ML100830112
| ML100830112 | |
| Person / Time | |
|---|---|
| Site: | Watts Bar  |
| Issue date: | 02/11/2010 |
| From: | NRC/RGN-II |
| To: | Tennessee Valley Authority |
| References | |
| 50-390/09-302 | |
| Download: ML100830112 (113) | |
Text
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Section 10 REPORT NUMBER: _---=2..;;;.,.00;;;...,;9 __ -3;;;...,;0;;..,;;;2"'---_______ _
FINAL SIMULATOR SCENARIOS CONTENTS:
J Final Simulator Scenarios
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'As given' with changes made during administration annotated Each containing ES-O-1 "Scenario Outline" Each containing ES-O-2 "Required Operator Actions" Location of Electronic Files:
Submitted By: ~rf}
FACILITY NAME: __
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Section 10 REPORT NUMBER: _--=2.:..;00:..:9:......;-3:..:0;,.:2:.....-_______ _
FINAL SIMULATOR SCENARIOS CONTENTS:
J Final Simulator Scenarios
~
'As given' with changes made during administration annotated
. Each containing ES-O-1 "Scenario Outline" Each containing ES-O-2 "Required Operator Actions" Location of Electronic Files:
Submitted By: ¥rf; Verified By: 1110-,1 iJ _ k R u>
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fAppendix 0 Scenario Outline Form ES-D-1 Facility:
Watts Bar Fall NRC Scenario No.: 1 Op Test No.:
1 Exam 2009 Examiners:
Operators:
SRO RO BOP Initial Conditions:
100% power, MOL. RCS boron is 877 ppm. Control Bank 0 is at 220 steps. Train NChannel 1 WorkWeek.
Turnover:
1A Containment Spray System (CSS) pump is out of service for bearing replacement, and is currently disassembled. LCO 3.6:6, Containment Spray System, Condition A was entered 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> ago. The 1 A CSS pump is expected to be returned to service in 16 hours1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br />. Maintain 100% power.
Current RCS boron concentration is 877 ppm. Train NChannel I Work Week.
Event Malf. No.
Event Event Description No.
Type*
1 RX24 I-BOP 1-PT-3-1, Main Feedwater Header Pressure Transmitter fails HIGH. BOP takes manual control of MFP Master Controller to restore feedwater flow to normal. Enter AOI-16, "Loss of Normal Feedwater."
2 NI07D I-RO Power Range N-44 channel fails high. RO takes manual control of rods to TS-SRO terminate the transient. Enters AOI-4 "Nuclear Instrumentation Malfunctions," or AOI-2, "Malfunction of Reactor Control System."
Requires Tech Spec evaluation.
3 RW16A C-BOP 1A ERCW supply header breaks in the Yard. Requires entry into AOI-13, TS-SRO "Loss of Essential Raw Cooling Water (ERCW)." Requires Tech Spec evaluation of ERCW system.
4 CV17B C-RO Number 1 seal on #2 RCP develops a leak, requiring entry into AOI-24, and a plant power reduction using AOI-39, "Rapid Load Reduction."
5 N/A R-RO Plant shutdown using GO-4/AOI-39, in response to the RCP seal leak.
N-BOP 6
TH03B M-ALL RCS leak which progresses to a small break LOCA, requiring entry into TH02B E-O, "Reactor Trip or Safety Injection," and subsequent transition to E-1, "Lo~s of Reactor or Secondary Coolant."
7 CS12B C-BOP 1 B CSS pump trips. Containment Air Return fans fail to auto start.
CS06G/H Requires entry into FR-Z.l on an ORANGE path condition.
8 RP02B C-BOP SI fails to auto actuate.
(N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Appendix 0 Watts Bar NRC Exam May 2009 NUREG 1021 Revision 9 f<\\ppendix D Scenario Outline Form ES-D-1 Facility:
Watts Bar Fall NRC Scenario No.: 1 Op Test No.:
1 Exam 2009 Examiners:
Operators:
SRO RO BOP Initial Conditions:
100% power, MOL. RCS boron is 877 ppm. Control Bank 0 is at 220 steps. Train NChannel 1 Work Week.
Turnover:
1A Containment Spray System (CSS) pump is out of service for bearing replacement, and is currently disassembled. LCO 3.6"6, Containment Spray System, Condition A was entered 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> ago. The 1A CSS pump is expected to be returned to service in 16 hours1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br />. Maintain 100% power.
Current RCS boron concentration is 877 ppm. Train NChannel I Work Week.
Event Malf. No.
Event Event Description No.
Type*
1 RX24 I-BOP 1-PT-3-1, Main Feedwater Header Pressure Transmitter fails HIGH. BOP takes manual control of MFP Master Controller to restore feedwater flow to normal. Enter AOI-16, "Loss of Normal Feedwater."
2 NI07D I-RO Power Range N-44 channel fails high. RO takes manual control of rods to TS-SRO terminate the transient. Enters AOI-4 "Nuclear Instrumentation Malfunctions," or AOI-2, "Malfunction of Reactor Control System."
Requires Tech Spec evaluation.
(
3 RW16A C-BOP 1A ERCW supply header breaks in the Yard. Requires entry into AOI-13, TS-SRO "Loss of Essential Raw Cooling Water (ERCW)." Requires Tech Spec evaluation of ERCW system.
4 CV17B C-RO Number 1 seal on #2 RCP develops a leak, requiring entry into AOI-24, and a plant power reduction using AOI-39, "Rapid Load Reduction."
5 N/A R-RO Plant shutdown using GO-4/AOI-39, in response to the RCP seal leak.
N-BOP 6
TH03B M-ALL RCS leak which progresses to a small break LOCA, requiring entry into TH02B E-O, "Reactor Trip or Safety Injection," and subsequent transition to E-1, "Lo~s of Reactor or Secondary Coolant."
7 CS12B C-BOP 1 B CSS pump trips. Containment Air Return fans fail to auto start.
CS06G/H Requires entry into FR-Z.1 on an ORANGE path condition.
8 RP02B C-BOP SI fails to auto actuate.
(N)ormal, (R)eactivity,
{I)nstrument, (C)omponent, (M)ajor
(
Appendix D Watts Bar NRC Exam May 2009 NUREG 1021 Revision 9
p\\ppendix D Initial Condition Turnover Event 1 Event 2 Event 3 Event 4 Event 5 Event 6 Event 7 Event 8 Critical Task 1 Critical Task 2 Critical Task 3 Appendix D Scenario Outline Form ES-D-1 Scenario 1 - Summary 100% power, MOL. RCS boron concentration is 877 ppm. Control Bank 0 is at 220 steps.
Train AlChannel 1 Work Week.
1A Containment Spray System (CSS) pump is out of service for bearing replacement, and is currently disassembled. LCO 3.6.6, Containment Spray System, Condition A was entered 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> ago. The 1A CSS pump is expected to be returned to service in 16 hours1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br />.
Maintain 100% power. Current RCS boron concentration is 877 ppm. Train AlChannel I WorkWeek.
1-PT-3-1, Main Feedwater Header Pressure Transmitter fails HIGH. Requires BOP to take manual control of MFP Master Controller to restore feedwater flow to normal. Requires entry into AOI-16, "Loss of Normal Feedwater."
Power Range N-44 channel fails HIGH. RO takes manual control of rods to terminate the transient. Enters AOI-4 "Nuclear Instrumentation Malfunctions." Requires Tech Spec evaluation.
1A ERCW supply header breaks in the Yard. Requires entry into AOI-13, "Loss of Essential Raw Cooling Water (ERCW)." Requires Tech Spec evaluation of ERCW system when cross-connected.
Number 1 seal on #2 RCP develops a leak, requiring entry into AOI-24, and a plant power reduction. RCP seal leakage worsens during the subsequent shutdown.
Plant shutdown using GO-4/AOI-39, in response to the RCP seal leak.
RCS leak develops after transition is made to ES-01, "Reactor Trip Response," requiring manual SI initiation (since auto SI is failed) and entry into E-O, "Reactor Trip or Safety Injection." RCS leak progresses to a small break LOCA, requiring entry into E-1, "Loss of Reactor or Secondary Coolant."
1 B CSS pump shaft seizes. Requires entry into FR-Z.1 on an ORANGE path condition, since NO CS pumps are running.
SI fails to auto actuate. Requires manual initiation.
Manually actuate at least one train of SIS-actuated safeguards before any of the following:
Transition to any E-1 series, E-2 series, or E-3 series procedure or transition to any FRG Completion of step 5.a of ES-O.1.
Trip all RCPs due to loss of cooling as a result of the Phase B actuation.
Manually start Containment Air Return fans to control containment pressure.
Watts Bar NRC Exam May 2009, NUREG 1021 Revision 9
[Appendix D Initial Condition Turnover Event 3
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Event 5 Event 8 Critical Task 1 Critical Task 2 Critical Task 3
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Appendix D Scenario Outline Form ES-D-1 Scenario 1 - Summary 100% power, MOL. RCS boron concentration is 877 ppm. Control Bank 0 is at 220 steps.
Train AlChannel1 Work Week.
1A Containment Spray System (CSS) pump is out of service for bearing replacement, and is currently disassembled. LCO 3.6.6, Containment Spray System, Condition A was entered 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> ago. The 1A CSS pump is expected to be returned to service in 16 hours1.851852e-4 days <br />0.00444 hours <br />2.645503e-5 weeks <br />6.088e-6 months <br />.
Maintain 100% power. Current RCS boron concentration is 877 ppm. Train AlChannel1 Work Week.
1-PT-3-1, Main Feedwater Header Pressure Transmitter fails HIGH. Requires BOP to take manual control of MFP Master Controller to restore feedwater flow to normal. Requires entry into AOI-16, "Loss of Normal Feedwater."
Power Range N-44 channel fails HIGH. RO takes manual control of rods to terminate the transient. Enters AOI-4 "Nuclear Instrumentation Malfunctions." Requires Tech Spec evaluation.
1A ERCW supply header breaks in the Yard. Requires entry into AOI-13, "Loss of Essential Raw Cooling Water (ERCW)." Requires Tech Spec evaluation of ERCW system when cross-connected.
Number 1 seal on #2 RCP develops a leak, requiring entry into AOI-24, and a plant power reduction. RCP seal leakage worsens during the subsequent shutdown.
Plant shutdown using GO-4/AOI-39, in response to the RCP seal leak.
RCS leak develops after transition is made to ES-01, "Reactor Trip Response," requiring manual SI initiation (since auto SI is failed) and entry into E-O, "Reactor Trip or Safety Injection." RCS leak progresses to a small break LOCA, requiring entry into E-1, "Loss of Reactor or Secondary Coolant."
1 B CSS pump shaft seizes. Requires entry into FR-Z.1 on an ORANGE path condition, since NO CS pumps are running.
SI fails to auto actuate. Requires manual initiation.
Manually actuate at least one train of SIS-actuated safeguards before any of the fof/owing:
Transition to any E-1 series, E-2 series, or E-3 series procedure or transition to any FRG Completion of step 5.a of ES-O.1.
Trip all RCPs due to loss of cooling as a result of the Phase B actuation.
Manually stan Containment Air Return fans to control containment pressure.
Watts Bar NRC Exam May 2009, NUREG 1021 Revision 9
Sin.
.;or Console Operators Instructions NRC Scenario 1 SIMULATOR SETUP INFORMATION
- 1.
ENSURE NRC Examination Security has been established.
- 2.
Right click on 347, and then select RESET.
- 3.
Enter the password.
- 4.
Select "Yes" on the INITIAL CONDITION RESET pop-up window.
- 5.
ENSURE the following information appears on the Director Summary Screen:
hs-72-27a-1 06020 cntmt spray pump a mtr sw R
00:00:00 00:00:00 Off Off cs06h air return fan b-b fail to start on phase b M
00:00:00 00:00:00 Active Active cs06g air return fan a-a fail to start on phase b M
00:00:00 00:00:00 Active Active hs-72-22a-1 05020 rwst spray hdr a fcv R
00:00:00 00:00:00 Off Off hs-72-39a-1 05080 cs hdr a isol vlv sw.
R 00:00:00 00:00:00 Off Off hs-72-34a-1 05060 cs pump a recirc fcv R
00:00:00 00:00:00 Off Off hs-72-44a-1 05040 cntmt sump hdr a fcv R
00:00:00 00:00:00 Off Off rp02b auto si initiation signal failure M
00:00:00 00:00:00 Active Active rx24 feed water header pressure transmitter pt-3-1 fail to position M
1 00:00:00 00:00:00 100 76.549 cs01b containment spray system pump b trip M
13 00:04:00 00:00:00 Active InActive ni07d pr channel output signal failure pr chnl 4 M
2 00:00:00 00:00:00 120 100.618 rwr05 power to appendix r valve 67-22 R
20 00:00:00 00:00:00 close open rwr03 power to appendix r valve 67-81 R
21 00:00:00 00:00:00 on off rwr12 powe'rto appendix rvalve 67-147 R
22 00:00:00 00:00:00 on off rw16a ercw supply header 1-a break in yard M
3 00:00:00 00:00:00 50 0
cv17b rcp1 seal failure rcp #2 M
4 00:00:00 00:02:30 0.115 0
th03b loca - small leak loop 2 M
5 00:00:00 00:03:00 15 0
th02b loca - cold leg loop 2 M
19 00:00:00 00:02:30 2
0 Page 1 of 4 Sin.
.or Console Operators Instructions NRC Scenario 1 SIMULATOR SETUP INFORMATION
- 1.
ENSURE NRC Examination Security has been established.
- 2.
Right click on 347, and then select RESET.
- 3.
Enter the password.
- 4.
Select "Yes" on the INITIAL CONDITION RESET pop-up window.
- 5.
ENSURE the following information appears on the Director Summary Screen:
Key Type Event Delay Inserted Ramp Initial Final Value hs-72-27a-1 06020 cntmt spray pump a mtr sw R
00:00:00 00:00:00 Off Off cs06h air return fan b-b fail to start on phase b M
00:00:00 00:00:00 Active Active cs06g air return fan a-a fail to start on phase b M
00:00:00 00:00:00 Active Active hs-72-22a-1 05020 rwst spray hdr a fcv R
00:00:00 00:00:00 Off Off hs-72-39a-1 05080 cs hdr a isol vlv sw.
