deficiencies (first shift of shift week) (N/A for AUOs)

C] Review Component Deviation Log (N/A for AUOs)

TVA40741 Page 1 of 1 OPDP-l-1 [01-14-2011]

Scenario 2 Attachment I AOI2 MALFUNCTION OF REACTOR CONTROL SYSTEM.

Attachment I

AOI-2 WBN MALFUNCTION OF REACTOR CONTROL SYSTEM Revision 37 Page 51 of5l ATTACHMENT I Page 1 of I REACTOR POWER VS TAVGITREF TEMPERATURE AND PZR LEVEL (Tavg-Tref values rounded to one tenth of a degree)

RX TAVG- PZR RX TAVE- PZR POWER TREF LEVEL POWER TREF LEVEL 2% 557.6 °F 25.7 % 52% 572.2°F 43.2%

4% 558.2 °F 26.4 % 54% 572.8 °F 43.9 %

6% 558.8 °F 27.1 % 56% 573.4 °F 44.6 %

8% 559.3 °F 27.8 % 58% 573.9 °F 45.3 %

10% 559.9 °F 28.5 % 60% 574.5°F 46.0%

12% 560.5 °F 29.2 % 62% 575.1 °F 46.7 %

14% 561.1°F 29.9% 64% 575.7 °F 47.4 %

16% 561.7°F 30.6% 66% 576.3 °F 48.1 %

18% 562.3°F 31.3% 68% 576.9 °F 48.8 %

20% 562.8 °F 32.0 % 70% 577.4 °F 49.5 %

22% 563.4 °F 32.7 % 72% 578.0 °F 50.2 %

24% 564.0 °F 33.4 % 74% 5786°F 50.9%

26% 564.6 °F 34.1 % 76% 579.2 °F 51.6%

28% 565.2 °F 34.8 % 78% 579.8 °F 52.3 %

30% 565.8 °F 35.5 % 80% 580.4 °F 53.0 %

32% 566.3 °F 36.2 % 82% 580.9 °F 53.7 %

34% 566.9°F 36.9% 84% 581.5°F 54.4%

36% 567.5 °F 37.6 % 86% 582 1 °F 55.1 %

38% 568.1 °F 38.3 % 88% 582 7 °F 55.8 %

40% 568.7 °F 39.0 % 90% 583.3 °F 56.5 %

42% 569.3 °F 39.7 % 92% 583.9 °F 57.2 %

44% 569.8 °F 40.4 % 94% 584.4 °F 57.9 %

46% 570.4 °F 41.1 % 96% 585.0 °F 58.6 %

48% 571.0°F 41.8% 98% 585.6 °F 59.3 %

50% 571.6°F 42.5% 1QQ°/g 566.2 °F 60,0 %

Scenario 2 Attachment 2 EO, Reactor Trip or Safety Injection Appendix A and B Attachments I through 5

WBN Reactor Trip or Safety Injection E-0 Unit I Rev. 0030 Appendix A (Page 1 of 9)

Equipment Verification Step Action/Expected Response Response Not Obtained ENSURE PCBs OPEN: OPEN manually.

PCB 5084.

PCB 5088.

2. ENSURE AFW pump operation: ESTABLISH at least one train AFW operation.

Both MD AFW pumps RUNNING.

TDAFWpump RUNNING.

LCVsinAUTO,OR controlled in MANUAL.

3. ENSURE MFW isolation: Manually CLOSE valves AND

MFW isolation and bypass STOP pumps, as necessary.

isolation valves CLOSED.

MEW reg and bypass reg valves CLOSED. IF any valves can NOT be closed, THEN

MFP A and B TRIPPED.

Standby MEP STOPPED. CLOSE #1 heater outlet valves.

Cond demin pumps TRIPPED.

Cond booster pumps TRIPPED.

#3 HDT Pumps TRIPPED.

#7 HDT Pumps TRIPPED.

Page 16 of 31

WBN Reactor Trip or Safety Injection E-0 Unit I Rev. 0030 Appendix A (Page 2of9)

Equipment Verification tep

[ Action/Expected Response Response Not Obtained

4. MONITOR ECCS operation:

a. Charging pumps RUNNING. a. Manually START charging pumps.

b. Charging pump alignment: b. ENSURE at least one valve in each set aligned.

RWST outlets I -LCV-62-1 35 and 1-LCV-62-136 OPEN.

VCT outlets 1-LCV-62-132 and 1-LCV-62-133 CLOSED.

Charging 1-.FCV-62-90 and 1-FCV-62-.91 CLOSED.

c. RHR pumps RUNNING. c. Manually START RHR pumps.

d. SI pumps RUNNING. d. Manually START SI pumps.

e. BIT alignment: e. ENSURE at least one valve

Outlets 1 -FCV-63-25 aligned, and flow thru BIT.

and 1-FCV-63-26 OPEN.

Flow thru BIT.

f. RCS pressure greater f. ENSURE SI pump flow.

than 1650 psig.

IF RCS press drops to less than 150 psig, THEN ENSURE RHR pump flow.

Page 17of31

WBN Reactor Trip or Safety Injection E-O Uniti Rev.0030 Appendix A (Page 3 of 9)

Equipment Verification Step Action/Expected Response Response Not Obtained

5. CHECK cntmt isolation: ACTUATE Phase A and

a. Phase A isolation: Cntmt Vent Isolation signal, o TrainAGREEN. OR o Train B GREEN.

Manually CLOSE valves and

b. Cntmt vent isolation: dampers as necessary.

o Train A GREEN.

o Train B GREEN.

Page 18 of 31

WBN Reactor Trip or Safety Injection E-0 Unit I Rev. 0030 Appendix A (Page 4 of 9)

Equipment Verification

_Step Action/Expected Response Response Not Obtained

6. CHECK cntmt pressure: PERFORM the following:

Phase B DARK [MISSP]. 1) ENSURE Phase B actuated.

Cntmt Spray DARK [MISSP]. 2) ENSURE Cntmt Spray actuated.

Cntmt press less than 2.8 psig. 3) ENSURE cntmt spray pumps running.

4) ENSURE cntmt spray flow.

5) ENSURE Phase B isolation:

Train A GREEN.

Train B GREEN

Manually CLOSE valves and dampers as necessary.

6) STOP all RCPs.

7) ENSURE MSIVs and bypasses CLOSED.

8) PLACE steam dump controls OFF.

9) WHEN 10 minutes has elapsed since Phase B actuated, THEN ENSURE air return fans start.

10) USE adverse cntmt [ADV] setpoints where provided.

7. DISPATCH AUO to perform Attachment I (E-0), Ice Condenser AHU Breaker Operation.

Page 19 of 31

WBN Reactor Trip or Safety Injection E-0 Unit I Rev. 0030 Appendix A (Page 5of9)

Equipment Verification Step Action/Expected Response Response Not Obtained

8. CHECK plant radiation NORMAL: NOTIFY Unit Supervisor IMMEDIATELY.

S/G blowdown rad recorder 1-RR-90-120 NORMAL prior to isolation [M-12].

Condenser vacuum exhaust rad recorder 1-RR-90-119 NORMAL prior to trip [M-12].

1-RR-90-106 and 1-RR-90-1 12 radiation recorders NORMAL prior to isolation [M-12].

S/G main steamline discharge monitors NORMAL [M-30].

Upper and Lower containment high range monitors NORMAL

[M-30].

NOTIFY Unit Supervisor conditions NORMAL.

9. ENSURE all D/Gs RUNNING. EMERGENCY START D/Gs

10. ENSURE ABGTS operation:

a. ABGTS fans RUNNING. a. Manually START fans.

b. ABGTS dampers OPEN: b. Locally OPEN dampers.

FCO-30-146A.

FCO-30-146B.

FCO-30-1 57A.

FCO-30-157B.

Page200f3l

WBN Reactor Trip or Safety Injection E-O Uniti Rev.0030 Appendix A (Page 6 of 9)

Equipment Verification Step Action/Expected Response Response Not Obtained

11. ENSURE at least four ERCW pumps Manually START pumps as necessary.

RUNNING, one on each shutdown board preferred.

12. ENSURE ERCW supply valves IF ERCW can NOT be OPEN to running DIG5. aligned to running DIG, THEN EMERGENCY STOP affected DIG.

13. ENSURE O-FCV-67-152, CCS HX C Manually OPEN O-FCV-67-152 ALT DISCH TO HDR B, is open to to position A.

position A.

14. CLOSE O-FCV-67-144, CCS HX C DISCH TO HDR A.

15. MONITOR EGTS operation: Manually START fans

EGTSfan5RUNNING.

AND

ENSURE dampers OPEN

VERIFY filter bank dp between 5 OPEN dampers.

and 9 inches of water.

16. ENSURE CCS pumps RUNNING: Manually START pumps as necessary.

1A-ACCS pump.

lB-B CCS pump.

C-S or 2B-B CCS pump.

17. DISPATCH AUO to shutdown Upper and Lower CNTMT rad monitors USING SOI-90.02.Gaseous Process Radiation Monitors Page 21 of 31

WBN Reactor Trip or Safety Injection E-0 Unit I Rev. 0030 Appendix A (Page 7 of 9)

Equipment Verification

_Step Action/Expected Response Response Not Obtained

18. WHEN Attachment 1 is complete (Ice Condenser AHU Breakers OPEN),

THEN ENERGIZE hydrogen igniters

[1 -M-1 0]:

1-HS-268-73 ON.