R 00:00:00 00:00:00 Off Off hs-72-34a-1 05060 cs pump a recirc fcv R
00:00:00 00:00:00 Off Off hs-72-44a-1 05040 cntmt sump hdr a fcv R
00:00:00 00:00:00 Off Off rp02b auto si initiation signal failure M
00:00:00 00:00:00 Active Active rx24 feed water header pressure transmitter pt-3-1 fail to position M
1 00:00:00 00:00:00 100 76.549 cs01b containment spray system pump b trip M
13 00:04:00 00:00:00 Active InActive ni07d pr channel output signal failure pr chnl 4 M
2 00:00:00 00:00:00 120 100.618 rwr05 power to appendix r valve 67-22 R
20 00:00:00 00:00:00 close open rwr03 power to appendix r valve 67-81 R
21 00:00:00 00:00:00 on off rwr12 power to appendix r valve 67-147 R
22 00:00:00 00:00:00 on off rw16a ercw supply header 1-a break in yard M
3 00:00:00 00:00:00 50 0
cv17b rcp1 seal failure rcp #2 M
4 00:00:00 00:02:30 0.115 0
th03b loca - small leak loop 2 M
5 00:00:00 00:03:00 15 0
th02b loca - cold leg loop 2 M
19 00:00:00 00:02:30 2
0 Page 1 of 4
SirL
.40r Console Operators Instructions NRC Scenario 1 SIMULATOR SETUP INFORMATION
- 6.
Place simulator in RUN and acknowledge any alarms.
- 7.
Place 18-8 Containment Spray pump handswitch in the STOP-PULL-TO-LOCK position. Hang HOLD NOTICE cards on handswitches 1-FCV-72-27A, 1-FCV-72-39A and 1-FCV-72-44A. Place PROTECTED EQUIPMENT (Pink Tag) on 18-8 CSS handswitch.
- 8.
ENSURE the "Train A Week - Channell" sign is placed on 1-M-30.
- 9.
Place simulator in FREEZE.
Page 2 of 4 SirL~or Console Operators Instructions NRC Scenario 1 SIMULATOR SETUP INFORMATION
- 6.
Place simulator in RUN and acknowledge any alarms.
- 7.
Place 18-8 Containment Spray pump handswitch in the STOP-PULL-TO-LOCK position. Hang HOLD NOTICE cards on handswitches 1-FCV-72-27A, 1-FCV-72-39A and 1-FCV-72-44A. Place PROTECTED EQUIPMENT (Pink Tag) on 18-8 CSS handswitch.
- 8.
ENSURE the "Train A Week - Channell" sign is placed on 1-M-30.
- 9.
Place simulator in FREEZE.
Page 2 of 4
Simulator Console Operators Instructions NRC Scenario 1 EVENT INITIATION AND ROLE PLAY 1
1 1-PT-3-1, Main Feedwater Header Pressure Tran~mitter fails HIGH ROLE PLA Y: As work control, when contacted, inform the MCR that it will bean hour or more before the work package to trouble shoot and repair the failed channel is complete.
2 2
Power Range N-44 channel fails high.
ROLE PLA Y: As work control, when contacted, inform the MCR that it will be an hour or more before the work package to trouble shoot and repair the failed channel is complete.
ROLE PLA Y: As work control, when contacted to initiate performance of IMI-160, reply that the instrument shop will be notified and instructed to contact the control room before the IMI is to be performed.
3 3
' 1A ERCW supply header breaks in the Yard.
Requires entry into AOI-13, "Loss of Essenti~1 Raw Cooling Water (ERCW)."
ROLE PLA Y: As Control Building AUO, inform the BOP operator that you are standing by for breaker manipulations.
Enter EVENT 20 then modify to CLOSE to restore power to 1-FCV-67 -22.
Enter EVENT 21 then modify to ON to restore power to 1-FCV-67-81.
Enter EVENT 22 then modify to ON to restore power to 1-FCV-67-147.
ROLE PLA Y: As Outside AUO, report a large amount of water in the yard.
4 4
Number 1 seal on #2 RCP develops a leak.
ROLE PLA Y: As System Engineer, when contacted, inform the MCR that RCP #2 needs to be removed from service in the next 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />.
ROLE PLA Y: As Operations $uperintendent, concur with the System Engineer request to remove RCP #2 in the next 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />.
Page 3 of4
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Simulator Console Operators Instructions NRC Scenario 1 EVENT INITIATION AND ROLE PLAY Exam Event Simulator Event DESCRIPTION/ROLE PLAY 1
1 1-PT-3-1, Main Feedwater Header Pressure Transmitter fails HIGH ROLE PLA Y: As work control, when contacted, inform the MCR that it will be an hour or more before the work package to trouble shoot and repair the failed channel is complete.
2 2
Power Range N-44 channel fails high.
ROLE PLA Y: As work control, when contacted, inform the MCR that it will be an hour or more before the work package to trouble shoot and repair the failed channel is complete.
ROLE PLA Y: As work control, when contacted to initiate performance of IMI-160, reply that the instrument shop will be notified and instructed to contact the control room before the IMI is to be performed.
3 3
1A ERCW supply header breaks in the Yard.
Requires entry into AOI-13, "Loss of Essential Raw Cooling Water (ERCW)."
ROLE PLA Y: As Control Building AUO, inform the BOP operator that you are standing by for breaker manipulations.
Enter EVENT 20 then modify to CLOSE to restore power to 1-FCV-67-22.
Enter EVENT 21 then modify to ON to restore power to 1-FCV-67-81.
Enter EVENT 22 then modify to ON to restore power to 1-FCV-67-147.
ROLE PLA Y: As Outside AUO, report a large amount of water in the yard.
4 4
Number 1 seal on #2 RCP develops a leak.
ROLE PLA Y: As System Engineer, when contacted, inform the MCR that RCP #2 needs to be removed from service in the next 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />.
ROLE PLA Y: As Operations Superintendent, concur with the System Engineer request to remove RCP #2 in the next 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />.
Page 3 of 4
Simulator Console Operators Instructions NRC Scenario 1 EVENT INITIATION AND ROLE PLAY DESCRIPTIONIROLE PLAY 5
NONE Plant shutdown using GO-4/AOI-39, in response to the RCP seal leak.
ROLE PLA Y: None.
Number 1 seal on #2 RCP leak becomes worse, requiring a reactor trip and stopping of RCP #2.
ROLE PLA Y: None.
6 19 RCS leak which progresses to a small break LOCA, requiring entry into E-1, "Loss of Reactor or Secondary Coolant."
ROLE PLA Y: None.
7 13 1 B CSS pump trips. Requires entry into FR-Z.1 on an ORANGE path condition.
ROLE PLA Y: As Auxiliary Building AUO, when contacted, inform the MCR that the 1 B-B Containment Spray motor has signs of an electrical fault and the room smells of burnt insulation.
ROLE PLA Y: As Control Building AUO, when contacted, inform the MCR that the breaker for 1 B-B Containment Spray pump tripped on instantaneous overcurrent.
Page 4 of 4
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Simulator Console Operators Instructions NRC Scenario 1 EVENT INITIATION AND ROLE PLAY Exam Event Simulator Event DESCRIPTION/ROLE PLAY 5
NONE Plant shutdown using GO-4/AOI-39, in response to the RCP seal leak.
ROLE PLA Y: None.
Number 1 seal on #2 RCP leak becomes worse, requiring a reactor trip and stopping of RCP #2.
ROLE PLA Y: None.
6 19 RCS leak which progresses to a small break LOCA, requiring entry into E-1, "Loss of Reactor or Secondary Coolant."
ROLE PLA Y: None.
7 13 1 B CSS pump trips. Requires entry into FR-Z.1 on an ORANGE path condition.
ROLE PLA Y: As Auxiliary Building AUO, when contacted, inform the MCR that the 1 B-B Containment Spray motor has signs of an electrical fault and the room smells of burnt insulation.
ROLE PLA Y: As Control Building AUO, when contacted, inform the MCR that the breaker for 1 B-B Containment Spray pump tripped on instantaneous overcurrent.
Page 4 of 4
I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.:
NRC Scenario #
Event #
......;.._____ Page _1 _
of
-.;;.;39~-I1 Event
Description:
1-PT-3-1, Main Feedwater Header Pressure Transmitter fails HIGH. Requires BOP to take manual control of MFP Master Controller to restore feedwater flow to normal. Requires entry into AOI-16, "Loss of Normal Feedwater."
Time II Position II Applicant's Actions or Behavior Simulator Operator enters Event 1.
Indications:
63-F SG LEVEL DEVIATION ICS Point U1168, "Thermal Mismatch" 1A and 1 B MFP speed indications dropping.
1A and 1 B MFP discharge flow dropping.
ALL Main feedwater regulating valves full open.
All SG levels dropping.
C" Diagnosesand announcesfailure of 1-PT-3:'1, Main Feed Header BOP Pressure transmitter; input to Master Main Feedvvater Pump Speed Controller,1-PC-46-20. May pe. done prior to receipt of any alarm.
BOP May take actions given in ARI63-F, "SG LEVEL DEVIATION."
BOP May take manual control of Master Controller to return MFP speed to pre-event speed.
SRO Enters AOI-16, "Loss of Normal Feedwater," and directs crew actions.
EXAMINER: The following actions are from ARI-63-F, "SG LEVEL DEVIATION." The operator MAY NOT implement these steps. SRO may implement AOI-16 first.
[1] DETERMINE which S/G has abnormal level.
. [2] CHECK steam flow/feed flow instrumentation to VERIFY level controls are restoring S/Glevels to NORMAL.
[3] IF level controls have malfunctioned, THEN BOP
[a] PLACE FW controls in manual.
[b] RESTORE S/G level to normal and GO TO AOI-16, LOSS OF NORMAL FEEDWATER.
I [4]IFM.FPTspeed controls have malfunCtioned, THEN BOP
[a]PlACEMFPT speed controls.inmanual.
~" <
"~,,
[b] ~ESTORE MFW/MSL!.Pto programAND
'/>;
/",
GOTOAOF-16,. LOSS OF NORMAL FEEDWATER.
[5] INITIATE WO for corrective action, if necessary.
EXAMINER: The following actions are from AOI-16, "Loss of Normal Feedwater,'"
Subsection 3.7, "MFW Pump speed Control Circuit Failure."
..* **1.~Ii~SK>~FVyF>,..:~P~~dcol)tr?Iler(~)~t-JQRMAL..*.; *. " **. ********** **.. ;:ci *.* ~.**
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I Appendix 0 Required Operator Actions Form ES-O-2 I Op Test No.:
NRC Scenario #
Event #
Page
_1 _
of _3_9_-11 Event
Description:
1-PT-3-1, Main Feedwater Header Pressure Transmitter fails HIGH. Requires BOP to take manual control of MFP Master Controller to restore feedwater flow to normal. Requires entry into AOI-16, "Loss of Normal Feedwater."
Time II Position II Applicant's Actions or Behavior Simulator Operator enters Event 1.
Indications:
63-F SG LEVEL DEVIATION ICS Point U1168, "Thermal Mismatch" 1A and 1 B MFP speed indications dropping.
1A and 1 B MFP discharge flow dropping.
ALL Main feed water regulating valves full open.
All SG levels dropping.
Diagnoses and announces failure of 1-PT-3-1, Main Feed Header BOP Pressure transmitter, input to Master Main Feed Water Pump Speed Controller, 1-PC-46-20. May be done prior to receipt of any alarm.
BOP May take actions given in ARI63-F, "SG LEVEL DEVIATION."
BOP May take manual control of Master Controller to return MFP speed to pre-event speed.
SRO Enters AOI-16, "Loss of Normal Feedwater," and directs crew actions.
EXAMINER: The following actions are from ARI-63-F, "SG LEVEL DEVIATION." The operator MAY NOT implement these steps. SRO may implement AOI-16 first.
[1] DETERMINE which S/G has abnormal level.
[2] CHECK steam flow/feed flow instrumentation to VERIFY level controls are restoring S/G levels to NORMAL.
[3] IF level controls have malfunctioned, THEN BOP
[a] PLACE FW controls in manual.
[b] RESTORE S/G level to normal and GO TO AOI-16, LOSS OF NORMAL FEEDWA TER.
[4] IF MFPT speed controls have malfunctioned, THEN BOP
[a] PLACE MFPT speed controls in manual.
[b] RESTORE MFW/MS b.P to program AND GO TO AOI-16, LOSS OF NORMAL FEEDWATER.
[5] INITIATE WO for corrective action, if necessary.
EXAMINER: The following actions are from AOI-16, "Loss of Normal Feedwater,"
Subsection 3.7, "MFW Pump speed Control Circuit Failure."
- 1. CHECK MFWPT speed controller(s) NORMAL.
I Appendix D Op Test No.:
Event
Description:
. Required Operator Actions
. Form ES-D-2 I NRC Scenario #
Event #
1 Page _2 _
of
_3;;.;9~-I1 1-PT-3-1, Main Feedwater Header Pressure Transmitter fails HIGH. Requires BOP to take manual control of MFP Master Controller to restore feedwater flow to normal. Requires entry into AOI-16, "Loss of Normal Feedwater."
Time II Position II Applicant's Actions or Behavior
/
- 1. RESPONSE NOT OBTAINED. C()f.jTROLMFPspeed using BOP MANUAL contrpl of master controller or individual controller{s) as required.
RO 2.PLACE.confrolrods in MANUAL.
- 3. CHECK MFW pumps recirc valves NORMAL.
- 4. ENSURE T-avg and T-refwithin 3°F.
BOP 5: MAINTAIN MFWP discharge press.on PROGRAM.
- 6. ENSURE S/G levels return toPROGRAM.
- 7. CHECK steam dump mode in T-AVG position.
- 8. INITIATE repairs to failed equipment.
- 9. IF desired to place control rods in AUTO, THEN ENSURE T-avg and T -ref within 1°F and PLACE control rods in auto.