1-HS-268-74 ON.

NOTE The following equipment is located on 1-M-9.

19. CHECK CNTMT PURGE fans STOP fans AND STOPPED.

PLACE handswitch in PULL-TO-LOCK.

20. CHECK FUEL HANDLING EXH fans STOP fans AND STOPPED, Fuel and Cask loading dampers CLOSED: PLACE handswitch in PULL-TO-LOCK, THEN Manually CLOSE dampers.

21. ENSURE AB GEN SUPPLY and STOP fans AND EXH fans STOPPED.

PLACE handswitch in PULL-TO-LOCK.

NOTE Dampers 1-HS-30-158 and 2-HS-30-270 remain open during ABI.

22. ENSURE AB GEN SUP & EXH Manually CLOSE dampers.

dampers CLOSED.

Page 22 of3l

WBN Reactor Trip or Safety Injection E-0 Unit I Rev. 0030 Appendix A (Page 8 of 9)

Equipment Verification Step Action/Expected Response Response Not Obtained

23. ENSURE MCR & SPREAD RM Manually CLOSE dampers.

FRESH AIR dampers CLOSED:

FCV-31-3.

FCV-31-4.

24. ENSURE at least one CB EMER CLEANUP fan RUNNING and associated damper OPEN:

CB EMERG CLEANUP FAN A-A, Manually START fan.

OR

FanB-BRUNNING..

FCO-31-8, OPEN. NOTIFY TSC if at least one damper NOT OPEN.

OR

FCO-31-7, OPEN

25. ENSURE at least one CB EMER PRESS fan RUNNING and associated damper OPEN:

CB EMERG PRESS FAN A-A, Manually START fan.

OR FAN B-B RUNNING.

FCO-31-6, OPEN. NOTIFY TSC if at least one damper NOT OPEN.

OR

FCO-31-5, OPEN.

Page23of3l

WBN Reactor Trip or Safety Injection E-0 Unit I Rev. 0030 Appendix A (Page 9 of 9)

Equipment Verification Step Action/Expected Response Response Not Obtained

26. ENSURE Control Building fans STOPPED and dampers CLOSED:

SPREADING ROOM SUPPLY Manually STOP fans AND and EXH FANS AND dampers.

NOTIFY TSC if any damper NOT

TOILET & LKR RM EXHAUST CLOSED.

FAN AND dampers.

27. INITIATE Appendix B (E-O), Phase B Pipe Break Contingencies.

Page24of3l

WBN Reactor Trip or Safety Injection E-0 Unit I Rev. 0030 Appendix B (Page 1 ofl)

Phase B Pipe Break Contingencies Ste _Action/Expected Response Response Not Obtained

1. CHECK PHASE B actuated. WHEN PHASE B actuation occurs,

[MISSP 1-XX-55-6C, -6D}

- THEN GO TO step 2.

2. ENSURE 1-FCV-32-1 10 CLOSED. DISPATCH AUO to perform

[CISP 1-XX-55-6E]

- Attachment 2 (E-0).

(A-train, window 13)

3. ENSURE 1-FCV-67-107 CLOSED. DISPATCH AUO to perform

[CISP 1-XX-55-6E]

- Attachment 3 (E-0).

(A -train, window 43)

4. ENSURE 1-FCV-70-92 CLOSED. DISPATCH AUO to perform

[CISP 1-XX-55-6E]

- Attachment 4 (E-0).

(A -train, window 73)

5. ENSURE 1-FCV-70-140 CLOSED. DISPATCH AUO to perform

[CISP 1-XX-55-6F]

- Attachment 5 (E-0).

(B -train, window 74)

Page25of3l

WBN Reactor Trip or Safety Injection E-0 Unit I Rev. 0030 Attachment I (Page 1 of 1)

Ice Condenser AHU Breaker Operation OPEN the following to remove power from ice condenser air handling units AND REPORT completion to UO:

BOARD COMPT NOMENCLATURE 480 V Reactor Vent 13D 1-BKR-232-A000/13D ICE COND Board I A-A 1 -AHU-61 -1/4/8/12/16/20/24/28 480 V Reactor Vent 14D 1-BKR-232-A000/14D ICE COND Board lA-A 1-AHU-61-3/7!1 1/1 5/1 9/23/27 480 V Reactor Vent 13D 1-BKR-232-B000/13D ICE COND Board 1 B-B 1 -AH U-61 -2/6/10/14/18/22/26/30 480 V Reactor Vent 14D 1-BKR-232-B000/14D ICE COND Board 1 B-B 1 -AH U-61 -5/9/13/17/21/25/29 Page 26 of 31

WBN Reactor Trip or Safety Injection E-0 Unit I Rev. 0030 Attachment 2 (Page 1 ofl)

Control Air Isolation A. CLOSE O-ISV-32-1013 CONTROL AIR EL 713 AB HDR ISOL

[A6/S EL. 713] (chain operated behind Fuel and Waste Handling Bd. A).

B. IF O-ISV-32-1013 CANNOT BE CLOSED, THEN OPEN and DISCONNECT C&SS air compressor breakers:

1. O-BKR-32-25 [480V SD BD 1A2-A, C/3D]

2. O-BKR-32-26 [480V SD BD IB1-B, C/3D]

3. O-BKR-32-27 [480V AUX BLDG COM BD, C/6C]

4. O-BKR-32-4900A [480V TURB BLDG COM BD, CI6C]

Page 27 of3l

WBN Reactor Trip or Safety Injection E-O

, Uniti Rev.0030 Attachment 3 (Page 1 ofl)

ERCW Isolation UNLOCK AND CLOSE I -ISV-67-523B, LOWER CNTMT VENT CLR I B &1 D ERCW SUP ISOL [A2U/692] (U-i penetration room North of AB Pipe Chase Cooler 1 B-B in overhead)

Page 28 of 31

WBN Reactor Trip or Safety Injection E-0 Unit I Rev. 0030 Attachment 4 (Page I of I)

CCS Return Isolation CLOSE 1-ISV-70-700, RCP OIL COOLER CCS RETURN ISOLATION

[A4N EL. 710 U-I Penetration Room] (approximately 10 ft. North of Penetration Room Cooler lB-B on mezzanine above RHR Sump Valve Room)

Page 29 of3I

WBN Reactor Trip or Safety Injection E-0 Unit I Rev. 0030 Attachment 5 (Page I of I)

CCS Supply Isolation CLOSE 1-ISV-70-516, REACTOR BUILDING CCS SUPPLY ISOLATION

[A6IT EL. 737] (Behind Elevator approximately 2 ft. west on mezzanine above A CCS Heat Exchanger)

Page300f3l

I !/ Watts Bar Nuclear Plant Unit I Abnormal Operating Instruction AOI-39 Rapid Load Reduction Revision 0014 Quality Related Level of Use: Continuous Use Effective Date: 03-02-201 1 Responsible Organization: OPS, Operations Prepared By: R. A. ORear Approved By: Brian Mcllnay

WBN Rapid Load Reduction AOI-39 Unit I Rev. 0014 Revision Log Revision Affected or Change Effective Page Number Date Numbers Description of RevisionlChange 9 06/20/06 2, 4, 5 Revised condenser backpressure requirements per PC 52076-A 10 06/22/07 2, 4 Revised condenser backpressure requirements per DCN 52215 stage 1.

11 08/30/07 2, 6, 20, 21 Non-intent. Added Step I RNO transit to Appendix A on a failure of turbine load reduction in AUTO. Complies with changes made to GO-4 for PER125I 13.

12 03/07/08 4, 5-6, 12 Replaced Table 1 and cautions at beginning of step 3.1, Section 3.2 & 3.3 for DCN 52228.

13 02/24/10 All Converted from W95 to W2003 using Rev 12.

Deleted table for recommended boration rates and referenced Reactivity Briefing Sheet.

Added concern for AFD to Caution for over borating. Included Reactivity Control Plan discussion into section 4.0. [PCR 3827] Added steps to shutdown a MFP [PCR 3449]

Added step to place EHC in IMP-IN. [PCR 4219] Enhanced steps for borating to provide flexibility to control AFD and Rod position.

[PCR 3328, 3318]

Changed target band for AFD to +/-3% as outlined in NOB. Added TI-7.012 as a Developmental Ref.

14 03/02/1 1 2, 4, 6- Reversed order of steps to ensure boration is 9,13, 14, started first as recommended by Reactivity 17, 19, 22- Management Review Board.

24 Minor editorial changes included: added page numbers to Diagnostic box, updated source identification, added Greek symbol (p) to steps directly affecting reactivity.

Page 2 of 24

WBN Rapid Load Reduction AOI-39 Uniti Rev.0014 1.0 PURPOSE This Instruction provides the guidance to initiate a controlled load reduction whenever plant conditions require a rapid power reduction without a reactor trip.

2.0 SYMPTOMS A. Tech Spec Safety Limit being exceeded.

B. Tech Spec Limiting Condition for Operation (LCO) and/or ACTION not being satisfied due to circumstances in excess of those addressed in LCO 3.0.3.

C. Expiration of a Tech Spec ACTION time.

D. Serious condition requiring rapid load reduction to prevent or minimize a more serious condition, but not requiring a unit trip.