With 1-PT-3-1, Main Feed Header Pressure failed; MFP speed control must remain in MANUAL.
- 11. RETURN TO Instruction in effect.
SRO Crew Brief would typically be conducted for this event as time 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 Maintenance Shift Supervisor (MSS). (Note: Maintenance notification may be delegated to the Shift Manager)..
Simulator operator enters Event 2
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I Appendix 0 Op Test No.:
Event
Description:
Required Operator Actions Form ES-O-2 I NRC Scenario #
Event #
______ Page
_2 _
of _3,;..;9;"-"-11 1-PT-3-1, Main Feedwater Header Pressure Transmitter fails HIGH. Requires BOP to take manual control of MFP Master Controller to restore feedwater flow to normal. Requires entry into AOI-16, "Loss of Normal Feedwater."
Time II Position II Applicant's Actions or Behavior
- 1. RESPONSE NOT OBTAINED. CONTROL MFP speed using BOP MANUAL control of master controller or individual controller(s) as required.
- 2. PLACE control rods in MANUAL.
- 3. CHECK MFW pumps recirc valves NORMAL.
- 4. ENSURE T-avg and T-ref within 3°F.
- 5. MAINTAIN MFWP discharge press on PROGRAM.
- 6. ENSURE S/G levels return to PROGRAM.
- 7. CHECK steam dump mode in T-AVG position.
- 8. INITIATE repairs to failed equipment.
- 9. IF desired to place control rods in AUTO, THEN ENSURE T-avg and T-ref within 1°F and PLACE control rods in auto.
With 1-PT-3-1, Main Feed Header Pressure failed, MFP speed control must remain in MANUAL SRO
- 11. RETURN TO Instruction in effect.
SRO Crew Brief would typically be conducted for this event as time 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 Maintenance Shift Supervisor (MSS). (Note: Maintenance notification may be delegated to the Shift Manager).
Simulator operator enters Event 2
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I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.:
NRC Scenario #
Event #
_2~ ____ Page _3 _
of _3.;...9'---11 Event
Description:
Power Range N44 fails high, requiring entry into AOI-4, "Nuclear Instrumentation Malfunctions."
Time II Position II Applicant's Actions or Behavior Indications:
1-M-4B 83-A, POWER RANGE OVERPOWER ROD WD STOP 1-M-4B 83-E, POWER RANGE CHANNEL DEVIATION 1-M-6A 115-C, POWER RANGE FLUX HI 1-M-6A 115-E, POWER RANGE FLUX RATE HI Rods inserting at 72 steps/minute with no corresponding drop in megawatt load.
RO Diagnoses and announces failure of Power Range Channel N44.
Enter and direct actions of AOI-4, "Nuclear Instrumentation SRO Malfunctions," Section 3.4, "Power Range Monitor (PRM) Failure" and directs crew actions.
EXAMINER: The following actions are from AOI-4, "Nuclear Instrumentation Malfunctions," Section 3.4, "Power Range Monitor (PRM) Failure."
- 1. PLACE control rods in MANUAL.
- 2. CHECK rod motion STOPPED.
CAUTION N41 controls S/G 1 and S/G 4 MFW reg valves.
N42 controls S/G 2 and S/G 3 MFW reg valves.
NOTE All four bypass reg valves are controlled by auctioneered high nuclear power as an anticipatory input.
- 3. CHECK N41 and N42 NORMAL.
NOTE Control rod withdrawal may not be possible if a PRM has failed high due to the 103%
Rod Withdrawl Stop (C-2).
SRO/RO
- 4. MAINTAIN T-avg and T-refwithin 3°F.
- 5. ENSURE 1-NR-92-145 recording operable power range channel.
NOTE Inputs to 1-TR-68-2A include power range monitor, pressurizer pressure,.6. T and Tavg.
Selection of an operable channel should consider other failures ih addition to the failed power range monitor channel.
- 6. ENSURE 1-TR-68-2A placed to operable.6.T/OT.6.T/OP.6.T channel using 1-XS-68-2B,.6. T RCDR TR-68-2A LOOP SELECT [1-M-5].
- 7. DEFEAT affected PRM functions:
RO REFER TO Attachment 1, PRM Function At NIS Rack.
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\\
I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.:
NRC Scenario #
Event #
2 Page
_3 _
of
_3;;.;9~-I1 Event
Description:
Power Range N44 fails high, requiring entry into AOI-4, "Nuclear Instrumentation Malfunctions."
Time Position II Applicant's Actions or Behavior Indications:
1-M-4B 83-A, POWER RANGE OVERPOWER ROD WD STOP 1-M-4B 83-E, POWER RANGE CHANNEL DEVIATION 1-M-6A 11S-C, POWER RANGE FLUX HI 1-M-6A 11S-E, POWER RANGE FLUX RATE HI Rods inserting at 72 steps/minute with no corresponding drop in megawatt load.
RO Diagnoses and announces failure of Power Range Channel N44.
Enter and direct actions of AOI-4, "Nuclear Instrumentation SRO Malfunctions," Section 3.4, "Power Range Monitor (PRM) Failure" and directs crew actions.
EXAMINER: The following actions are from AOI-4, "Nuclear Instrumentation Malfunctions," Section 3.4, "Power Range Monitor (PRM) Failure."
- 1. PLACE control rods in MANUAL.
- 2. CHECK rod motion STOPPED.
CAUTION N41 controls SIG 1 and SIG 4 MFW reg valves.
N42 controls SIG 2 and SIG 3 MFW reg valves.
NOTE All four bypass reg valves are controlled by auctioneered high nuclear power as an anticipatory input.
- 3. CHECK N41 and N42 NORMAL.
NOTE Control rod withdrawal may not be possible if a PRM has failed high due to the 103%
Rod Withdrawl Stop (C-2).
SRO/RO
- 4. MAINTAIN T-avg and T-ref within 3°F.
- 5. ENSURE 1-NR-92-145 recording operable power range channel.
NOTE Inputs to 1-TR-68-2A include power range monitor, pressurizer pressure,,1T and Tavg.
Selection of an operable channel should consider other failures in addition to the failed power range monitor channel.
- 6. ENSURE 1-TR-68-2A placed to operable,1T/OT,1T/OP,1T channel using 1-XS-68-2B,,1 T RCDR TR-68-2A LOOP SELECT [1-M-S].
- 7. DEFEAT affected PRM functions:
RO REFER TO Attachment 1, PRM Function At NIS Rack.
I Appendix 0 Required Operator Actions Form ES-O-2 I Op Test No.:
NRC Scenario #
Event #
....;2=--. ____ Page
_4 _
of
_3;;,.;9~-I1 Event
Description:
Power Range N44 fails high, requiring entry into AOI-4, "Nuclear Instrumentation Malfunctions."
Time II Position II Applicant's Actions or Behavior EXAMINER: The following steps are from AOI-4, Attachment 1, "PRM Function at NIS Rack."
NOTE The following annunciators may be affected by defeating a PRM channel:
[66-C, 67-C, 68:-C, 69-C] N-(#) OVERPOWER ROD STOP BYPASSED.
[82-E] NIS CHANNEL IN TEST.
[83-A] POWER RANGE OVERPOWER ROD WD STOP.
[83-E] POWER RANGE CHANNEL DEVIATION.
[115-C] POWER RANGE FLUX HI.
[115-E] POWER RANGE FLUX RATE HI.
- 1. PERFORM the following steps for the affected PRM:
- a. PLACE DETECTOR CURRENT COMPARATOR switch for UPPER SECTION to failed channel.. (N44)
- b. PLACE DETECTOR CURRENT COMPARATOR switch for LOWER SECTION to failed channel. (N44).'
NOTE On the following step, annunciator window 83-A, POWER RANGE OVERPOWER ROD WD STOP will clear (if channel failure was high) and window 66-C, 67-C, 68-C OR 69-C, N-(#)
OVERPOWER ROD STOP BYPASSED, will come into alarm depending on which channel is bypassed.
- c. PLACE ROD STOP BYPASS switch to failed channel. (N44)
- d. PLACE POWER MISMATCH BYPASS switch to failed channel.
(N44)
NOTE On the following step, annunciator window 83-E, POWER RANGE CHANNEL DEVIATION, will clear and annunciator window 82-E, NIS CHANNEL IN TEST, will come into alarm.
- e. PLACE COMPARATOR CHANNEL DEFEATswitchto failed channel. (N44)
NOTE On the following step, annunciator window 115-E, POWER RANGE FLUX RATE HI, will clear if the positive rate trip light is LIT.
RO f.IF POSITIVE RATE TRIP is LIT, THEN RESET RATE MODE switch.
EXAMINER: The crew must return to AOI-4, Section 3.4, Step 8 to complete required actions. The following continues with Step 8.
CAUTION Allowing at least 5 minutes between any rod control input (i.e., T -avg, T -ref, or NIS) change and placing rods in AUTO, will help prevent undesired control rod movement.
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I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.:
NRC Scenario #
Event #
_2 _____ Page
_4 _
of _3.;...9'---11 Event
Description:
Power Range N44 fails high, requiring entry into AOI-4, "Nuclear Instrumentation Malfunctions."
Time II Position Applicant's Actions or Behavior EXAMINER: The following steps are from AOI-4, Attachment 1, "PRM Function at NIS Rack."
NOTE The following annunciators may be affected by defeating a PRM channel:
[66-C, 67-C, 68-C, 69-C] N-(#) OVERPOWER ROD STOP BYPASSED.
[82-E] NIS CHANNEL IN TEST.
[83-A] POWER RANGE OVERPOWER ROD WD STOP.
[83-E] POWER RANGE CHANNEL DEVIATION.
[115-C] POWER RANGE FLUX HI.
[115-E] POWER RANGE FLUX RATE HI.
- 1. PERFORM the following steps for the affected PRM:
- a. PLACE DETECTOR CURRENT COMPARATOR switch for UPPER SECTION to failed channel. (N44)
- b. PLACE DETECTOR CURRENT COMPARATOR switch for LOWER SECTION to failed channel. (N44)
NOTE On the following step, annunciator window 83-A, POWER RANGE OVERPOWER ROD WD STOP will clear (if channel failure was high) and window 66-C, 67-C, 68-C OR 69-C, N-(#)
OVERPOWER ROD STOP BYPASSED, will come into alarm depending on which channel is bypassed.
- c. PLACE ROD STOP BYPASS switch to failed channel. (N44)
- d. PLACE POWER MISMATCH BYPASS switch to failed channel.
(N44)
NOTE On the following step, annunciator window 83-E, POWER RANGE CHANNEL DEVIATION, will clear and annunciator window 82-E, NIS CHANNEL IN TEST, will come into alarm.
- e. PLACE COMPARATOR CHANNEL DEFEAT switch to failed channel. (N44)
NOTE On the following step, annunciator window 115-E, POWER RANGE FLUX RATE HI, will clear if the positive rate trip light is LIT.
- f. IF POSITIVE RATE TRIP is LIT, THEN RESET RATE MODE switch.
EXAMINER: The crew must return to AOI-4, Section 3.4, Step 8 to complete required actions. The following continues with Step 8.
CAUTION Allowing at least 5 minutes between any rod control input (i.e., T-avg, T-ref, or NIS) change and placing rods in AUTO, will help prevent undesired control rod movement.
I Appendix D Op Test No.:
Event
Description:
Required Operator Actions Form ES-D-2 I NRC Scenario #
Event #
....;;;.2 _____ Page
_5 _
of
_3.;;.;9~-I1 Power Range N44 fails high, requiring entry into AOI-4, "Nuclear Instrumentation Malfunctions."
Time II Position II Applicant's Actions or Behavior
- 8. WHEN failed PRM defeated AND AUTO rod control desired, THEN:
- a. ENSURE T-avg and T-refwithin 1°.
- b. ENSURE zero demand on control rod position indication [1-M-4].
- c. PLACE control rods in AUTO.
- 9. INITIATE repairs on failed channel.
- 10. NOTIFY Work Control to have 1M trip failed channel bistables.
CAUTION Power fuses should not be removed during the performance of IMI-160 until affected S/G level controlsare in manual at either the SG LEVEL - NIS BIAS controller(s) or the MFW reg valve controllers.
- 11. WHEN notified bistables are tripped, CHECK lights and alarms referenced in Appendix A are LIT.
- 12. REFER TO Tech Specs:
3.3.1-1, "Rx Trip System (RTS)"
2.a. Power Range Neutron Flux - High Condition D. One Power Range Neutron Flux-High channel inoperable. Place channel in trip within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> AND Reduce THERMAL POWER to S 75% RTP within 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br />; OR Place channel in trip within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> AND Perform SR 3.2.4.2 every 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> OR be in Mode 3 within 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br />.
2.b. Power Range Neutron Flux - Low Condition E. With one channel inoperable, place the channel in trip within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> OR be in Mode 3 in 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br />.
3.a. Power Range Neutron Flux Rate - High Positive Rate SRO Condition E. With one channel inoperable, place the channel in trip within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> OR be in Mode 3 in 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br />.
- 6. Overtemperature AT Condition. W. Place channel in trip within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> OR be in Mode 3 within 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br />.
EXAMINER: P-7 not necessary due to cascading from P-10.
16.c. Power Range Neutron Flux, P-8 Condition S. With ONE channel inoperable, verify the interlock is in required state for existing unit conditions within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> OR be in Mode 2 within 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br />.
16.d. Power Range Neutron Flux, P-9 Condition S. With ONE channel inoperable, verify the interlock is in required state for existing unit conditions within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> OR
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I Appendix 0 Op Test No.:
Event
Description:
Required Operator Actions Form ES-O-2 I NRC Scenario #
Event #
_2 _____ Page _5 _
of _3.;...9'--...,1 Power Range N44 fails high, requiring entry into AOI-4, "Nuclear Instrumentation Malfunctions."
Time II Position II Applicant's Actions or Behavior
- 8. WHEN failed PRM defeated AND AUTO rod control desired, THEN:
- a. ENSURE T-avg and T-ref within 1°.
- b. ENSURE zero demand on control rod position indication [1-M-4].
- c. PLACE control rods in AUTO.