E. The SM has determined that plant conditions require a rapid load reduction at less than or equal to 5% per minute.

2.2 Indications A. NONE 2.3 Automatic Actions A. If a signal has occurred requiring an Auto turbine runback and the runback failed to occur, then action should be taken in accordance with AOl-I 6, Loss Of Normal Feedwater or AOI-37, Turbine Runback Response.

PagQf24

WBN Rapid Load Reduction AOI-39 Unit I Rev. 0014 3.0 OPERATOR ACTIONS 3.1 Diagnostics CAUTION Condenser backpressure should be maintained less than the limits of Table I during load reduction-see next page.

NOTE Load reduction rate shall be limited to a maximum of 5%/mm. If greater than 5% is required or becomes necessary, then reactor should be tripped.

IF GO TO Subsection Page Reactor power is greater than 50% 3.2 6 Reactor power is less than 50% 3.3 13 Page.4 of 24

A & B and C CONDENSER VACUUM LO-LO AND LO ALARMS C

3 6.50 :hZ CD 3

0 (ft ZONE C) 6.00 (ft 0

3 5.50 3 BZONES CD 0.

I 0

w 5.00 0.

(0 (0) CD 4D (0) 0 C

w C) 0 0

3 4.00 w

z 8 3.50 0(0 3.00 2.50 0 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 LOAD (MWe)

WBN Rapid Load Reduction AOI-39 Unit I Rev. 0014 Step Action/Expected Response sponse Not Obtained 3.2 Power Reduction From Greater Than 50% Power CAUTION Over boration may result in excessive rod withdrawal, T-avg lower than desired, and AFD oscillations.

NOTE

Rod Control should remain in automatic for T-avg Control

Reactivity Briefing Sheet, Thumb Rules (page 3), lists boration flows and volumes for different reduction rates.

Effect of boration will lag behind turbine load reduction and can be compensated for by temporarily increasing boric acid flow rate above recommended rate.

INITIATE a manual boration:

a. DETERMINE recommended a. INITIATE emergency boration.

boration flow rate and volume

1) PLACE boric acid transfer from Reactivity Briefing Sheet:

pump aligned to blender in

b. INITIATE normal boration: FAST speed

1) ADJUST BA flow controller, 2) (p) ADJUST 1-FCV-62-138 to 1-FC-62-139, to desired flow establish desired flow rate.

rate.

3) WHEN boration is complete,

2) ADJUST BA batch counter THEN 1-FQ-62-139 to required CLOSE 1FCV-62-138, quantity. AND

3) PLACE mode selector PLACE boric acid transfer 1-l-IS-62-140B to BOR. pump used in SLOW speed

4) (p) PLACEVCT makeup control 1-HS-6214OA, to START.

5) VERIFY desired boric acid flow indicated on I -Fl-62-I 39.

Page 6of24

WBN Rapid Load Reduction AOl-39 Unit I Rev. 0014 Step Action/Expected Response Response Not Obtained 3.2 Power Reduction From Greater Than 50% Power (continued)

CAUTION

Condenser Backpressure limits are on page 5.

TURBINE MANUAL Operation requires continuous operator monitoring and control.

LOSS OF CONDENSER VACUUM may be made worse if steam dumps are actuated. AOl-Il requires T-ave and T-ref be maintained within 3°F.

NOTE If the initiating condition is corrected, the power reduction may be terminated

2. ESTABLISH a turbine load reduction SELECT TURBINE MANUAL, and rate less than or equal to 5%/mm: PERFORM Appendix A.

a. PLACE turbine in IMP IN OR

b. SET a desired load in the CHECK that turbine control has tripped SETTER with the REFERENCE to MANUAL as indicated by the CONTROL. TURBINE MANUAL pushbutton

c. SET the LOAD RATE at less than backlighted, orequalto5%/min. (p) Momentarily DEPRESS

d. (p) DEPRESS GO pushbutton. the G.V. LOWER at intervals that control load reduction less than or equal to 5% /min.

Page 7 of 24

WBN Rapid Load Reduction AOI-39 Uniti Rev. 0014 Step Action/Expected Response Response Not Obtained 3.2 Power Reduction From Greater Than 50% Power (continued)

NOTE AFD green target band can be monitored using ICS Turn On code DOGHOUSE.

3. MONITOR rod position: (p) ADJUST boric acid flow rate as

Rods above Lo-Lo insertion limit needed to return rods to required position o AFD within Target Band IF higher boric acid flow rate is needed to compensate for load reduction rate, THEN INITIATE emergency boration

1. PLACE boric acid transfer pump aligned to blender in FAST speed

2. (p) ADJUST 1-FCV-62-138 to establish desired flow rate.

WHEN boration is complete, THEN CLOSE 1-FCV-62-138, AND PLACE boric acid transfer pump used in SLOW speed

4. REFER TO EPIP-1, Emergency Plan Classification Flowchart

5. NOTIFY the Load Coordinator of the required load reduction and expected ramp rate Page 8 of 24

WBN Rapid Load Reduction AOI-39 Unit I Rev 0014 Step Action/Expected Response Response Not Obtained 3.2 Power Reduction From Greater Than 50% Power (continued)

NOTE If reactor power is stabilized at a lower level a drop in T-avg will occur due to Xenon build up. Dilution may be required to maintain power level.

6. MONITOR T-avg and T-ref: (p) CONTROL T-avg with Control Rods T-ave trending to T-ref. in manual.

IF T-ave and T-ref mismatch can NOT e Mismatch less than 5°F.

be maintained less than 5°F, THEN TRIP reactor, and GO TO E-O, Reactor Trip or Safety Injection.

7. CHECK rate of power reduction is (p) TRIP reactor, and rapid enough for existing plant **

GO TO E-O, Reactor Trip or Safety conditions. Injection.

8. NOTIFY Cnds Demin AUO of impending pmp shutdowns.

Page 9 of24

WBN Rapid Load Reduction AOI-39 Unit I Rev. 0014 Step Action/Expected Response Response Not Obtained 32 Power Reduction From Greater Than 50% Power (continued)

9. WHEN rated thermal power change exceeds 15% in one hour, THEN NOTIFY Chemistry to initiate 1-S 1-68-28.

10. WHEN between 70 and 75% power, THEN REMOVE one Cnds Bstr Pmp and one Cnds Demin Pmp from service:

PLACE selected Cnds Bstr Pmp handswitch to STOP.

PLACE selected Cnds Demin Pmp handswitch to STOP, and CLOSE the suction valve.

Page 10 of 24

WBN Rapid Load Reduction AOI-39 Uniti Rev0014 Step Action/Expected Response Response Not Obtained 3.2 Power Reduction From Greater Than 50% Power (continued)

NOTE A MFPT may be removed from service at power levels between 65% and 45%, if approved by the SM.

NOTE If holding power level at less than 60%, the Cnds Demin pumps may be left running based on header pressure and the ability of the pumps to pump forward.

11. WHEN between 55 and 70% power, THEN REMOVE both operating Cnds Demin Pumps and one of three #3 Heater Drain Pumps from service:

a. Simultaneously PLACE Cnds Demin Pump handswitches to STOP.

b. CLOSE Cnds Demin Pump suction valves.

c. STOP and PULL-TO-LOCK one of three #3 Heater Drain Pumps.

12. WHEN 65% power is reached, THEN STOP and PULL-TO-LOCK one of two #7 Heater Drain Pumps.

13. WHEN 49% power is reached, THEN CHECK Annunciator Window 69-E, P-9 RX TRIP FROM TURB TRIP BLOCKED, is LIT.

Pagellof24 -

WBN Rapid Load Reduction AOI-39 Uniti Rev.0014

_Step Action/Expected Response Response Not Obtained 3.2 Power Reduction From Greater Than 50% Power (continued)

14. IF Power reduction below 50% is required, THEN GO TO Subsection 3.3, Step 4.

15. STOP The load reduction by depressing HOLD on the Turbine Reference Setter.

16. STABI LIZE Turbine/Reactor power with Tavg/Tref within 3°F.

17. WHEN Boration is COMPLETE, THEN PERFORM the following to REALIGN makeup to AUTO:

a. ENSURE 1-FC-62-142, PWTO BLENDER, on 35% (7ogpm) and Manual-Auto toggle in AUTO.

b. ADJUST 1-FC-62-139, BATO BLENDER, to new RCS CB.

c. PLACE 1-HS-62-140B, VCT MAKEUP MODE, in AUTO.

d. TURN 1-HS-62-140A, VCT MAKEUP CONTROL, to START.

e. CHECK Red light is LIT.

18. GO TO GO-4, Normal Power Operation.

End of Subsection Page 12 of24

WBN Rapid Load Reduction AOl-39 Uniti Rev. 0014 Step Action/Expected Response Response Not Obtained 3.3 Power Reduction From 50% Power CAUTION 9 Condenser Backpressure limits are on page 5.

Avoid excessive rod insertion after turbine is tripped. If resulting reactor power is subcritical or less than desired, rods SHALL NOT be withdrawn in an attempt to recover reactor power.

NOTE If the initiating condition is corrected, power reduction may be terminated.

CHECK reactor power less than or **

GO TO Subsection 3.2 equal to 49%, annunciator window 69-E, P-9 RX TRIP FROM TURBINE TRIP BLOCKED, is LIT.

2. ENSURE rod control in AUTO. Manually INSERT the control bank as turbine load is reduced, maintaining Tavg on program.

CAUTION TURBINE MANUAL operation requires continuous operator monitoring and control.