- 9. INITIATE repairs on failed channel.
- 10. NOTIFY Work Control to have 1M trip failed channel bistables.
CAUTION Power fuses should not be removed during the performance of IMI-160 until affected S/G level controls are in manual at either the SG LEVEL - NIS BIAS controller{s) or the MFW reg valve controllers.
- 11. WHEN notified bistables are tripped, CHECK lights and alarms referenced in Appendix A are LIT.
- 12. REFER TO Tech Specs:
3.3.1-1, "Rx Trip System (RTS)"
2.a. Power Range Neutron Flux - High Condition D. One Power Range Neutron Flux-High channel inoperable. Place channel in trip within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> AND Reduce THERMAL POWER to ::; 75% RTP within 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br />; OR Place channel in trip within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> AND Perform SR 3.2.4.2 every 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> OR be in Mode 3 within 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br />.
2.b. Power Range Neutron Flux - Low Condition E. With one channel inoperable, place the channel in trip within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> OR be in Mode 3 in 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br />.
3.a. Power Range Neutron Flux Rate - High Positive Rate SRO Condition E. With one channel inoperable, place the channel in trip within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> OR be in Mode 3 in 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br />.
- 6. Overtemperature L1T Condition W. Place channel in trip within 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> OR be in Mode 3 within 78 hours9.027778e-4 days <br />0.0217 hours <br />1.289683e-4 weeks <br />2.9679e-5 months <br />.
EXAMINER: P-7 not necessary due to cascading from P-10.
16.c. Power Range Neutron Flux, P-8 Condition S. With ONE channel inoperable, verify the interlock is in required state for existing unit conditions within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> OR be in Mode 2 within 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br />.
16.d. Power Range Neutron Flux, P-9 Condition S. With ONE channel inoperable, verify the interlock is in required state for existing unit conditions within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> OR
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.1 Appendix D Required Operator Actions Form ES-D-2 I Op Test No.:
NRC Scenario #
Event #
....;2=--____ Page
_6 _
of
_3;;...;9~-I1 Event
Description:
Power Range N44 fails high, requiring entry into AOI-4, Nuclear Instrumentation Malfunctions."
Time II Position II Applicant's Actions or Behavior be in Mode 2 within 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br />.
16.e. Power Range Neutron Flux, P-10 Condition R. With ONE channel inoperable, verify the interlock is in required state for existing unit conditions within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> OR be in Mode 3 within 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br />.
- 13. NOTIFY Operations Duty Manager and Rx Engineering of failed channel.
- 14. DO NOT CONTINUE with this Instruction UNTIL failed PRM repair is completed.
CREW Crew Brief would typically be conducted for this event as time allows prior to the next event.
Notifications should be addressed as applicable if not specifically addressed by the procedure or in the crew brief.
CREW Operations Management - Shift Manager.
Maintenance Personnel -Maintenance Shift Supervisor (MSS).
(Note: Maintenance notification may be delegated to the Shift Manager).
Simulator operator enters Event 3
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I Appendix 0 Required Operator Actions Form ES-O-2 I Op Test No.:
NRC Scenario #
Event #
2 Page
_6 __ of
_3.;..;9~-I1 Event
Description:
Power Range N44 fails high, requiring entry into AOI-4, Nuclear Instrumentation Malfunctions."
Time Position Applicant's Actions or Behavior be in Mode 2 within 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br />.
16.e. Power Range Neutron Flux, P-10 Condition R. With ONE channel inoperable, verify the interlock is in required state for existing unit conditions within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> OR be in Mode 3 within 7 hours8.101852e-5 days <br />0.00194 hours <br />1.157407e-5 weeks <br />2.6635e-6 months <br />.
- 13. NOTIFY Operations Duty Manager and Rx Engineering of failed channel.
- 14. DO NOT CONTINUE with this Instruction UNTIL failed PRM repair is completed.
CREW Crew Brief would typically be conducted for this event as time allows prior to the next event.
Notifications should be addressed as applicable if not specifically addressed by the procedure or in the crew brief.
CREW Operations Management - Shift Manager.
Maintenance Personnel -Maintenance Shift Supervisor (MSS).
(Note: Maintenance notification may be delegated to the Shift Manager).
Simulator operator enters Event 3
I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.:
NRC Scenario #
Event #
_3.;...... ____ Page
_7 _
of
_3.;.;9~-I1 Event
Description:
1A ERCW supply header breaks in the Yard. Requires entry into AOI-13, "Loss of Essential Raw Cooling Water (ERCW)." Requires Tech Spec evaluation of ERCW system when cross-connected.
Time Position Applicant's Actions or Behavior Indications:
223-A ERCW HDR A SUP PRESS LO 223-B ERCW PMP A-A DISCH PRESS LO 226-B ERCW PMP D-A DISCH PRESS LO 223-C ERCW HDR 1A STRAINER ~P HI 225-E-TR-AIB ERCW TO C&SS COMPR FLOW HI O-PI-67':18A, A ERCW SUP HDR PRESS indicating approximately 50 psig.
1-FI-67-61, 1A ERCW SUP HDR FLOW indicating approximately 500 gpm.
BOP Diagnose and announce failure to the crew. May dispatch operators to determine the location of the leak.
SRO Enters AOI-13, "Loss of Essential Raw Cooling Water," and directs actions.
EXAMINER: The following actions are from AOI-13, "Loss of Essential Raw Cooling Water (ERCW)," Sub section 3.4, "Supply Header Rupture in Yard or Plugged Strainer."
- 1. CHECK supply header pressure high with any strainer DP alarm LIT.
- 1. RESPONSE NOT OBTAINED: GO TO Step 3.
- 3. CHECK hdr press 10 alarm, DARK:
BOP ERCW HDR A SUP PRESS LO [223-A]
ERCW HDR B SUP PRESS LO [229-A]
- 3. RESPONSE NOT OBTAINED: START additional pumps as BOP required, AND DISPATCH personnel to determine location of rupture.
NOTE 1 D All supply headers may return normal if supply header pressure was initially high with strainer backwash being successful in reducing supply header pressure and restoring affected supply header flow.
NOTE 2 D Both Train A Supply Headers may indicate below normal pressure, visual verification may be required.
NOTE 3 D MOVs with power normally removed may not travel tofull closed position under high flow conditions; local verification of isolation may be required.
- 5. CHECK.Supply Header 1A~()wat expected value for exisfin9.
. plantcQnditi()n~.
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I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.:
NRC Scenario #
Event #
....;;..3 _____ Page
_7 _
of
....;;..39~-I1 Event
Description:
1A ERCW supply header breaks in the Yard. Requires entry into AOI-Time Indications:
13, "Loss of Essential Raw Cooling Water (ERCW)." Requires Tech Spec evaluation of ERCW system when cross-connected.
Position II Applicant's Actions or Behavior 223-A ERCW HDR A SUP PRESS LO 223-B ERCW PMP A-A DISCH PRESS LO 226-B ERCW PMP D-A DISCH PRESS LO 223-C ERCW HDR 1A STRAINER i1.P HI 225-E-TR-A/B ERCW TO C&SS COMPR FLOW HI O-PI-67.:18A, A ERCW SUP HDR PRESS indicating approximately 50 psig.
1-FI-67-61, 1A ERCW SUP HDR FLOW indicating approximately 500 gpm.
BOP Diagnose and announce failure to the crew. May dispatch operators to determine the location of the leak.
SRO Enters AOI-13, "Loss of Essential Raw Cooling Water," and directs actions.
EXAMINER: The following actions are from AOI-13, "Loss of Essential Raw Cooling Water (ERCW)," Sub section 3.4, "Supply Header Rupture in Yard or Plugged Strainer."
- 1. CHECK supply header pressure high with any strainer DP alarm LIT.
- 1. RESPONSE NOT OBTAINED: GO TO Step 3.
- 3. CHECK hdr press 10 alarm, DARK:
BOP ERCW HDR A SUP PRESS LO [223-A]
ERCW HDR B SUP PRESS LO [229-A]
- 3. RESPONSE NOT OBTAINED: START additional pumps as BOP required, AND DISPATCH personnel to determine location of rupture.
NOTE 1 D All supply headers may return normal if supply header pressure was initially high with strainer backwash being successful in reducing supply header pressure and restoring affected supply header flow.
NOTE 2 D Both Train A Supply Headers may indicate below normal pressure, visual verification may be required.
NOTE 3 D MOVs with power normally removed may not travel to full closed position under high flow conditions; local verification of isolation may be required.
Appendix D Op Test No.:
Event
Description:
Required Operator Actions Form ES-D-2 NRC Scenario #
Event #
......;;.3 _____ Page
_8 _
of......;;.39;"""-11 1A ERCW supply heaqer breaks in the Yard. Requires entry into AOI-13, "Loss of Essential Raw Cooling Water (ERCW)." Requires Tech Spec evaluation of ERCW system when cross-connected.
Time Position II Applicant's Actions or Behavior
- 5. RESPONSE NOT OBTAINED: PERFORM the following:
- a. UNLOCK, and CLOSE,bkron RxMOV Bd'1A2-A, c17B,,1:7 FCV-67-22.
0'
- d. ENSURE 2-FCV-67-147, CCS Hx C Sup From Hdr 2B, OPEN,
- e. OPEN1-FCV-67-147. CCS Hx C Sup From Hdr 1A.
- f. CLOSE 1-FCV-67-22, Strainer 1AA Inlet.
- g. CLOSE 1-FCV-67-81, AB Supply Hdr 1A.
- h. GO TO Step 9.
HEADER LOST DGs AFFECTED BACKUP VALVE POSITION BOP 1A 1 A-A 1-FCV-67-68 OPEN 2A-A 2-FCV-67-68 OPEN 1B 1B-8 1-FCV-67-65 OPEN 28-8 2-FCV-67-65 OPEN SRO
- 10. CHECK in-service ERCW header pressures and flows return to expected values for existing plant conditions.
- 11. CHECK pump amps NORMAL.
- 12. REFER TO Tech Specs:
3.7.8, Essential Raw Cooling Water System (ERCW).
SRO Action A, and determines that the break location does not cause diesel generators to be INOPERABLE.
Since the ERCW headers are cross-tied, entry into LCO 3.0.3 is required.
- 13. INITIATE repair.
- 14. IF E;RCW to in-service CCS heat exchanger was interrupted, SRO THEN NOTIFY Duty System Engineer to initiate evaluation for effect on CCS equipment and piping.
- 15. R'EFER TO SOI-67.01, Essential Raw Cooling Water System, for system realignment.
- 16. RETURN TO Instruction in effect.
I Appendix 0
\\
Op Test No.:
Event
Description:
Required Operator Actions Form ES-O-2 I NRC Scenario #
Event #
3 Page _8 _
of _3_9_-11 1A ERCW supply header breaks in the Yard. Requires entry into AOI-13, "Loss of Essential Raw Cooling Water (ERCW)." Requires Tech Spec evaluation of ERCW system when cross-connected.
Time II Position II Applicant's Actions or Behavior
- 5. RESPONSE NOT OBTAINED: PERFORM the following:
- d. ENSURE 2-FCV-67-147, CCS Hx C Sup From Hdr 2B, OPEN.
- e. OPEN 1-FCV-67-147, CCS Hx C Sup From Hdr 1A.
- f. CLOSE 1-FCV-67-22, Strainer 1 A-A Inlet.
- g. CLOSE 1-FCV-67-81, AB Supply Hdr 1A.
- h. GO TO Step 9.
HEADER LOST DGs AFFECTED BACKUP VALVE POSITION BOP 1A 1A-A 1-FCV-67-68 OPEN 2A-A 2-FCV-67-68 OPEN 1B 18-8 1-FCV-67-65 OPEN 28-8 2-FCV-67-65 OPEN SRO
- 10. CHECK in-service ERCW header pressures and flows return to expected values for existing plant conditions.
- 11. CHECK pump amps NORMAL.
- 12. REFER TO Tech Specs:
3.7.8, Essential Raw Cooling Water System (ERCW).
SRO Action A, and determines that the break location does not cause diesel generators to be INOPERABLE.
Since the ERCW headers are cross-tied, entry into LCO 3.0.3 is required.
- 13. INITIATE repair.
14.IF E;RCW to in-service CCS heat exchanger was interrupted, SRO THEN NOTIFY Duty System Engineer to initiate evaluation for effect on CCS equipment and piping.
- 15. REFER TO SOI-67.01, Essential Raw Cooling Water System, for system realignment.
- 16. RETURN TO Instruction in effect.
I Appendix D Op Test No.:
Event
Description:
Required Operator Actions Form ES-D-2 I NRC Scenario #
Event #
_3~ ____ Page
_9 _
of.......;.;39;""-'-11 1A ERCW supply header breaks in the Yard. Requires entry into AOI-13, "Loss of Essential Raw Cooling Water (ERCW)." Requires Tech Spec evaluation of ERCW system when cross-connected.
Time II Position II Applicant's Actions or Behavior SRO Crew Brief would typically be conduced for this event as time 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 Maintenance Shift Supervisor (MSS). (Note: Maintenance notification may be delegated to the Shift Manager),
Simulator operator enters Event 4
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I Appendix D Op Test No.:
Event
Description:
Required Operator Actions Form ES-D-2 I NRC Scenario #
Event #
3 Page _9__ of _3;;.,;9;""'--11 1A ERCW supply header breaks in the Yard. Requires entry into AOI-13, "Loss of Essential Raw Cooling Water (ERCW)." Requires Tech Spec evaluation of ERCW system when cross-connected.
Time II Position II Applicant's Actions or Behavior SRO Crew Brief would typically be conduced for this event as time 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 Maintenance Shift Supervisor (MSS). (Note: Maintenance notification may be delegated to the Shift Manager),
Simulator operator enters Event 4
I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.:
NRC Scenario #
Event #
_4,,;,:'..;;5~___ Page.!.2....- of _3;;;.;9~-I1 Event
Description:
Number 1 seal on #2 Rep develops a leak, requiring entry into AOI-24, and AOI-39, "Rapid Load Reduction."