3. ESTABLISH a turbine load reduction SELECT TURBINE MANUAL, rate of less than or equal to 5%/mm:

OR

a. PLACE turbine in IMP IN CHECK that Turbine Control has

b. SET a desired load in the tripped to MANUAL as indicated by the SETTER with the REFERENCE TURBINE MANUAL pushbutton CONTROL backlighted,

c. SET the LOAD RATE less than (p) Momentarily DEPRESS or equal to 5%/mm. the G.V. LOWER at intervals that

d. (p) DEPRESS GO pushbutton. control load reduction less than or equal to 5%/mm.

Page .laof24

WBN Rapid Load Reduction AOI-39 Uniti Rev. 0014 Step Action/Expected Response Response Not Obtained 3.3 Power Reduction From 50% Power (continued)

4. WHEN 48% reactor power is reached, THEN CHECK annunciator window 70-C, P-8 LO PWR-FLOW TRIP BLOCKED, is LIT.

5. CHECK power reduction rate rapid PERFORM one of the following based enough for existing plant conditions. on plant conditions:

(p) TRIP reactor and ** GO TO E-0, Reactor Trip or Safety Injection.

OR (p) TRIP turbine and **

GO TO AOl-i 7, Turbine Trip.

6. WHEN 45% power is reached, THEN CONTINUE with the procedure.

Page 14 of24

WBN Rapid Load Reduction AOI-39 Unit I Rev. 0014 Step Action/Expected Response Response Not Obtained 3.3 Power Reduction From 50% Power (continued)

7. IF two MFWPs in service THEN SHUTDOWN one MFWP:

a. IF 1A MFWP is to be removed from service, THEN

1) PLACE 1-SIC-46-20A, MFPT A speed control in MANUAL and DECREASE speed.

2) ENSURE recirc valve OPENS

3) WHEN 1A MFP speed is approx 3,300 rpm, THEN PLACE 1-HS-46-9A, to TRIP

4) REFER TO SOl-2 & 3.01, Condensate and Feedwater System to complete shutdown.

Page 15 ot24

WBN Rapid Load Reduction AOI-39 Uniti Rev. 0014 Step Action/Expected Response Response Not Obtained 3.3 Power Reduction From 50% Power (continued)

b. IF lB MFWP is to be removed from service, THEN

1) PLACE 1-SIC-46-20B, MFPT B speed control in MANUAL and DECREASE speed.

2) ENSURE recirc valve OPENS

3) WHEN lB MFP speed is approx 3,300 rpm, THEN PLACE 1-HS-46-36A, to TRI P

4) REFER TO SOl-2 & 3.01, Condensate and Feedwater System to complete shutdown.

8. STOP the second #7 Heater Drain Tank pump, and PLACE both #7 Heater Drain Tank pumps handswitches in PULL TO LOCK.

9. CLOSE #7 Heater Drain Tank pumps discharge valves:

o 1-HS-6-143A

1-HS-6-163A

1-HS-6-184A Page 16 of 24

WBN Rapid Load Reduction AOI-39 Unit I Rev. 0014 Step Action/Expected Response Response Not Obtained 3.3 Power Reduction From 50% Power (continued)

10. WHEN less than 40% power, Manually PUSH AMSAC THEN Test/BIk/Operate, I -HS-3-264A CHECK 1-HS-3-264A, AMSAC AMSAC TEST/BLOCK pushbutton.

BLOCK <40% light is LIT.

11. WHEN 30% power is reached, THEN PERFORM the following:

a. ENSURE turbine is operating in the IMP OUT position.

b. STOP and PULL-TO-LOCK one of two #3 Heater Drain Pumps.

c. STOP one of two operating CBPs by PLACING the pump handswitches to STOP.

d. STOP one of three operating Hotwell Pumps.

12. STABILIZE the unit between 20 PERFORM either of the following:

and 30% reactor power with reliable (p) TRIP reactor and steam/feed flow indications. **

GO TO E-0, Reactor Trip or Safety Injection.

OR (p) TRIP turbine and GO TO AOl-i 7, Turbine Trip.

13. EVALUATE conditions to determine if turbine AND reactor shutdown required.

17 of 24

WBN Rapid Load Reduction AOI-39 Unit I Rev. 0014 Step _Action/Expected Response Response Not Obtained 3.3 Power Reduction From 50% Power (continued)

14. WHEN Boration is COMPLETE, THEN PERFORM the following to REALIGN makeup to AUTO:

a. ENSURE 1-FC-62-142, PWTO BLENDER, on 35% (7Ogpm) and Manual-Auto toggle in AUTO.

b. ADJUST 1-FC-62-139, BATO BLENDER, to new RCS CB.

c. PLACE 1-HS-62-140B, VCT MAKEUP MODE, in AUTO.

d. TURN 1-HS-62-140A, VCT MAKEUP CONTROL, to START.

e. CHECK Red light is LIT.

15. WHEN rated thermal power change exceeds 15% in one hour, THEN NOTIFY Chemistry to initiate 1-S 1-68-28.

Page 18 of 24

WBN Rapid Load Reduction AOI-39 Unit I Rev. 0014 Step Action/Expected Response Response Not Obtained 3.3 Power Reduction From 50% Power (continued)

16. PERFORM the following:

o REFER TO GO-5, Unit Shutdown From 30% Reactor Power To Hot Standby for guidance in removing equipment from service.

(p) ADJUST reduction rate as necessary to facilitate removal of equipment and maintain controlled conditions.

o CONTINUE rapid load reduction.

End of Subsection Page 19of 24

WBN Rapid Load Reduction AOI-39

Uniti Rev.0014 4.0 DISCUSSION A. When removing the unit from service with conditions that require a rapid shutdown from 100% RTP, it is advisable to begin a boration in accordance with the applicable Reactivity Control Plan. The boration should assist in keeping the rods above the RIL during the power reduction while allowing the rods to insert to maintain TavglTref. The inserted rods should provide the capacity to withdraw rods and stabilize Tavg in the event that a momentary hold is required during the power reduction.

B. Very fast ramp rates (up to 5%/mm) may result in rods inserting below the RIL briefly until the effects of the boration are realized. The Reactivity Control Plan boration volumes are calculated to maintain nominal rod position for AFD control. Boration should be started at the beginning of the power reduction.

Time outside of the plus or minus 3% target band during the load reduction is allowed, but should be minimized in order to limit the resultant Xenon oscillation. Rods should remain in automatic for Tavg control during the load reduction until the applicable Reactivity Control Plan specifies Manual control.

C. For events requiring a partial load reduction at a rapid rate such as an automatic turbine runback or the need for manual run back the turbine in order to remove equipment from service, the load reduction should be made using rods for Tavg control. Boration should be initiated as soon as the unit is stabilized at the new lower power level in order to clear any RIL alarms and to return AFD to within limits. Placard values can be used to commence the initial boration, and then the rod position can be optimized by a more detailed review of the Reactivity Control Plan. The guidance for a partial load drop assumes a rapidly evolving transient occurring over a short duration. In situations requiring a partial load reduction of greater than 50% load, and it is determined during the evolution that the RIL is being exceeded, then a boration should be commenced during the load reduction as soon as time and operator span-of-control allows.

D. For power levels less than 50% power the TS limits for AFD do not apply.

While it is desirable to maintain Delta Flux within the target band for all power levels greater than 15%, it should be emphasized that plant stability and maneuverability is a higher priority than Delta Flux control at low power levels.

Page 20 of 24

WBN Rapid Load Reduction AOl-39 Unit I Rev. 0014

5.0 REFERENCES

5.1 Performance A. AOl-i 6, Loss of Normal Feedwater.

B. AOl-17, Turbine Trip.

C. AOl-37, Turbine Runback Response.

D. E-0, Reactor Trip Or Safety Injection.

E. GO-4, Normal Power Operation.

F. GO-5, Unit Shutdown From 30% Reactor Power To Hot Standby.

G. EPIP-1, Emergency Plan Classification Flowchart.

H. 1-Sl-68-28, Primary Radiochemistry Requirements.

I. SOl-2 & 3.01, Condensate and Feedwater System.

J. SOl-62.02, Boron Concentration Control.

5.2 Developmental A. SPP-i0.4, Reactivity Management Program.

B. Tl-7.01 2, Administration Of The Reactivity Briefing Sheets And Reactivity Control Plan 5.3 Technical Specifications A. 3.1.1, Shutdown Margin (SDM) T-avg

- > 200°F.

B. 3.1.7, Control Bank Insertion Limits C. 3.2.3, Axial Flux Difference (AFD)

D. LCO 3.0.3 Page2l o124

WBN Rapid Load Reduction AOI-39 Uniti Rev.0014 Appendix A (Page 1 of 2)

Operating with Turbine Controls in Manual Mode 1.0 INSTRUCTIONS NOTES

1) This section should only be used when the OPERATOR AUTO mode is malfunctioning and the turbine is online.

2) When the turbine controls are in MANUAL mode the active Turbine Manual buttons will be illuminated.

3) Turbine load changes immediately when a raise or lower button is pressed.

4) Brief momentary button presses are best for making small load changes.

5) Raising and Lowering load contained in steps 1 .OB and 1 CC below may be used alternatively to achieve desired load.

A. IF turbine controls are NOT in TURBINE MANUAL mode AND TURBINE MANUAL mode is desired, THEN PRESS TURBINE MANUAL button in TURBINE MODES group.

B. INITIATE load reduction by PERFORMING the following on the Turbine EHC panel:

1. (p) MOMENTARILY PRESS the lower button (GV) in the TURBINE MANUAL group.

2. MONITOR REFERENCE DROP.

3. REPEAT Substeps 1.OB.1 and 1.OB.2 as required to achieve desired load.

Page 22 of 24

WBN Rapid Load Reduction AOl-39 Unit I Rev. 0014 Appendix A (Page2of2)

Operating with Turbine Controls in Manual Mode 1.0 INSTRUCTIONS (continued)

CAUTION Raise and Lower buttons operate Governor Valves at a rate of 33%! minute. If Fast push button is also depressed at the same time the valve movement rate is 133.3%! minute.

C. INITIATE load increase by PERFORMING the following on the Turbine EHC panel:

1. (p) MOMENTARILY PRESS the raise button (GV) in the TURBINE MANUAL group.

2. MONITOR REFERENCE INCREASE.

3. REPEAT Substeps 1.OC.1 and 1.OC.2 as required to achieve desired load.

D. IF OPERATOR AUTO turbine control mode is desired, THEN PRESS OPER AUTO button in TURBINE MODES group.

Page 23 of 24

WBN Rapid Load Reduction AOI-39

Uniti Rev 0014 Source Notes (Page 1 ofl)

Implementing Affected Requirements Statement Source Document Statement Steps Rewrite GO1-6 to become a rapid SOER 94-01 Rec. 2 C.1 Afl load reduction procedure.

Page 24 of 24

I !/1 Watts Bar Nuclear Plant Unit I System Operating Instruction SO I -2&3.O1 Condensate And Feedwater System Revision 0112 Quality Related Level of Use: Multiple Effective Date: 02-17-2011 Responsible Organization: OPS, Operations Prepared By: R. A. ORear Approved By: - Brian Mclnay

WBN Condensate And Feedwater System SOI-2&3.01 Uniti Rev 0112 Page2of 242 Revision Log Revision Affected or Change Effective Page Number Date Numbers Description of Revision/Change 110 10/27/10 2,9, 11-13, 29, 34, Created Section 8.28 to facilitate fast 44, 45, 48, 49, 51, draindown of hotwell (PCR 4288).

Corrected Source Note notation 82-84: 88..90,99, (PCR 4432).

102-104, 108, 110, Enhanced hose step in Section 8.25.

113, 115, 121-123, Added MFP trip oil press verification to Eng 131-134,136,138, recommended value due to 140, 142, 146, 149, SQN-NOER-10-032.

151, 155, 156, 158, Minor/editorial changes:

170-172,174, 177, Revised TE NOTE in Section 5.4 and 5.5 180, 184-1 87, 189, and deleted incorrect TE NOTE in Section 214-217

208, 5.4 to clarify which TEs need to be above 250°F (PER 232129).

Added Critical Step markers and Critical Evolution consideration step to Sections 8.22.1 and 8.22.2 (PER 246210).

Revised NOTE 1 in Section 5.10 and 5.11 (PCR 4629).

Updated Maintenance Shop names, WO to SR, and RADCON to RP.

Revised section closure steps.

Corrected minor formatting errors.

1 11 12/20/2010 2, 35, 124, 217, Added infrequent section 8.29 to align 218 condensate to suction of MFWP to use recirc valve flowpath to condenser for cooling.

Added HS information for operating FCV-3-205 in section 7.3.3 step 4 [PER 268677]

112 02/17/11 2, 18, 70-76, 78- Revised and clarrified sections 5.10 and 84, 86,95-100, 5.1 1 to control MEW pump trip bus breakers 102-103, 105, 106, and to work in conjunction with and allow

, preparations to be performed in parallel with GO-2. [PCR 5003] Made minor format changes to Sections 5.10 and 5.11 to enhance configuration control and comply with Writers Guide.

WBN Condensate And Feedwater System SOI-2&3.01 Uniti Rev.0112 Page3of 242 Table of Contents

1.0 INTRODUCTION

7 1.1 Purpose 7 1.2 Scope 7

2.0 REFERENCES

8 2.1 Performance References 8 2.2 Developmental References 9 3.0 PRECAUTIONS AND LIMITATIONS 11 4.0 PREREQUISITE ACTIONS 21 4.1 PreliminaryActions 21 4.2 Field Preparations 22 4.3 Approvals and Notifications 22 5.0 STARTUP 23 5.1 Short Cycle Operation 23 5.2 Establishing Condenser Vacuum 30 5.3 Long Cycle Deaeration 35 5.4 Power Escalation 45 5.5 Long Cycle Operation 45 5.6 Bypass Reg to Main Reg Transfer (Method 1) 52 5.7 Bypass Reg to Main Reg Transfer (Method 2) 54 5.8 Condensate Booster Pump Operation 56 5.9 Standby Main Feed Pump Operation Or Standby Alignment 61 5.10 MFP lAOperation 70 5.11 MFPlBOperation 95 5.12 Condensate Demin Pump Operation 118 6.0 NORMAL OPERATION 120 6.1 Condensate Processing And Handling 120

6. Qpraton of the Feedwater System 120 6.3 Condensate System 121

WBN Condensate And Feedwater System SOl-2&3.01 Uniti Rev.0112 Page4of 242 Table of Contents (continued) 7.0 SHUTDOWN 122 7.1 Shutdown Cond Demin Pumps 122 7.2 Shutdown Condensate Booster Pumps 123 7.3 MFP SHUTDOWN 125 7.3.1 TDMFP Shutdown 125 7.3.2 Standby Main Feed Pump Shutdown 131 7.3.3 Standby MFP Shutdown And Standby Alignment 132 7.4 Main Reg to Bypass Reg Transfer 135 7.5 Shut Down Condensate System from Long Cycle Deaeration 138 7.6 HWP Shutdown 141 7.7 Removing CBP and MFP from Service During Shutdown 142 8.0 INFREQUENT OPERATIONS 143 8.1 CST A Cleanup via Condensate System 143 8.2 Swapping MFPT Duplex Filter IA and 1 B 144 8.2.1 Swapping MFPT Duplex Filter IA 144 8.2.2 Swapping MFPT Duplex Filter lB 146 8.3 Align CST B for Ui Hotwell Makeup 148 8.4 Transfer Water between CSTs 150 8.5 Placing MFPs on Turning Gear During Shutdown 152 8.6 Isolate MFPT A or B 156 8.7 Alternating HWPs 159 8.8 Guidelines for Starting SMFP with Short Term Use of 1-FCV-3-195 161 8.9 Replacing Turbine Driven MFP with SMFP, or Periodic Operation of SMFP 165 8.10 Transferring Hotwell Level Transmitters 168 8.11 Placing Condensate In Service to SGBD First Stage HXs 171 8.12 Starting CVPs With Vacuum Established 174 8.13 Swapping MFP Turbine Oil Coolers 176 8.14 CST A Heatup via Condensate ystem 180

WBN Condensate And Feedwater System SOI-2&3.01 Unit I Rev. 0112 Page5of 242 Table of Contents (continued) 8.15 Removing Condensate From Service to SGBD First Stage HXs 181 8.16 Hot Well Pump Operation at Power 182 8.16.1 HWPShutdownatPower 182 8.16.2 HWP Startup at Power 184 8.17 Condensate Booster Pump Operation at Power 187 8.17.1 CBPShutdownatPower 187 8.17.2 CBP Startup at Power 190 8.18 Check For Water Accumulation On Discharge Of Vacuum Pumps 194 8.19 Isolate Hotwell From CST 195 8.20 Transfer Water from CSTs to Station Sump 196 8.21 Checking Condenser Vacuum Inleakage 199 8.22 Adjust Main Feed Pump Hand Speed Changers 201 8.22.1 Adjust A Main Feed Pump Turbine Hand Speed Changer 201 8.22.2 Adjust B Main Feed Pump Turbine Hand Speed Changer 204 8.23 Adjust CBP Oil Temperature During Plant Operation 207 8.24 Swapping MFPT Main Oil Pumps With MFPT In Service 208 8.24.1 Swapping 1A MFPT Main Oil Pumps 208 8.24.2 Swapping lB MFPT Main Oil Pumps 210 8.25 Condenser Water Level Control 212 8.26 Throttling H/P Steam Supply Isol During MFPT Startup 214 8.26.1 Throttling 1A MFPT H/P Steam Supply lsol During Startup 214 8.26.2 Throttling lB MFPT H/P Steam Supply Isol During Startup 216 8.27 Post Trip Cooldown of Feedwater Lines 218 8.28 Fast Draindown of Hotwell 224 8.29 Modified Longcycle for Condensate Cooling While Shutdown 226 9.0 RECORDS 228 9.1 QARecords 228 9.2 Non-QA Records 228 Appendix A: MFPT Duplex Filters IA And lB 229

WBN Condensate And Feedwater System SOl-2&3.O1 Uniti Rev.0112 Page 6 of 242 Table of Contents (continued)