II Time II Position II Applicant's Actions or Behavior Indications:
100-0 RCP SEAL LEAKOFF FLOW HI 1-FR-62-24 SEAL LEAKOFF - HI RANGE Green pen indicates a rising trend.
RO Diagnoses and announce§ the problem with RCP 2 #1 Seal Leakoff flow.
SRO Enters and directs actions contained in AOI-24, "RCP Malfunctions During Pump Operation."
EXAMINER: The following steps are from AOI-24, "RCP Malfunctions During Pump Operation," Section 3.3.
CAUTION A seal leakoff rise to greater than 2.0 gpm AFTER experiencing low leakoff of less than 0.8 gpm may indicate seal degradation. Plant Management should be notified of leakoff trends.
NOTE 1 Anytime #1 seal leakoff flow exceeds the values shown on Attachment 1, system engineering should be requested to perform an evaluation of the #1 seal condition.
NOTE 2 During plant startup after seal maintenance, the #1 seal may require 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> of run time before the seal seats fully and operates normally.
NOTE 3 The #1 seal return should be isolated between 3 and 5 minutes after tripping an RCP to allow for pump coastdown.
RO 1.MONITOR #1 sealleakoff equal to or greater than 6.0 gpm.
- 2. MONITORRCPs lower bearing and #1 seal outlet temp STABLE or DROPPING.
- 3. REFER TO appropriate instruction to initiate a controlled shutdown to Mode 3 while continuing with this instruction:
- AOI-39, Rapid Load Reduction.
- GO-4, Normal Power Operation.
- GO-5, Unit Shutdown From 30% Reactor Power to Hot Standby.
NOTE RCP shutdown time is based on an orderly reactor shutdown and may be delayed or
,expedited based on ongoing evaluations of current plant conditions, other pump parameters and efforts to restore seal leakoff flows to normal.
- 4. REMOVE RCP from service:
Within 8 hrs, OR As directed by Plant Management.
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I Appendix 0 Required Operator Actions Form ES-O-2 I Op Test No.:
NRC Scenario #
Event #
_4..:..l'...;;5~ ___ Page.:!.2...- of _3_9_-11 Event
Description:
Number 1 seal on #2 Rep develops a leak, requiring entry into AOI-24, and AOI-39, "Rapid Load Reduction."
Time II Position II Applicant's Actions or Behavior Indications:
100-D Rep SEAL LEAKOFF FLOW HI 1-FR-62-24 SEAL LEAKOFF - HI RANGE Green pen indicates a rising trend.
RO Diagnoses and announces the problem with Rep 2 #1 Seal Leakoff flow.
SRO Enters and directs actions contained in AOI-24, "Rep Malfunctions During Pump Operation."
EXAMINER: The following steps are from AOI-24, "RCP Malfunctions During Pump Operation," Section 3.3.
CAUTION A seal leakoff rise to greater than 2.0 gpm AFTER experiencing low leakoff of less than 0.8 gpm may indicate seal degradation. Plant Management should be notified of leakoff trends.
NOTE 1 Anytime #1 sealleakoff flow exceeds the values shown on Attachment 1, system engineering should be requested to perform an evaluation of the #1 seal condition.
NOTE 2 During plant startup after seal maintenance, the #1 seal may require 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> of run time before the seal seats fully and operates normally.
NOTE 3 The #1 seal return should be isolated between 3 and 5 minutes after tripping an Rep to allow for pump coastdown.
- 1. MONITOR #1 sealleakoff equal to or greater than 6.0 gpm.
- 2. MONITOR Reps lower bearing and #1 seal outlet temp STABLE or DROPPING.
- 3. REFER TO appropriate instruction to initiate a controlled shutdown to Mode 3 while continuing with this instruction:
- AOI-39, Rapid Load Reduction.
- GO-4, Normal Power Operation.
- GO-5, Unit Shutdown From 30% Reactor Power to Hot Standby.
NOTE Rep shutdown time is based on an orderly reactor shutdown and may be delayed or
,expedited based on ongoing evaluations of current plant conditions, other pump parameters and efforts to restore seal leakoff flows to normal.
- 4. REMOVE Rep from service:
Within 8 hrs, OR As directed by Plant Management.
I Appendix D Op Test No.:
Event
Description:
Required Operator Actions Form ES-D-2 I NRC Scenario #
Event #
_4-'"',...;5____ Page.:!...1.- of _3.-9'---11 Number 1 seal on #2 RCP develops a leak, requiring entry into AOI-24, and AOI-39, "Rapid Load Reduction."
Time II Position II Applicant's Actions or Behavior
- 5. MONITOR RCP immediate shutdown required:
RO REFER TO ATTACHMENT 2, RCP Immediate Shutdown Criteria.
- GO TO Subsection 3.2, Step 2.
- 5. RESPONSE NOT OBTAINED** GO TO Step 6.
- 6. ADJUST seal injection flow to exceed total #1 seal leakoff rate.
- 7. CONTACT System Engineer for further guidance WHILE continuing this Instruction:
SRO Recommendations for continued RCP operation.
Installation of alternate flow measuring equipment (flows greater than 6 gpm).
- 8. CHECK seal injection flow between 8 and 13 gpm/RCP.
- 9. CONTROL VCT outlet temp less than 123°F:
RO ADJUST 1-HS-62-78A ADJUST charging and letdown flow to reduce regen heat-exchanger outlet temp.
- 10. CHECK VCT pressure between 15 and 30 psig.
- 11. MONITOR RCP lower bearing and #1 seal outlet temp:
RO Less than or equal to 180°F.
STABLE or DROPPING.
- 12. INITIATE repairs as required.
- 13. RETURN TO Instruction in effect.
EXAMINER: The following actions are from AOI-39, "Rapid Load Reduction," Section 3.2.
CAUTION Condenser Backpressure limits are on previous page.
CAUTION TURBINE MANUAL Operation requires continuous operator monitoring and control.
CAUTION LOSS OF CONDENSER VACUUM may be made worse if steam dumps are actuated. AOI-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.
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I Appendix 0 Op Test No.:
Event
Description:
Required Operator Actions Form ES-O-2 I NRC Scenario #
Event #
_4..;,i,~5;......___ Page _11_ of _3;;..;9;"""-11 Number 1 seal on #2 RCP develops a leak, requiring entry into AOI-24, and AOI-39, "Rapid Load Reduction."
Time II Position II Applicant's Actions or Behavior
- 5. MONITOR RCP immediate shutdown required:
RO REFER TO ATTACHMENT 2, RCP Immediate Shutdown Criteria.
- GO TO Subsection 3.2, Step 2.
- 5. RESPONSE NOT OBTAINED** GO TO Step 6.
- 6. ADJUST seal injection flow to exceed total #1 sealleakoff rate.
- 7. CONTACT System Engineer for further guidance WHILE continuing this Instruction:
SRO Recommendations for continued RCP operation.
Installation of alternate flow measuring equipment (flows greater than 6 gpm).
- 8. CHECK seal injection flow between 8 and 13 gpm/RCP.
- 9. CONTROL VCT outlet temp less than 123°F:
RO ADJUST 1-HS-62-78A ADJUST charging and letdown flow to reduce regen heat-exchanger outlet temp.
- 10. CHECK VCT pressure between 15 and 30 psig.
- 11. MONITOR RCP lower bearing and #1 seal outlet temp:
RO Less than or equal to 180°F.
STABLE or DROPPING.
- 12. INITIATE repairs as required.
- 13. RETURN TO Instruction in effect.
EXAMINER: The following actions are from AOI-39, "Rapid Load Reduction," Section 3.2.
CAUTION Condenser Backpressure limits are on previous page.
CAUTION TURBINE MANUAL Operation requires continuous operator monitoring and control.
CAUTION LOSS OF CONDENSER VACUUM may be made worse if steam dumps are actuated. AOI-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.
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I Appendix D Op Test No.:
Event
Description:
Required Operator Actions Form ES-D-2 I NRC Scenario #
Event #
_4,,;,:'...,;;5~ ___ Page ~
of _3_9_-11 Number 1 seal on #2 RCP develops a leak, requiring entry into AOI-24, and AOI-39, "Rapid Load Reduction."
Time II Position II Applicant's Actions or Behavior
- 1. ESTABLISH a turbine load reduction rateiess than orequal to 5%/min:
- a.
SET a desired load in the SETTER with the REFERENCE BOP CONTROL
- b.
SET the LOAD RATE at less. than or equal to 5%/min.
- c.
DEPRESS. GO pushbutton.
CAUTION Over boration may result in excessive rod withdrawal or Tavg lower than desired for at power conditions.
NOTE 1 Rod Control should remain in automatic for Tavg Control.
NOTE 2 The following Table assumes - 1/3 reactivity by rod insertion during the load reduction.
The RCS boron concentration may be adjusted should ~I or RILs criteria be approached.
- 2. INITIATE a manualboration:
- a. DETERMINE recommended boration flowrate and volume from table below.
~
TURBINE LOAD BORATION BORIC ACID VOLUME REDUCTION RATE FLOWRATE TO REDUCE POWER
(%/min)
(gal/min)
FROM 100% TO 20%
2%
20GPM 3%
30GPM
-800 GALs
- ,4%
40GPM TOTAL RO
- b. INITIATE boration to maintain control rods above low-low' insertion limit:*
- 1) ADJUST BA flow controller,1-FC-62-139, to desired flow rate.
- 2) ADJUST BA batch counter 1-FQ-62-139 to required quantity.
- 3) PLACE mode selector 1-HS-62-140B to BOR.
- 4) PLACE VCT makeup controI1-HS-62-140A,to START.
- 5) VERIFY desired boric acid flow indicated on 1-FI-62-139.
- 3. REFER TO EPIP-1, Emergency Plan Classification Flowchart.
- 4. NOTIFY the Load Coordinator of the required load reduction and expected ramp rate.
EXAMINER: After sufficient load reduction is accomplished, cue Simulator Operator to insert Event 5. Conditions will degrade and warrant initiation of a reactor trip and entry into E-O, "Reactor Trip or Safety Injection." When the crew trips the reactor, an RCS leak develops, requiring a safety injection.
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I Appendix 0 Op Test No.:
Event
Description:
Required Operator Actions Form ES-O-2 I NRC Scenario #
Event #
......;.;4,:..;5~ ___ Page ~
of
....;.;39~-I1 Number 1 seal on #2 RCP develops a leak, requiring entry into AOI-24, and AOI-39, "Rapid Load Reduction."
Time Position Applicant's Actions or Behavior
- 1. ESTABLISH a turbine load reduction rate less than or equal to 5%/min:
- a.
SET a desired load in the SETTER with the REFERENCE BOP CONTROL.
- b.
SET the LOAD RATE at less than or equal to 5%/min.
- c.
DEPRESS GO pushbutton.
CAUTION Over boration may result in excessive rod withdrawal or Tavg lower than desired for at power conditions.
NOTE 1 Rod Control should remain in automatic for Tavg Control.
NOTE 2 The following Table assumes - 1/3 reactivity by rod insertion during the load reduction.
The RCS boron concentration may be adjusted should ill or RILs criteria be approached.
- 2. INITIATE a manual boration:
- a. DETERMINE recommended boration flowrate and volume from table below.
TURBINE LOAD BORATION BORIC ACID VOLUME REDUCTION RATE FLOWRATE TO REDUCE POWER
(%/min)
(gal/min)
FROM 100% TO 20%
2%
20 GPM 3%
30 GPM
- 800 GALs
- 4%
40 GPM TOTAL RO
- b. INITIATE boration to maintain control rods above low-low*
insertion limit:
- 1) ADJUST BA flow controller, 1-FC-62-139, to desired flow rate.
- 2) ADJUST BA batch counter 1-FQ-62-139 to required quantity.
- 3) PLACE mode selector 1-HS-62-140B to BOR.
- 4) PLACE VCT makeup controI1-HS-62-140A, to START.
- 5) VERIFY desired boric acid flow indicated on 1-FI-62-139.
- 3. REFER TO EPIP-1, Emergency Plan Classification Flowchart.
- 4. NOTIFY the Load Coordinator of the required load reduction and expected ramp rate.
EXAMINER: After sufficient load reduction is accomplished, cue Simulator Operator to insert Event 5. Conditions will degrade and warrant initiation of a reactor trip and entry into E-O, "Reactor Trip or Safety Injection." When the crew trips the reactor, an RCS leak develops, requiring a safety injection.
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I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.:
NRC Scenario #
Event #
_6..;..... ____ Page.1l...- of
_3..;;.;9~-I1 Event
Description:
During load reduction, an RCS leak develops requiring the crew to evaluate plant conditions, initiate a manual reactor trip and safety injection. Entry into E-O will be followed by entry into E-1, "Loss of Reactor or Secondary Coolant."
Time II Position II Applicant's Actions or Behavior RO Diagnoses and annou,)cesthe conditions havew()rsened....
144-A, "ICE COND INLET DOOR OPEN," alarms.
SRO Enters and directs the actions of AOI-6, "SmaU Reactor Coolant System Leak."
EXAMINER: The following actions are from AOI-S.
NOTE During performance of this instruction the need for a rapid load reduction or Unit trip should be continuously evaluated RO
- 1. CHECK pzr level DROPPING. ** GO TO Step 4.
- 4. IF RHR Shutdown Cooling mode in service, THEN GO TO AOI-14, Loss of RHR Shutdown Cooling.
- 5. MAKE plant announcement via PA:
SRO "Attention plant personnel. A primary system leak has developed.
Any personnel located either inside containment or in the Auxiliary Building should exit the area immediately." (Repeat)
- 6. MONITOR pzr level STABLE or RISING.
RNO:
SRO IF loss of pzr level is IMMINENT, RISING. THEN:
- a. TRIP Rx.
- b. INITIATE SI.
- c. ** GO TO E-O, Rx Trip or Safety Injection.
SRO Directs a manual reactor trip based on PZR level response.
SRO Directs a manual safety injection based on change,in containment conditions after the reactor trip..
EXAMINER: The following actions are from E-O, "Reactor Trip or Safety Injection."