Appendix B: SG Program Level-vs-Nuclear Power 231 Appendix C: Main Feed Pump Hot Start 234 Appendix 0: Main Feed Pump Cold Start 235 Appendix E: CBP Oil And Bearing Temperature Trending 239 Source Notes 241 ATTACHMENTS Attachment IH: Condensate And Feedwater System Handswitch Checklist 2&3.O1-IH Attachment IP: Condensate And Feedwater System Power Checklist 2&3.O1-IP P: Condensate And Feedwater System Power Checklist 2&3.O1-2P Attachment IV: Condensate And Feedwater System Valve Checklist 2&3.Ol-1V V: Condensate And Feedwater System Valve Checklist 2&3.Ol-2V

WBN Condensate And Feedwater System SOI-2&3.01 Unftl Rev.0112 Page 7 of 242

1.0 INTRODUCTION

1.1 Purpose To provide instructions for operation of the Condensate and Feedwater Systems.

1.2 Scope This Instruction includes startup, normal operation, and shutdown [cli] operation of the following equipment:

A. Hotwell Pumps B. Condensate Booster Pumps C. Main Feed Pumps (MFP) c.iij D. Standby Main Feed Pump (SMFP)

E. Condenser Vacuum Pumps (CVP)

F. Condensate Demin Pumps

WBN Condensate And Feedwater System SOl-2&3.01 Uniti Rev.0112 Page8of 242

2.0 REFERENCES

2.1 Performance References A. SOl-2.02, Condensate Startup Filter B. SOl-3.02, Auxiliary Feedwater System C. SOl-5&6.O1, Extraction Steam, Heater Drains, and Vent System D. SOl-14.O1, Condensate Demineralizer Polisher Operation E. SOl-25/26.O1, Raw Service and High Pressure Fire Protection Systems F. 501-37.01, Gland Seal Water System G. SOI-47.O1, Main Turbine Turning Gear Operation H. SOI-47.03, Main Turbine Steam Seal System I. SOI-54.O1, Injection Water System J. SOl-90.02, Gaseous Process Radiation Monitors K. SOl-90.05, Post-Accident Rad Monitors L. TI-i 01 .03A.O1, System 3A, MFP Periodic Checkout Operation Using Aux Boiler Steam M. 0-Pl-OPS-17.0, 18 Month Locked Valve Verification N. Ml-57.036, Electric Motor/Generator Replacement and Bearing

0. 0-Pl-OPS-1.i, Jumper Control Process

WBN Condensate And Feedwater System SOl-2&3.O1 Uniti Rev.0112 Page 9 of 242 2.2 Developmental References A. SOI-2.03, Main Condenser Fast Fill and Drain B. N3-2-4002, System Description, Condensate System C. N3-3A-4002, System Description, Main Feedwater, Feedwater Control, and Injection Water D. Vendor Manuals:

1. WBN-VTM B580-0010, Byron Jackson, Contract 083018, #0038

2. WBN-VTM-B580-0030; Vendor Technical Manual For Byron Jackson Condensate Booster, Condensate Hotwell, #3 & #7 Heater Drain And Standby Main Feed Pumps; Byron Jackson, Ingersoll-Rand, Contract 083174

3. WBN-VTD-B580-0150; Installation, Operation And Maintenance Instructions For The Byron Jackson Standby Main Feed Pumps [PUB. #

G404550]

4. WBN-VTM-W1 20-2094

5. WBN-VTD-P076-0020, Parson-Peebles Operating and Maintenance Instructions For Standby Main Feed, Hotwell, Booster, NO. 3 and NO. 7 Heater Drain Pump Motors [PUB. # AGC1254498-502]

WBN Condensate And Feedwater System SOl-2&3.01 Unitl Rev. 0112 Page 10 of 242 22 Developmental References (continued)

E. WA Drawings:

1. 45B1754-5C

2. l-45B6236-010, -011, -017, -020, -033, -034, -035, -041, -042, -043, -044

3. 1-45B6275-011, -028

4. 45N700-l

5. 45N721-1

6. 1-45W600-2, -3, -5, -6, -7, -8, -9, -11

7. 1-45W600-46-1, -3, -4, -5, -7

8. l-45W600-57-l, -2, -31

9. 1-45W703-1

10. 1 -45W753-7

11. 1-45VV760-2-1 through -5

12. 1-45W760-3-1 through -11

13. 1 -45W1 646-2

14. 1-47W803-1

15. 1-47W804-1,-2

WBN Condensate And Feedwater System SOI-2&3.01 Uniti Rev.0112 Page 11 of 242 3.0 PRECAUTIONS AND LIMITATIONS A. Hotwell/Hotwell Pumps I. Failure to isolate 1-LCV-37-1, GSW STOR TNK MU LEVEL CNTL, before starting the first Hotwell Pump, will result in GSW Tank overflow.

2. Flow from the Hotwell to the CSTs should be limited when condenser vacuum does NOT exist. Notify Chemistry for contingent actions. [c.12)

3. Filling Hotwell 18 or more above normal when water temp is below 60°F could cause Condenser wall weld failure.

4. 1-LCV-2-9, MAIN CONDENSER AUTO MAKEUP LEVEL CNTL, has a hole drilled in valve to allow 8 to 10 gpm leak-by with valve closed, thus raising Hotwell level.

5. Pumping Hotwell water to the CST when vacuum is broken raises CST 02.

6. Hotwell Pump motor bearing temp alarm should be set at 225°F or lower.

Max temperature limit on bearings is 300°F per reference 2.2.A.

7. Hotwell pumps require >12 inches Hotwell Level to ensure adequate suction is available. [c.6]

8. If hotwell pump motor has been NOT running for 7 days or more, or motor upper bearing maintenance has just been performed, Mechanical Maintenance must be contacted to prelube the upper bearing by removing about a cup of oil from the drain valve at the bearing sight glass and adding it back through the oil filler/breather connection at the top of the bearing.

(Ref: MI-57.036, Attachment 1, Step 1.B)

B. Common/Misc Systems

1. Since the Condenser Vacuum Exhaust effluent must be monitored for a SG tube leak, and the CVE monitors must remain isolated until vacuum is achieved to avoid water damage, the following comp measures must be taken per guidance in System Description N3-2-4002, Section 4.10:

a. SG blowdown rad monitors should be placed in service.

b. Sampling provisions of the ODCM will be used to assess radioactive effluents out of the CVE.

WBN Condensate And Feedwater System SOI-2&3.01 Unitl Rev.0112 Page 12 of 242 3.0 PRECAUTIONS AND LIMITATIONS (continued)

2. RCW supplies to various oil Hxs throughout system are isolated to prevent excessive oil cooling and condensation in piping. Care should be taken to ensure these valves are open before starting associated equipment.

3. Injection Water Pump damage may occur if operated over 4 minutes without at least one MFP receiving seal flow. Pumps have no recirc capability.

4. Steam Dumps to the Main Condenser should NOT be used with a water box out of service. Prolonged exposure to super heated steam in a water box without circ water may cause damage to condenser tubes and adversely impact Condenser Vacuum Pump performance.

5. 1-FS-2-35 permits 1-FCV-15-43 to open at greater than 3500 gpm condensate flowrate.

6. To protect the condensate demins, 1-TS-1543 alarms at greater than or equal to 145°F blowdown fluid temperature and closes 1-FCV-15-43 at greater than or equal to 1 50°F.

7. 1-FCV-2-260, (actuated by 1-PDI-2-260), maintains a constant L\P across the second stage HXs and the GSC.

8. 1-FCV-2-329B is modulated by 1-PDIC-2-329 to maintain 2.1 psid across the first stage HXs (1-FCV-2-329A full open).

9. During unit startup, 1-FCV-2-329A is fully open, initially. As load rises, 1-FCV-2-3298s capacity to maintain 2.1 psid is exceeded. At 2.8 psid (13% load) across low pressure heaters, 1-FCV-2-329B closes and 1-FCV-2-329A is modulated by 1-TIC-2-329A to maintain 230°F condensate temperature out of the first stage heat exchangers.

10. If SGBD flow is being initiated or isolated with unit at greater than 13%

load, 1-FCV2-329A could be fully closed. This valve should be partially opened to ensure condensate flow through first stage heat exchanger prior to initiating SGBD flow to prevent water hammer. Controller gain/setpoint may be adjusted as required to maintain stable system operation as directed by System Engineering/Instrument Maintenance (IM).

11. Chemistry should be notified before initiating Short Cycle, Long Cycle, or Power Operation to coordinate chemical addition and sampling activities.

12. Instrument Maintenance should be notified to ensure required instruments are in service as necessary to support system operation. -

WBN Condensate And Feedwater System SOI-2&3.O1 Uniti Rev.0112

. Pagel3of242 3M PRECAUTIONS AND LIMITATIONS (continued)

13. Work in Radiologically Controlled Area (RCA) requires the use of existing RWPs, and may require additional ALARA Preplans. Failure to follow posted Rad control requirements can cause unnecessary radiation exposure. Radiation Protection should be notified of work having the potential to change radiological conditions.

14. Steps that directly affect reactivity will be preceded with the Greek symbol (p).

C. Condensate

1. Before pressurizing the Condensate System or drawing a vacuum, consideration should be given to Injection Water, Gland Seal Water, Auxiliary Feedwater, Exhaust Hood Sprays, and Chemical Feeds.

2. Cond Demin AUO should be notified before starting pumps that could affect Cond Demin AP, to allow actions to prevent high AP auto-bypass.

3. Normal Condensate operating temp limit is 140°F. Operating above 140°F can damage Cond Demin Resin.

D. Shortcycle

1. Short Cycle is not for long-term operation. Due to piping vibration and movement, Short Cycle operation should be minimized by proceeding to Long Cycle recirc as soon as reasonable, when the required conditions are satisfied.