- 1. ENSURE reactor trip:
- 2. ENSURE Turbine Trip:
- 3. CHECK 6.9 kV shutdown boards:
CRITICAL RO
- 4. CHECK SI actuated: Notes SI did NOT auto actuate, and TASK manually actuates 51 (if not previously manually initiated).
- 5. EVALUATE support systems:
- REFERTO Appendixes A and B (E-O), Equipment Verification pages 15-28~
EXAMINER: Appendixes A and B are at the back of this Scenario Guide.
- 6. ANNOUNCE reactor trip and safety injection over PA system.
RO 7.ENSUREsecondary heat sink available with either:
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I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.:
NRC Scenario #
Event #
6 Page ~
of _3;;.,;9;"""-11 Event
Description:
During load reduction, an RCS leak develops requiring the crew to evaluate plant conditions, initiate a manual reactor trip and safety injection. Entry into E-O will be followed by entry into E-1, "Loss of Reactor or Secondary Coolant."
Time II Position II Applicant's Actions or Behavior RO Diagnoses and announces the conditions have worsened.
144-A, "ICE COND INLET DOOR OPEN," alarms.
SRO Enters and directs the actions of AOI-6, "Small Reactor Coolant System Leak."
EXAMINER: The following actions are from AOI-6.
NOTE During performance of this instruction the need for a rapid load reduction or Unit trip should be continuously evaluated RO
- 1. CHECK pzr level DROPPING. ** GO TO Step 4.
- 4. IF RHR Shutdown Cooling mode in service, THEN GO TO AOI-14, Loss of RHR Shutdown Cooling.
- 5. MAKE plant announcement via PA:
SRO "Attention plant personnel. A primary system leak has developed.
Any personnel located either inside containment or in the Auxiliary Building should exit the area immediately." (Repeat)
- 6. MONITOR pzr level STABLE or RISING.
RNO:
SRO IF loss of pzr level is IMMINENT, RISING. THEN:
- a. TRIP Rx.
- b. INITIATE SI.
- c. ** GO TO E-O, Rx Trip or Safety Injection.
SRO Directs a manual reactor trip based on PZR level response.
SRO Directs a manual safety injection based on change in containment conditions after the reactor trip.
EXAMINER: The following actions are from E-O, "Reactor Trip or Safety Injection."
- 1. ENSURE reactor trip:
- 2. ENSURE Turbine Trip:
- 3. CHECK 6.9 kV shutdown boards:
CRITICAL RO
- 4. CHECK SI actuated: Notes SI did NOT auto actuate, and TASK manually actuates SI (if not previously manually initiated).
- 5. EVALUATE support systems:
- REFER TO Appendixes A and B (E-O), Equipment Verification pages 15-28.
EXAMINER: Appendixes A and B are at the back of this Scenario Guide.
- 6. ANNOUNCE reactor trip and safety injection over PA system.
- 7. ENSURE secondary heat sink available with either:
I Appendix D Op Test No.:
Event
Description:
Required Operator Actions Form ES-D-2 I NRC Scenario #
Event #
_6""""-____ Page.1.!...- of _3_9 __
11 During load reduction, an RCS leak develops requiring the crew to evaluate plant conditions, initiate a manual reactor trip and safety injection. Entry into E-O will be followed by entry into E-1" "Loss of Reactor or Secondary Coolant."
Time II Position II Applicant's Actions or Behavior
- At least one SIG NR level greater than 29% [39% ADV].
- 8. MONITOR RCS temp stable at or trending to 55rF:
- 9. ENSURE excess letdown valves CLOSED:
RO 1-FCV-62-54 1-FCV-62-55
- 10. CHECK pzr PORVs and block valves:
- a. Pzr PORVs CLOSED.
- b. At least one block valve OPEN.
- 11. CHECK pzr safety valves CLOSED:
EVALUATE tailpipe temperatures and acoustic monitors.
- 12. CHECK pzr sprays CLOSED.
NOTE Seal injection flow should be maintained to all RCPs.
CRITICAL
- 13. CHECK if RCPs should remain in service:
TASK RO
- a. Phase B signals DARK [MISSP].*.
- b. RCS pressure greater than 1500 psig.
- 14. CHECK SIG pressures:
RO All S/G pressures controlled or rising.
All S/G pressures greater than 120 psig.
- 15. CHECK for RUPTURED S/G All SIGs narrow range levels CONTROLLED or RO DROPPING.
Secondary side radiation NORMAL from Appendix A.
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I Appendix D Op Test No.:
Event
Description:
Required Operator Actions Form ES-D-2 I NRC Scenario #
Event #
6 Page ~
of
_3.;;...;9~-I1 During load reduction, an RCS leak develops requiring the crew to evaluate plant conditions, initiate a manual reactor trip and safety injection. Entry into E-O will be followed by entry into E-1, "Loss of Reactor or Secondary Coolant."
Time II Position II Applicant's Actions or Behavior
- At least one S/G NR level greater than 29% [39% ADV].
- 8. MONITOR RCS temp stable at or trending to 55rF:
- 9. ENSURE excess letdown valves CLOSED:
RO 1-FCV-62-54 1-FCV-62-55
- 10. CHECK pzr PORVs and block valves:
- a. Pzr PORVs CLOSED.
- b. At least one block valve OPEN.
- 11. CHECK pzr safety valves CLOSED:
EVALUATE tailpipe temperatures and acoustic monitors.
- 12. CHECK pzr sprays CLOSED.
NOTE Seal injection flow should be maintained to all RCPs.
CRITICAL
- 13. CHECK if RCPs should remain in service:
TASK RO
- a. Phase B signals DARK [MISSP].
- b. RCS pressure greater than 1500 psig.
- 14. CHECK S/G pressures:
RO All S/G pressures controlled or rising.
All S/G pressures greater than 120 psig.
- 15. CHECK for RUPTURED S/G All S/Gs narrow range levels CONTROLLED or RO DROPPING.
Secondary side radiation NORMAL from Appendix A.
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I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.:
NRC Scenario #
Event #
6 Page..!.2....- of
......;;..;39~-I1 Event
Description:
During load reduction, an RCS leak deVf:llops requiring the crew to evaluate plant conditions, initiate a manual reactor trip and safety injection. Entry into E-O will be followed by entry into E-1, "Loss of Reactor or Secondary Coolant."
Time II Position Applicant's Actions or Behavior
- 16. CHECK cntmt conditions:
Cntmt pressure NORMAL.
BOP Radiation NORMAL from Appendix A.
Cntmt sump level NORMAL.
Cntmt temp ann window DARK [104-B].
- 16. RESPONSE NOT OBTAINED: ** GO TO E-1, Loss of Reactor or Secondary Coolant.
EXAMINER: 1 B Containment Spray pump will trip, resulting in an ORANGE path condition on Containment Status Tree. The SRO will implement FR-Z.1 "High Containment Pressure," based on plant conditions.
EXAMINER: The following actions are from FR-Z.1 "High Containment Pressure."
CAUTION If ECA-1.1, Loss of RHR Sump Recirculation, is in effect, the number of cntmt spray pumps to be operated is directed in ECA-1.1 rather than in this instruction.
NOTE Adverse containment setpoints [ADV] should be used where provided due to Phase B actuation.
- 1. ENSURE cntmt spray operation:
- a. Cntmt spray signal ACTUATED.
- b. Cntmt spray pumps RUNNING.
- c. Cntmt spray valves 1-FCV-72-2 and 1-FCV-72-39 OPEN.
- d. Cntmt spray pump suction valves OPEN:
Valves from RWST:
- 1) 1-FCV-72-21 and RO
- 2) 1-FCV-72-22.
OR Valves from cntmt sump:
- 1) 1-FCV-72-44 and
- 2) 1-FCV-72-45.
- e. Cntmt spray flow:
- 1-FI-72-34.
- 1-FI-72-13.
- 1. RESPONSE NOT OBTAINED: ESTABLISH at least one train of SRO cntmt spray flow.
Since there are NO containment spray pumps available at this
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I Appendix 0 Required Operator Actions Form ES-O-2 I Op Test No.:
NRC Scenario #
Event #
_6..;;.....-____ Page ~
of _3.;;.,;9;"""-11 Event
Description:
During load reduction, an RCS leak develops requiring the crew to evaluate plant conditions, initiate a manual reactor trip and safety injection. Entry into E-O will be followed by entry into E-1, "Loss of Reactor or Secondary Coolant."
Time II Position II Applicant's Actions or Behavior
- 16. CHECK cntmt conditions:
Cntmt pressure NORMAL.
BOP Radiation NORMAL from Appendix A.
Cntmt sump level NORMAL.
Cntmt temp ann window DARK [104-B].
- 16. RESPONSE NOT OBTAINED: ** GO TO E-1, Loss of Reactor or Secondary Coolant.
EXAMINER: 1 B Containment Spray pump will trip, resulting in an ORANGE path condition on Containment Status Tree. The SRO will implement FR-Z.1 "High Containment Pressure," based on plant conditions.
EXAMINER: The following actions are from FR-Z.1 "High Containment Pressure."
CAUTION If ECA-1.1, Loss of RHR Sump Recirculation, is in effect, the number of cntmt spray pumps to be operated is directed in ECA-1.1 rather than in this instruction.
NOTE Adverse containment setpoints [ADV] should be used where provided due to Phase B actuation.
- 1. ENSURE cntmt spray operation:
- a. Cntmt spray signal ACTUATED.
- b. Cntmt spray pumps RUNNING.
- c. Cntmt spray valves 1-FCV-72-2 and 1-FCV-72-39 OPEN.
- d. Cntmt spray pump suction valves OPEN:
Valves from RWST:
- 1) 1-FCV-72-21 and RO
- 2) 1-FCV-72-22.
OR Valves from cntmt sump:
- 1) 1-FCV-72-44 and
- 2) 1-FCV-72-45.
- e. Cntmt spray flow:
°1-FI-72-34.
° 1-FI-72-13.
- 1. RESPONSE NOT OBTAINED: ESTABLISH at least one train of SRO cntmt spray flow.
Since there are NO containment spray pumps available at this
(
I Appendix D Op Test No.:
Event
Description:
Required Operator Actions Form ES-D-2 I NRC Scenario #
Event #
~7':..;8 _____ Page.!2..- of.....;.;39 __ ~1 1 B CS pump shaft seizes. Requires entry into FR-Z.1 on an ORANGE path condition, since NO CS pumps are running. Containment Air Return fans fail to auto start. SI fails to auto actuate.
Time II Position II Applicant's Actions or Behavior time the SRO will continue procedure performance.
- 2. ENSURE cntmt isolation:
- a. Phase A isolation:
Train A GREEN.
Train B GREEN.
- b. Cntmt vent isolation:
RO Train A GREEN.
Train B GREEN.
- c. Phase B isolation:
Train A GREEN.
Train B GREEN.
- 3. ENSURE MSIVs and bypasses CLOSED.
- 4. PLACE steam dump controls OFF:
BOP 1-HS-1-103A, STEAM DUMP FSV "A" 1-HS-1-:103B, STEAM DUMP FSV"B."
- 5. ENSURE all four RCPs STOPPED.
- 6. MONITOR EGTS operation:
- a. EGTS fans RUNNING.
- b. Filter bank dp between 5 and 9 inches of water.
- 7. ENSURE ABGTS operation:
- a. ABGTS fans RUNNING.
FCO-30-146A BOP FCO-30-146B.
FCO-30-157A FCO-30-157B.
(
I
~.
I Appendix 0 Op Test No.:
Event
Description:
Required Operator Actions Form ES-O-2 I NRC Scenario #
Event #
7,8 Page ~
of _3;;..;9~~1 1 B CS pump shaft seizes. Requires entry into FR-Z.1 on an ORANGE path condition, since NO CS pumps are running. Containment Air Return fans fail to auto start. SI fails to auto actuate.
Time II Position II Applicant's Actions or Behavior time the SRO will continue procedure performance.
- 2. ENSURE cntmt isolation:
- a. Phase A isolation:
Train A GREEN.
Train B GREEN.
- b. Cntmt vent isolation:
RO Train A GREEN.
Train B GREEN.
- c. Phase B isolation:
Train A GREEN.
Train B GREEN.
- 3. ENSURE MSIVs and bypasses CLOSED.
- 4. PLACE steam dump controls OFF:
BOP 1-HS-1-103A, STEAM DUMP FSV "A."
1-HS-1-103B, STEAM DUMP FSV "B."
- 5. ENSURE all four RCPs STOPPED.
- 6. MONITOR EGTS operation:
- a. EGTS fans RUNNING.
- b. Filter bank dp between 5 and 9 inches of water.
- 7. ENSURE ABGTS operation:
- a. ABGTS fans RUNNING.
FCO-30-146A.
BOP FCO-30-146B.
FCO-30-157 A.
FCO-30-157B.
(
I Appendix D Op Test No.:
Event
Description:
Required Operator Actions Form ES-D-2 I NRC Scenario #
Event #
~7':...;;8~ ___ Page..!l.- of ~39~-I1 1 B CS pump shaft seizes. Requires entry into FR-Z.1 on an ORANGE path condition, since NO CS pumps are running. Containment Air Return fans fail to auto start. SI fails to auto actuate.
Time II Position II Applicant's Actions or Behavior CRITICAL
- 8. WHEN 10 minutes has elapsed since Phase B actuation, THEN TASK BOP ENSURE cntmt air return fans start, as directed by E-O, Appendix B, or FR-Z.1. (Note: Fans did NOT auto start, but were previously started manually.)
CAUTION RCS cooldown requires the availability of at least one S/G.
If ALL SIGs are Faulted, at least a minimum detectable feed flow to each SIG is required to limit thermal stress during subsequent SIG feed operations.
- 9. CHECK S/G pressures:
BOP All S/G pressures controlled or rising.
All S/G pressures greater than 120 psig.
- 10. DETERMINE if RHR spray should be placed in service:
a.CHECK the following conditions:
At least one hour has elapsed since the beginning of the RO accident.
Cntmt pressure is greater than 9.5 psig.
RHR suction is aligned to cntmt sump.
At least one charging pump and one SI pump running.
10.a. RESPONSE NOT OBTAINED: a. WHEN all conditions met, SRO THEN PERFORM Sub step 10b.
- GO TO Step 11.
- 11. RETURN TO Instruction in effect.
EXAMINER: SRO will return to 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].
- b. RCS pressure greater than 1500 psig.
- 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 S/G pressures:
BOP All S/G pressures controlled or rising.
All S/Gs pressures greater than 1-20 psig.
(
I Appendix D Op Test No.:
Event
Description:
Required Operator Actions Form ES-D-2 I NRC Scenario #
Event #
7,8 Page.1.Z.- of _3_9_-11 1 B CS pump shaft seizes. Requires entry into FR-Z.1 on an ORANGE path condition, since NO CS pumps are running. Containment Air Return fans fail to auto start. SI fails to auto actuate.
Time II Position II Applicant's Actions or Behavior CRITICAL
- 8. WHEN 10 minutes has elapsed since Phase B actuation, THEN TASK BOP ENSURE cntmt air return fans start, as directed by E-O, Appendix B, or FR-Z.1. (Note: Fans did NOT auto start, but were previously started manually.)
CAUTION RCS cooldown requires the availability of at least one S/G.
If ALL SIGs are Faulted, at least a minimum detectable feed flow to each SIG is required to limit thermal stress during subsequent SIG feed operations.
- 9. CHECK S/G pressures:
BOP All S/G pressures controlled or rising.
All S/G pressures greater than 120 psig.
- 10. DETERMINE if RHR spray should be placed in service:
- a. CHECK the following conditions:
At least one hour has elapsed since the beginning of the RO accident.
Cntmt pressure is greater than 9.5 psig.
RHR suction is aligned to cntmt sump.
At least one charging pump and one SI pump running.
10.a. RESPONSE NOT OBTAINED: a. WHEN all conditions met, SRO THEN PERFORM Sub step 10b.
- GO TO Step 11.
- 11. RETURN TO Instruction in effect.
EXAMINER: SRO will return to 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].
- b. RCS pressure greater than 1500 psig.
- 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 S/G pressures:
BOP All S/G pressures controlled or rising.
All S/Gs pressures greater than 120 psig.
I Appendix 0 Op Test No.:
Event
Description:
Required Operator Actions Form ES-O-2 I NRC Scenario #
Event #
.....;..:7,~8~ ___ Page.1L of _3.;...;9~-!1 1 B CS pump shaft seizes. Requires entry into FR-Z.1 on an ORANGE path condition, since NO CS pumps are running. Containment Air Return fans fail to auto start. SI fails to auto actuate.
Time II Position II Applicant's Actions or Behavior BOP S. MAINTAIN Intact S/G NR levels:
- a. MONITOR levels greater than 29% [39% ADV].
- b. CONTROL intact S/G levels between 29% and SO% [39% and SO%ADV).
- 6. CHECK secondary radiation:
S/G discharge monitors NORMAL.
BOP Condenser vacuum exhaust rad monitors NORMAL.
BOP RO RO S/G blowdown rad monitor recorders NORMAL trend prior to isolation.
- 7. ENSURE cntmt hydrogen analyzers in service:
PLACE 1-HS-43-200A in ANALYZE [M-10).
PLACE 1-HS*A3-210A in ANALYZE [M-10).
CHECK low flow lights not lit [M-10].
Locally CHECK low analyzer temp lights NOT lit [North wall of Train A 480V SO Bd rm).
- 8. MONITOR pzr PORVs and block valves:
- a. Pzr PORVs CLOSED.
- b. At least one block valve OPEN.
- 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 1-FCV-72-39.
- 10. ENSURE both pocket sumppumps STOPPED [M-1S):
BOP 1-HS-77-410.
1-HS-77-411.
(
(
I Appendix 0 Op Test No.:
Event
Description:
Required Operator Actions Form ES-O-2 I NRC Scenario #
Event #
~7':....;8;.....-___ Page.:!L of
~39;""'--I1 1 B CS pump shaft seizes. Requires entry into FR-Z.1 on an ORANGE path condition, since NO CS pumps are running. Containment Air Return fans fail to auto start. SI fails to auto actuate.
Time II Position II Applicant's Actions or Behavior
- 5. MAINTAIN Intact S/G NR levels:
- a. MONITOR levels greater than 29% [39% ADV].
- b. CONTROL intact S/G levels between 29% and 50% [39% and 50% ADV].
- 6. CHECK secondary radiation:
S/G discharge monitors NORMAL.
BOP Condenser vacuum exhaust rad monitors NORMAL.
S/G blowdown rad monitor recorders NORMAL trend prior to isolation.
- 7. ENSURE cntmt hydrogen analyzers in service:
PLACE 1-HS-43-200A in ANAL YZE [M-10].
BOP PLACE 1-HS-43-21 OA in ANALYZE [M-10].
CHECK low flow lights not lit [M-10].
Locally CHECK low analyzer temp lights NOT lit [North wall of Train A 480V SD Bd rm].
- 8. MONITOR pzr PORVs and block valves:
- a. Pzr PORVs CLOSED.
- b. At least one block valve OPEN.
- 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 1-FCV-72-39.
- 10. ENSURE both pocket sump pumps STOPPED [M-15]:
BOP 1-HS-77-410.
1-HS-77-411.
I Appendix D Required Operator Actions
. Form ES-D-2 I Op Test No.:
NRC Scenario #
Event #
~7':..;;8~ ___ Page ~
of _3;;.;9~-I1 Event
Description:
1 B CS pump shaft seizes. Requires entry into FR-Z.1 on an ORANGE path condition, since NO CS pumps are running. Containment Air Return fans fail to auto start. SI fails to auto actuate.
Time II Position II Applicant's Actions or Behavior
- 11. CHECK SI termination criteria:
- a. CHECK RCS subcooling greater than 65°F [85°F ADV].
SRO 11.a. RESPONSE NOT OBTAINED: a. ** GO TO Caution prior to Step 12.
CAUTION If offsite power is lost after 51 reset, manual action will be required to restart the 51 pumps and RHR pumps due to loss of 51 start signal.
- 12. RESET SI and CHECK the following:
RO SI ACTUATED permissive DARK.
~UTO SI BLOCKED permissiveLiT.
- 13. DETERMINE if RHR pumps should be stopped:
- a. CHECK RCS pressure greater than 150 'psig.
. c. CHECK RCS pressure stable or rising.
- d. STOP RHR pumps and PLACE in A-AUTO.
- e. MONITOR RCS pressure greater than 150 psig.
- 14. CHECK pressure in all S/Gs controlled or rising.
- 15. CHECK RCS pressure stable or dropping.
- 16. MONITOR electrical board status:
- a. CHECK offsite power available.
- b. CHECK all shutdown boards ENERGIZED by offsite power.
- c. PLACE any unloaded DIG in standby USING SOI-82 Diesel Generators.
- 17. INITIATE BOP realignment:
BOP REFER TO AOI-17, Turbine Trip.
(Note: See detailed steps at the back of this Scenario Guide.)
(
(
I Appendix D Op Test No.:
Event
Description:
Required Operator Actions Form ES-D-2 I NRC Scenario #
Event #
7,'-'8 ____ Page ~
of _39'---11 1 B CS pump shaft seizes. Requires entry into FR-Z.1 on an ORANGE path condition, since NO CS pumps are running. Containment Air Return fans fail to auto start. SI fails to auto actuate.
Time II Position II Applicant's Actions or Behavior
- 11. CHECK SI termination criteria:
- a. CHECK RCS subcooling greater than 65°F [85°F ADV].
SRO 11.a. RESPONSE NOT OBTAINED: a. ** GO TO Caution prior to Step 12.
CAUTION If offsite power is lost after 51 reset, manual action will be required to restart the 51 pumps and RHR pumps due to loss of 51 start signal.
- 12. RESET SI and CHECK the following:
RO SI ACTUATED permissive DARK.
AUTO SI BLOCKED permissive LIT.
- 13. DETERMINE if RHR pumps should be stopped:
- a. CHECK RCS pressure greater than 150 psig.
- c. CHECK RCS pressure stable or rising.
- d. STOP RHR pumps and PLACE in A-AUTO.
- e. MONITOR RCS pressure greater than 150 psig.
- 14. CHECK pressure in all S/Gs controlled or rising.
- 15. CHECK RCS pressure stable or dropping.
- 16. MONITOR electrical board status:
- a. CHECK offsite power available.
- b. CHECK all shutdown boards ENERGIZED by offsite power.
- c. PLACE any unloaded DIG in standby USING SOI-82 Diesel Generators.
- 17. INITIATE BOP realignment:
BOP REFER TO AOI-17, Turbine Trip.
(Note: See detailed steps at the back of this Scenario Guide.)
(
I Appendix D Op Test No.:
Event
Description:
Required Operator Actions Form ES-D-2 I NRC Scenario #
Event #
_7;;..:,...;8 ____ Page ~
of _3;.;9~-I1 1 B CS pump shaft seizes. Requires entry into FR-Z.1 on an ORANGE path condition, since NO CS pumps are running. Containment Air Retum fans fail to auto start. SI fails to auto actuate.
Time II Position II Applicant's Actions or Behavior
- 18. INITIATE 480V board room breaker alignments USING the following:
Appendix A (E-1), CLA Breaker Operation.
Appendix B (E-1), Ice Condenser AHU Breaker Operation.
BOP Appendix C (E-1), 1-FCV-63-1 Breaker Operation.
Appendix D (E-1), 1-FCV-63-22 Breaker Operation.
(NOTE: Detailed steps at the back of this Scenario Guide.)
- 19. DETERMINE if hydrogen igniters should be energized:
- a. CHECK hydrogen analyzers in service.
- b. CHECK cntmt hydrogen less than 5% [M-10].
- c. ENERGIZE hydrogen igniters [M-10]:
1-HS-268-73 ON.
1-HS-268-74 ON.
SRO Power to at least one operable RHR pumpAVAILABLE.
Cntmt sump valve 1-FCV-63-72 or 1-FCV-63-73 to operable RHR pump AVAILABLE.
- 21. EVALUATE plant equipment status:
REFER TO Appendix E (E-1), Equipment Evaluation.
- 22. CHECK Aux Bldg radiation for loss of RCS inventory outside cntmt:
- a. Area monitor recorders 1-RR-90-1 and 0-RR-90-12A Aux Bldg points NORMAL.
- b. Vent monitor recorder 0-RR-90-101 NORMAL trend prior to
.isolation.
- 23. NOTIFY Chemistry of event status and plant conditions.
- 24. DETERMINE if RCS cooldovitn and depressurization is required:
- a. CHECK ReS pressure greater than 150 psig.
(
(
I Appendix D Op Test No.:
Event
Description:
Required Operator Actions Form ES-D-2 I NRC Scenario #
Event #
.....;..;7,.....;8~ ___ Page ~
of
_3.;..;9~-I1 1 B CS pump shaft seizes. Requires entry into FR-Z.1 on an ORANGE path condition, since NO CS pumps are running. Containment Air Return fans fail to auto start. SI fails to auto actuate.
Time II Position II Applicant's Actions or Behavior
- 18. INITIATE 480V board room breaker alignments USING the following:
Appendix A (E-1), CLA Breaker Operation.
Appendix B (E-1), Ice Condenser AHU Breaker Operation.
BOP Appendix C (E-1), 1-FCV-63-1 Breaker Operation.
Appendix D (E-1), 1-FCV-63-22 Breaker Operation.
(NOTE: Detailed steps at the back of this Scenario Guide.)
- 19. DETERMINE if hydrogen igniters should be energized:
- a. CHECK hydrogen analyzers in service.
- b. CHECK cntmt hydrogen less than 5% [M-10].
- c. ENERGIZE hydrogen igniters [M-10]:
1-HS-268-73 ON.
1-HS-268-74 ON.
SRO Power to at least one operable RHR pumpAVAILABLE.
Cntmt sump valve 1-FCV-63-72 or 1-FCV-63-73 to operable RHR pump AVAILABLE.
- 21. EVALUATE plant equipment status:
REFER TO Appendix E (E-1), Equipment Evaluation.
- 22. CHECK Aux Bldg radiation for loss of RCS inventory outside cntmt:
- a. Area monitor recorders 1-RR-90-1 and 0-RR-90-12A Aux Bldg points NORMAL.
- b. Vent monitor recorder 0-RR-90-1 01 NORMAL trend prior to isolation.
- 23. NOTIFY Chemistry of event status and plant conditions.
- 24. DETERMINE if RCS cooldown and depressurization is required:
- a. CHECK RCS pressure greater than 150 psig.
(
I Appendix D Op Test No.:
Event
Description:
Required Operator Actions Form ES-D-2 I NRC Scenario #
Event #
~7':..;8;...... ___ Page ~
of
_3;...;9;......~1 1 B CS pump shaft seizes. Requires entry into FR-Z.1 on an ORANGE path condition, since NO CS pumps are running. Containment Air Return fans fail to auto start. SI fails to auto actuate.
Time II Position II Applicant's Actions or Behavior I
I
EXAMINER: When the decision is made to transition to ES-1.2, "Post LOCA Cooldown and Depressurization," inform the applicants that "Another crew will continue from here" and cue the Simulator Operator to stop simulation.
I I
.. END OF S~EN~RIO.
(
(
I Appendix 0 Op Test No.:
Event
Description:
Required Operator Actions Form ES-O-2 I NRC Scenario #
Event #
7,8 Page ~
of _3;:;.;9;;"""--11 1 B CS pump shaft seizes. Requires entry into FR-Z.1 on an ORANGE path condition, since NO CS pumps are running. Containment Air Return fans fail to auto start. SI fails to auto actuate.
Time II Position II Applicant's Actions or Behavior I
I
EXAMINER: When the decision is made to transition to ES-1.2, "Post LOCA Cooldown and Depressurization," inform the applicants that "Another crew will continue from here" and cue the Simulator Operator to stop simulation.
I I
END OF SCENARIO
WBN REACTOR TRIP OR SAFETY INJECTION E-O Rev 28 I Step II Action/Expected Response II Response Not.obtained APPENDIX A (E-O)
Page 1 of (I EQUIPM ENT VERIFICATION 2
ENSURE PCBs OPEN:
PCB 5084.