E. Long Cycle Deaeration

1. Used when:

a. SG temp is 400°F or less (not required when in Hot Standby with NO possibility of injecting into SGs, i.e., NO feedwater pumps in service) and MFW ISOL MOVs closed.

b. Condensate press below 350 psig (below 550 psig if operating CBP).

c. SG press atmospheric or greater.

d. Condensate temp 100°F or greater (If Unit Heatup/Startup in progress).

WBN Condensate And Feedwater System SOl-2&3.01 Uniti Rev.0112 Page 14 of 242 3.0 PRECAUTIONS AND LIMITATIONS (continued)

2. The deaeration line valves (1-ISV-3-602 and 1-FCV-3-195) should be open during long-cycle deaeration with only HWPs operating and closed during all other modes. 1-FCV-3-195 will NOT withstand the higher pressure drop caused by the MFPs. [C.17)

F. Condensate Booster Pumps

1. The minimum oil temperature recommendation is 70°F to 80°F. This is based on ensuring adequate oil is available during startup, when the oil temperature is lowest. (with oil temperature this low, the auxiliary oil pump may trip on overload, or the oil relief valve may lift due to high pressure and cause the bearing to be starved). The maximum oil temperature is 135°F.

This is based on allowing a maximum oil temperature out of the bearing of 185°F, with a 40°F rise across the bearing.

2. If injection water is aligned to a non-running Condensate Booster Pump, the pump should either be promptly started or injection water isolated to avoid water intrusion to the CBPs oil system.

G. Standby Main Feedwater Pump

1. 1-PCV-3-40 must be set at 1200 psia and closed, and 1-FCV-3-195 closed before starting any of the three MFPs.

2. The Standby Main Feed Pump minimum oil temperature recommendation is 70°F to 80°F. This is based on ensuring adequate oil is available during startup, when the oil temperature is lowest. (with oil temperature this low, the auxiliary oil pump may trip on overload, or the oil relief valve may lift due to high pressure, and cause the bearing to be starved). The maximum oil temperature is 135°F. This is based on allowing a maximum oil temperature out of the bearing of 185°F, with an 40°F rise across the bearing.

3. Standby Main Feed Pump (SMFP) should be operated at low flow conditions without a Condensate Booster Pump, to prevent lifting #1 Heater relief valves at 1650 psig.

4. SMFP Motor, Gear, and Pump Lube systems should be heated to 140 to 160°F oil leaving the bearings before placing RCW in service to the oil coolers. Oil temp alarm is 170°. This helps limit startup vibration.

WBN Condensate And Feedwater System SOI-2&3M1 Uniti Rev.0112 Page 15 of 242 3.0 PRECAUTIONS AND LIMITATIONS (continued)

5. A feedwater isolation (FWI) signal will cause the SMFP miniflow valves to fully open. The valves will return to their modulated position on FWI signal reset, or they can be controlled manually. This design change was made to give the miniflow valves a head start open signal on FWI to limit the delta pressure transient across the valves for improvement of operation and service life.

6. The following are monitored during Standby MFP operation. Pump is manually tripped if manufacturers limit is reached and no auto-trip occurs.

PARAMETER MANUFACTURERS LIMIT Low Suction Press 100 psig (below 50% load) 250 psig (50% load or above)

High Discharge Press 1363 psig Low Bearing Oil Press 8 psig or less (Auto Trip) 10 psig or less (Auto Trip)

High Bearing Metal Temp 225°For more (Journal & Thrust)

7. If SBMFP vibration is greater than or equal to 5 mils, evaluate Unit load reduction to allow removal of pump from service. If vibration reaches 10 mils, immediately trip the pump.

8. The following guidance may be used to start or stop the SBMFP during hot weather:

NOTE The MFPT CONDENSER VACUUM LO alarm [Window 55-D] comes in at 12.5 Hg vacuum (17.5 HgA). This corresponds to a MFPT condenser drain temperature of185°F.

If the SBMFP is in service due to elevated hotwell and circulating water temperatures, the following guidance may be used to remove the SBMFP from service as water temperatures drop:

The SBMFP may be secured if any of the following conditions exist:

a. Both MFPT condensers are 12.5 in. HgA, OR

b. Hotwell pump discharge temperature drops to 129°F, OR

WBN Condensate And Feedwater System SOI-2&301 Uniti Rev.0112

. Pagel6of242 3.0 PRECAUTIONS AND LIMITATIONS (continued)

c. C zone main condenser back pressure drops to 5.0 in. HgA, OR

d. CCW inlet temperature drops to 87°F (should be secured prior to 67° F) with all 4 CCW pumps in service, OR

e. MFPT Condenser drain temperature 171°F.

If the SBMFP is NOT in service, the following guidance may be used to place the SBMFP in service as water temperatures rise:

The SBMFP should be placed in service if any of the following conditions exist:

f. Either MFPT condensers are >15.4 in. HgA, OR

g. Hotwell pump discharge temperature achieves the maximum allowable condensate polisher inlet temperature of 140°F, OR

h. C zone main condenser back pressure achieves the alarm setpoint when operating above 90% power, OR

i. Plant power is power limited due to C Zone main condenser back pressure exceeding the associated alarm setpoint, OR

j. MFPT Condenser drain temperature >180°F.

9. All jumper installation and removal shall be in accordance with 0Pl-OPS-1 .1, Jumper Control Process.

H. MFWPs/MFPTs

1. MFPTs and MFPs Motor, Gear, and Pump Lube systems should be heated to 140 to 160°F oil leaving the bearings before placing RCW in service to the oil coolers. Oil temp alarm is 170°F. This helps limit startup vibration.

2. The MFPT turning gear is NOT designed to be rolled off like the main turbine. Any action or evolution that could spin the MFP turbine while the turning gear is in operation could result in damage if the turning gear is NOT removed from service. Example: Unisolating the manual valves to the HP or LP steam supply.

3. MFP suction press should be kept as low as possible to help prevent exceeding the discharge piping design pressure of 1230 psig. However, short duration disch press up to 1363 psig is acceptable.

WBN Condensate And Feedwater System SOI-2&3.01 Uniti Rev.0112 Page 17 of 242 3.0 PRECAUTIONS AND LIMITATIONS (continued)

4. The TDMFP should NOT be operated until sufficient forward flow (approx 4500 gpm) can be provided continuously to the SGs using the SMFP.

5. Trip of a MFPT, loss of MFPT reset, or reset of a MFP NOT available due to maintenance activities, may cause ESFAS AFW start or require entering LCO 3.3.2, Condition J.

6. A feedwater isolation (FWI) signal will cause the TDMFP miniflow valves to fully open. The vales will return to their modulated position on FWI signal reset, or they can be controlled manually. This design change was made to give the miniflow valves a head start open signal on FWI to limit the delta pressure transient across the valves for improvement to operation and service life.

7. If MFPT steam seals are applied with rotor at rest, rotor, seal, and/or bearing damage can occur. Prolonged admission of seal steam before establishing condenser vacuum may damage condenser. Removing steam seals before condenser vacuum is zero, may damage seals due to high air in-leakage through seals.

8. When extended shutdown of MFP Turbines is required, voltage should be removed from affected MFPT Control Panel to extend relay coil life. [C.4]

9. MFP Turbine vibration is high when operated at rated speed (5012 RPM) and low forward flow or recirc flows. Operator action should be taken to minimize time in this condition to less than 20 minutes, at which time speed should be reduced to achieve acceptable vibration conditions.

10. The following are monitored during MFP operation. MFPs are manually tripped if manufacturers limit is reached and no auto-trip occurs:

PARAMETER MANUFACTURERS LIMIT PUMP Low Suction Press 100 psig (below 50% load) MFPs 250 psig (50% load or above)

High Discharge Press 1363 psig MFPs Low Bearing Oil Press 8 psig or less (Auto Trip) MFPs & MFPT 10 psig or less (Auto Trip)

Low Vacuum 10 in. Hg or less (Auto Trip) MFPT High Thrust Bearing Wear 0.010 in. or more wear displacement MFPT from 0 (Auto Trip)

High Bearing Metal Temp 225°F or more (Journal & Thrust) MFPs & MFPT Overspeed 6006 to 6126 rpm (Auto Trip) MFPT

WBN Condensate And Feedwater System SOI-2&3.O1 Unitl Rev.0112 Page 18 of 242 3M PRECAUTIONS AND LIMITATIONS (continued)

11. If MFP and/or MFPT vibration is greater than or equal to 5 mils, evaluate Unit load reduction to allow removal of pump from service, If vibration reaches 10 mils, immediately trip the pump.

12. In Mode 1, entry into Tech Spec 3.3.2 condition J may be suspended for up to 4 hours4.62963e-5 days 0.00111 hours 6.613757e-6 weeks 1.522e-6 months when placing the second Turbine Driven Main Feedwater Pump (TDMFWP) in service or removing one of two Turbine Driven Main Feedwater Pumps (TDMFWP) from service. Refer to Tech Spec 3.3.2 table 3.3.2-1.

13. In Mode 2, trip function of all Turbine Driven Main Feedwater Pumps (TDMFWP) is required when one or more (TDMFWP) is supplying feedwater to the Steam Generators. During the process of placing the first TDMFW pump in service, the anticipatory AFW auto-start channel for the non-operating TDMFW pump is deenergized to prevent inadvertent AFW auto-start during rollup trip testing and overspeed trip testing. Once the operating TDMFW pump has established sufficient feed flow to maintain SG level, the anticipatory AFW auto-start channel for the non-operating TDMFW pump is placed in the trip condition, and the AFW pumps secured. Refer to Tech Spec 3.3.2.6.e and B 3.3.2.6.e.

14. MFPT condenser initial vacuum is drawn using the Condenser Vacuum Pumps and then swapped to the Main Condenser to prevent creating a large pressure change in the Main Condenser.

MFPs Common/Feedwater

1. 1-PCV-3-40 must be set at 1200 psia and closed, and 1-FCV-3-195 closed before starting any of the three MFPs.

2. MEW discharge piping Overpressure may occur if CBPs or Cond Demin Pumps are operated in conjunction with the MEPs below 50% Power.

3. Loss of MEP Injection Water may result in steaming or hot water leakage into the bearing oil or bearing overheat. Injection Water should be restored immediately or a controlled shutdown of the MEP should be initiated.

4. When MEW flow is stopped, the MEW piping may lose its charge to the main condenser. The line charge and pressure must be reestablished very slowly past the valves or pump used to stop flow, prior to reopening the valves or starting pump, to prevent a severe water-hammer.

WBN Condensate And Feedwater System SOI-2&3.O1 Uniti Rev.0112 Page 19 of 242 3M PRECAUTIONS AND LIMITATIONS (continued)

5. MEW Bypass flows in excess of 84,510 pph will exceed the calibration range of the bypass flow transmitters computer points E0407A, F0427A, F0447A, and F0467A which will make U1118 series ICS venturi -based calorimetric power inaccurate.

6. During startup, the main ERVs and bypass FRV5 should be momentarily throttled almost closed, prior to starting the first higher pressure pump (CDPs, CBPs, MEP5) and the flow and pressure downstream of FRVs established very slowly, to avoid severe water hammer.

7. Eor short duration test purposes, using a single MEP, 1-FCV-3-195 may be opened to allow higher long cycle recirculation flow than achievable via 1-PCV-3-40, with the following limitations:

a. MEW and long cycle piping must be charged and at the higher pressure before opening 1-FCV-3-195.

b. 1-ECV-3-195 to be gradually opened fully and NOT throttled.

c. Limited to two MEW loops with the other two loops main and bypass ERVs and long cycle paths closed (single loop flow performed for SMFP).

d. Throttle flow on the one or two open main ERV5.

e. No two higher pressure pumps (CDPs, CBP, or MEPs) are to be in operation simultaneously.

f. Should only be done during cold shutdown long cycle recirculation.

WBN Condensate And Feedwater System SOI-2&3.0l Unit I Rev. 0112 Page 20 of 242 3.0 PRECAUTIONS AND LIMITATIONS (continued)

J. Low Power (Below 22% Ioad)/Swapover Operations:

1. SG Feedwater additions must be via the upper (bypass) nozzle and should be continuous rather than intermittent, to reduce SG upper nozzle thermal cycling, but intermittent flow is permitted.

2. SC lower nozzle must be isolated (MEW ISOL MOVs closed) to prevent cold water, at the hot lower nozzle, in order to limit the number of feedwater system induced transients and the minimum temperature of continuous EW flow into the S/C preheater region.

3. 1-HS-3-45, LONG CYCLE RECIRC-NORMAL, accomplishes partial auto realignment for the 2 modes; however, manual positioning of some valves is required as directed by this instruction.

4. The interlock functions of 1-HS-3-45, LONG CYCLE RECIRC-NORMAL, are functional, but the operator is expected to take appropriate action if conditions warrant. Feedwater flow to the lower nozzle must be terminated and bypass flow established if any of the following minimums are reached:

(1) MEW line temp below 250°F.

(2) MFW line flow below 14%.

5. A low flow alarm at 20% (ARI-57-63 Window 59-C) gives the operator time to take corrective action before manual actions must be taken when flow drops to <14%. This low flow condition (<14%) is indicated by the extinguishing of the blue Main Flow> SP lights on 1-M-3.

WBN Condensate And Feedwater System SOl-2&3.O1 Uniti Rev0112 Page 187 of 242 Date________ INITIALS 8.17 Condensate Booster Pump Operation at Power 8.17.1 CBP Shutdown at Power CAUTION Consider load reduction of approximately 2% based on current plant conditions.

NOTES

1) When a CBP is stopped near full power the following parameters are expected to change as follows: Feedwater flow will fluctuate and stabilize at original value, MFWP suction pressure will lower approx. 70 psig (See P&L 3.OH.10), and #3 HDT level will fluctuate approximately 1/2 inch.

2) FW Heater levels may fluctuate, consider local monitoring.

3) The ICS may be used to monitor discharge valve closure progress by observing lowering CBP motor power and raising discharge pressure.

4) Precaution 3.OF.2 should be reviewed prior to removing a CBP from service.

[1] ENSURE selected CBP AUX OIL PUMP in P-AUTO:

(N/A other CBP5)

A. 1-HS-2-105A, AUX OIL PMP CNDS BSTR PMP A.

B. 1-HS-2-107A, AUX OIL PMP CNDS BSTR PMP B.

C. 1-HS-2-109A, AUX OIL PMP CNDS BSTR PMP C.

[2] THROTTLE CLOSE selected Condensate Booster Pump discharge valve: (N/A other C BPs)

A. 1-ISV-2-607, CONDENSATE BSTR PUMP IA DISCHARGE ISOL [T7G1685].

B. 1-ISV-2-608, CONDENSATE BSTR PUMP lB DISCHARGE ISOL [T7F/685].

C. 1-ISV-2-609, CONDENSATE BSTR PUMP IC DISCHARGE ISOL [T7F1685].

WBN Condensate And Feedwater System SOI-2&3.O1 Uniti Rev.0112 Page 188 of 242 Date_______ INITIALS 817.1 CBP Shutdown at Power (continued)

[3] PLACE selected CBP(s) handswitch to STOP, AND HOLD UNTIL associated suction valve starts to CLOSE

[1-M-3]: (NIA other CBPs)

A. 1-HS-2-97A, CNDS BSTR PMP A.

B. 1-HS-2-91A, CNDS BSTR PMP B.

C. 1-HS-2-84A, CNDS BSTR PMP C.

[4] ENSURE suction valve CLOSED for applicable CBP [1-M-3]:

(NIA other CBPs)

A. 1-FCV-2-94 [1-HS-2-94A], CNDS BSTR PMP A SUCTION VLV.

B. 1-FCV-2-87 [1-HS-.2-87A], CNDS BSTR PMP B SUCTION VLV.

C. 1-FCV-2-81 [1-HS-2-81A], CNDS BSTR PMP C SUCTION VLV.

[5] LOCALLY OBSERVE pump rotation stops.

[6] CLOSE respective CBP Oil Hx RCW Supply:

(NIA valves not used)

NOMENCLATURE LOCATION POSITION UNID PERF INITIALS CONDENSATE BOOSTER PUMP IA CBP OIL COOLER 1A RCW T7G/685 CLOSED 1-ISV-24-711

, INLET ISOL CONDENSATE BOOSTER PUMP lB

CBP OIL COOLER lB RCW T7F1685 CLOSED l-ISV-24-710 INLET ISOL CONDENSATE BOOSTER PUMP IC

CBP OIL COOLER 1C RCW T7F1685 CLOSED l-ISV-24-709 INLET ISOL

WBN Condensate And Feedwater System SOI-2&3.O1 Uniti Rev.0112 Page 189 of 242 Date________ INITIALS 8.17.1 CBP Shutdown at Power (continued)

NOTE Approximately 30 minutes should be allowed from time of pump shutdown to allow pump casing to cool to prevent seal leakoff from flashing to steam.

[7] CLOSE the applicable Seal Water Injection valves for the CBP being shutdown: (N1A other CBP5)

NOMENCLATURE LOCATION UNID PERF INITIALS CNDS BSTR PUMP 1A SEAL T8G1685.5 1-ISV-54-540 WTR INJ ISOL CNDS BSTR PUMP lB SEAL T8F/685.5 l-ISV-54-541 WIR INJ ISOL CNDS BSTR PUMP ic SEAL T8F/685.5 i-ISV-54-542 WTR NJ ISOL CNDS BSTR PUMP 1A SEAL T8G/685.5 1-LOV-54-543 WTR LEAKOFF CNDS BSTR PUMP lB SEAL T8F/685.5 l-LOV-54-544 WTR LEAKOFF CNDS BSTR PUMP 1C SEAL T8F/685.5 l-LOV-54-545 WTR LEAKOFF

[8] IF stopping the Aux Oil Pump, THEN PLACE selected CBP AUX OIL PUMP in STOP/PULL-TO-LOCK: (NIA other CBPs)

A. 1-HS-2-105A, AUX OIL PMP CNDS BSTR PMP A.

B. 1-HS-2-107A, AUX OIL PMP CNDS BSTR PMP B.

C. 1-HS-2-109A, AUX OIL PMP CNDS BSTR PMP C.

End of Section

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5.0 REFERENCES

1.0 INTRODUCTION

2.0 REFERENCES

1.0 INTRODUCTION

2.0 REFERENCES

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