PCB 5088.
ENSURE AFW pump operation:
TD AFW pump RUNNING.
leVs in AUT.o, or controlled in MANUAL.
- 3.
ENSURE MFW isolation:
+
MFW isolation and bypass isolation valves CLOSED.
+
MFW reg and bypass reg valves CLOSED.
+
MFP A and B TRIPPED.
+
Standby MFP STOPPED.
+
Cond demin pumps TRIPPED.
+
Cond booster pumps TRIPPED.
14 0(28 OPEN manually.
ESTABLISH at least one train AFWoperation.
Manually CLOSE valves and STOP pumps, as necessary.
IF any valves can NOT be closed, THEN CLOSE #1 heater outlet valves.
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WBN REACTOR TRIP OR SAFETY INJECTION E-O Re"i 28 I Step II Action/Expec.ted Response II Response Not Obtained A.PPEr\\lDIX A.
(E-O)
Page 1 of 0 EQUIPMENT VERIFICATION 2
ENSURE PCBs OPEN:
PCB 50,s4.
PCB 5088.
ENSURE A.FW pump operation:
TD.AF'*h* pump RUNNING.
LC\\lS in AUTO. or controlled in MA.NUAL.
- 3.
ENSURE !... 1FV'/ ;solation:
MFW isol3tion and bypass isolation valves CLOSED.
M FIN reg and bypass reg valves CLOSED.
~*t1FP./4, and B TRIPPED.
Standby r... 1FP STOPPED.
Cond dernin pumps TRIPPED.
Cond booster pumps TRIPPED.
14 of 28 OPEN manuaJ.I.)'.
ESTABLISH at least one train A.FVIJ' operation.
Manually CLOSE val*... es and STOP pumps, as necessar.{.
IF any val*iss can NOT be closed, THEN CLOSE #1 heater outlet valves.
waN REACTOR TRIP OR SAFETY INJECTION E-O Rev 28 I Step II ActionJExpeded Response II Response Not Obtained
- 4.
APPENDIX A (E-O)
Page 2 of 10 EQUfPME.NT VERIFICATION MONITOR ECCS operation:
<31. Charging pumps RUNNING.
- b. Charging pump alignment RWST outlets 1-LCV-62-135 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.
- d. SI pumps RUNNING.
- e. BIT alignment Outlets 1-FCV-63-25 and 1-FCV-63-26 OPEN.
Flow thru BIT.
- f.
ReS pressure greater than 1650 psig.
15 of 28
- a. Manually START charg;ing pumps.
- b. ENSURE at least one valve in each set aligned.
- c. Manually START RHR pumps.
- d. Manually START SI pumps.
- e. ENSURE at least one valve aligned, and flow thru BIT.
t ENSURE SI pump flow.
IFRCS press drops to less than 150 psig, THEN ENSURE RHR pump flow.
(
(
(
WBN REACTOR TRIP OR SAFETY INJECTION E-O Rev 28 I Step II /I,etian/Expected Response II Response Not Obtained APPEt\\lDIX A.
(E-O)
Page 2 of 0 EQUIPMENT VERIFICA nON
- 4.
MONITOR ECCS operation:
- d. Charging pumps RUNNING.
- b. Charging pump alignment:
RV:ST oLltletsl-LCV-62-135 and *j-LCV-62-136 opaJ.
'lCT olJtlets *1-LC\\/ 32 and 1-LCV-62-133 CLOSED.
Charging "j-FCV-62-90 and l-FCV-62-'9*1 CLOSED.
- c. RHR pumps RU NNING.
- d. SI pumps RUNr--J ING.
- e. BIT alignment Outlets -FCV-63-25 and 1-FC\\f-63-26 OPEN.
Flo'N thru BIT.
- f.
RCS pressure greater than 650 psig.
15 of 28
- 3. Manually START charging pumps.
- b. ENSURE at least one val.... e in each set aligned.
- c.
r\\l1anually START RH R pumps.
- d. Manually START Ell pumps.
- e. ENSURE at least one **,.-;J!ve aligned, and flo'll," tihru BIT.
- f.
Ef*~SURE 81 pump fJo"w.
IF ReS press drops to less than *150 psig, THEN ENSURE RHR pump flow.
('
WBN REACTOR TRIP OR SAFETY INJECTION E-O Rev 28 I Step II Actio n fExpected Respo n &e II Response Not Obtained 5
.APPENDIX A (E-O)
Page:3 of 0 EQUIPMENT VERIFICATION CHECK cntmt isolation:
- a. Phase A. isolation:
Tratn A GREEN.
Train B GREEN.
- b. Cntmt vent isolation:
Train A GREE~J.
Train B GREEN.
16 of 28 ACTUATE Phase A and Cntmt 'lent
!solation signal.
OR Manually CLOSE valves and dampers as necessary
(
(
WBt~
REACTOR. TRIP OR SAFETY INJECTION E-O Re"f 28 I Step II Action/Expected Response II Response Not Obtained 5
,A.PPENDIX A (E-O)
Page :3 of 0 EQUIPMENT VERIFICATION CHECK cntmt isolation:
- a. Phase A. isolation:
Train A GREEN.
Train B GREEN.
- b. Cntmt'./ent isolation:
Train A GREEN.
Train B GREEN.
16 of 28 ACTUATE Phase A and Cntmt lent Isolation signal, OR Manuall:\\" CLOSE valves.::md dampers as necessary.
WBN REACTOR TRIP OR SAFETY INJECTION E-O Rev 28 I Step II Action/Expected Response II Response Not Obtained
- 6.
APPENDIXA (E-O)
Page 4 of 10 EQUIPMENT VERIFICATION CHECK cntmt pressure:
Phase B DARK [MISSP].
Cntmt Spray DARK [M I SSP].
Cntmt press less than 2.8 psig.
PERFORM the following:
- 1)
ENSURE Phase B aduated.
- 2)
ENSURE Cntmt Spray actuated.
- 3)
ENSURE cntmt spray pumps runmng.
ENSURE cntmt spray flow.
- 5)
ENSURE Phase B isolation:
- Train A GREEN.
- Train B GREEN
- Manually CLOSE valves and dampers as nec.essary.
- 6)
STOP all Reps.
- 7)
ENSURE MSlVsand bypasses CLOSED.
- 8)
PLACE steam dump controls OFF.
- 9)
WHEN 10 minutes has elapsed since Phase B actuated, THEN ENSURE air retum fans start.
- 10) USE adverse mtmt [ADY]
setpoints where provided.
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WBN REACTOR TRIP OR SAFETY INJECTION E-O Rev 28 I Step II,8,ctioniExpeded Response II Response Not Obtained
- 6.
.APPE~~DIX A (E-Q)
Page 4 of 'to EQUIPMENT VERIFICATION CHECK cntmt pressure:
Phase B DARK [MISSP].
Cntmt Spray nARK [MISSPI.
Cntmt press less than 2.8 psig.
PERFORM the following:
'1)
ENSURE Phase B actuated.
2}
ENSURE Cntmt Spray actuated.
- 3)
ENSURE cntrnt spray pumps running.
4}
ENSURE cntmt spra~~' flo'"".
5.,
ENSURE Phase B isolation:
- 6)
T' I EI}
9}
- Trai.n A GREEN.
- Train B GREEN
- :Manually CLOSE valves and dampers as necessary.
STOP all RCPs.
ENSURE MSIVs and bypasses CLOSED.
PLACE stearn dump controls OFF.
WHEN 0 minutes has elapsed since Phase B actuated, THEN ENSURE air return fans start.
- 10)
USE adverse cntmt [AD\\1 setpoints \\I.. *here provided.
WBN REACTOR TruP OR SAFETY INJECTION E-O Rev 28 I Step II ActionJExpected Response II Response Not Obtained APPENDIXA (E-O)
Page 5 of 0 EQUIPMENT VERIFICATION
- 1.
CHECK plant radiation NORMAL:
8 S/G blowdown rad recorder 1-RR-90-120 NORMAL prior to isolation [M-12J.
Condenser vacuum exhaust rad recorder 1-RR-90-119 NORMAL prior to trip [M-121-1-RR-90-106 and 1-RR-90-112 radiation recorders NORMAL prior to isolation fM-12].
SJG main steamline discharge monitors NORMAL [M-30].
Upper and Lower containment high range monitors NORMAL
[M-30].
NOTIFY Unit Supervisor conditions NORMAL ENSURE all DIGs RUNNING.
18 of 28 NOTIFY Unit Supervisor IMMEDIATELY.
EMERGENCY START DIGs
(
(
WBN REACTOR TRIP OR SAFETY INJECTION E-O Rev 28 I Step II Action/Expected Response II Response Not Obtained A.PPENDlX A (E-O)
Page 5 of 0 EQUIPMENT VERIFICATION 7"
CIl ECK plant radiation NORMAL:
8 SiC? blO'Ndmi';TI rad recorder 1-RR-S10- 20 NORMAL prior to isolation [M-"12].
Condenser vacuum exhaust rad recorder "j-RR-90-"1 19 NORMA.L prior to trip [1'11-"12].
l-RR-90-106 and 1-RR-90-112 radiation recorders NORM"AL prior to isolation [1*,'1-12].
S/G main steamlinedischarfle monitors NORMAL [M-31J].
Upper and LovI'er containment high range monitors NORMfo,L
[M-30].
NOTIFY Unit Superv"isor conditions NORMAL ENSURE all DiGs RUNNING" 18 of 28 NOTIFY Unit Supervisor IMMEDIATELY.
EMERGENCY START DIGs
WBN REACTOR TRIP OR SAFETY INJECTlor, E-O Rev 28 I Step II Action/Expecteel Response II Response Not Obtained APPENDIXA (E-O)
Page 6 of 0 EQU IPMENT VERIFICATION 9_
ENSURE ASGTS operation:
- a. ABGTS fans RUNNING.
FCO-30-146A.
FCO-30-14SR FCO-30-15TA.
FCO-30-157B.
W.
ENSURE at least four ERCV...
- ptmlps RU ~~NING, one on each shutdo'wn hoard preferred.
- 1.
ENSURE ERCVV supply valves OPEN to flJnning DIGs.
- 12.
ENSURE CCS HX C A.L T DISCH TO HDR S, O-FC\\l-67-1S2,is open to position A.
'190f28
- a. r'Jianually START fans.
- b. Localill OPEN dampers.
rvlalluaHy START pumps as neoessary'w IF ERC'N can NOT be aligned to funning DIG, THEN EMERGENCY STOP affected
[)jG.
Manually OPEN O-FC'V-67 -152 to position A..
(
(
(
WBN REACTOR TRIP OR SAFETY INJECTION E-O Rev 28 I Step II Action/Expected Response II Response Not Obtained APPE~~DIXA (E-O)
Page 6 of 10 EQUIPMENT VERIFICATION
- 9.
ENSURE A8GTS operation:
- 3.,tJ..BGTS fans RUNNING.
FCO-30-146,A..
FCO-30-146B.
FCO-30-1S7 A.
FCO-30-157B.
- 10.
ENSURE at least four ERG'I'! pumps RlJ t'~NING, one on each shutdov'lrJ board preferred.
- 1.
ENSURE ERCVV supply va!ves OPEN to mnning DIGs.
- 12.
ENSURE CCS HX C A.L T DISCH TO HDR S, O-FC'/-67-1S2. is open to position A.
'I 9 of 28
- a.
Manually START fans.
- b. Locally OPEN dampers.
ManuaHy START pumps as necessar:lN IF ERC'.N can NOT be aligned to running DfG, THEN EMERGENCY STOP affected DIG.
Manually OPEN O-FC\\l-67 -152 to position A.
WBN REACTOR TRIP OR SAFETY INJECTION E-O Rev 28 I Step II ActionJExpected Response II Response Not Obtained APPENDIXA (E-O)
Page 7 of 10 EQU IPMENT VERIFICATION
- 13.
CLOSE ecs HX e DISCH TO HIJR A, O-fCV-67-144.
- 14.
MONITOR EGTS operation:
- EGTS fans RUNNING.
- ENSURE dampers OPEN VERIFY filter bank dp between 5 and 9 inches of water.
- 15.
ENSURE CGS pumps RUNNING:
- 18-8 CCS pump.
Manually START fans OPEN dampers.
Manually START pumps as necessary.
NOTE The Upper and lower Cntmt.ad monitors sampling pumps should be shutdown ifthe sample flowpath is isolated.
The following equipment is located on 1-M-9.
- 16.
CHECK CNTMT PURGE fans STOPPED:
20 of 28 STOP fans and PLACE handswitc:h in PULl-TO-LOCK.
WBN REACTOR TRIP OR SAFETY INJECTION
~
I Action/Expected Response II Response Not Obtained APPENDIXA (E-O)
Page 7 of W EQUIPMENT VERIFICATION 3_
CLOSE CCS HX C DISCH TO HDR A, O-FC\\f-67 -144_
E-O Ref'." 28 14_
MONITOR EGTS operation:
- EGTS fans RIJNt'~ING,
!'>'1anually START fans OPHl dampers_
- ENSURE dampers OPEN
\\/ERIFY filter bank dp between 5 and 9 inches of,;,vater,
'15, ENSURE CCS pumps RUNNlt"JG:
(
- 1 A.-.A, CCS pump, Manually START pumps as necessary.
(
- 1 o-B CCS pump_
NOTE The Upper and lO'.'/er Cntmt rad monitors sampling pumps should be shutdo',,vrl ifthe sample flo"path is isolated.
The following equipment is located on -M-9.
6, CHECK ct'HMT PURGE fans STOPPED:
20 of 28 STOP fans and PLACE hands'Niter, in P'ULl-TO-LOCK.
WBW REACTOR TRIP OR SAFETY INJECTION E-O Rev.28 I Step II Actiof11Expected Response II Response Not Obtained APPENDIXA (E-O)
Page B of 10 EQUIPM ENT VERIFICATION
- 17.
CHECK FUEL HANDLING EXH fans STOPPED, Fuel and Cask loading dampers CLOSED:
- 18.
ENSURE AS GEN SUPPLY and EXH fans STOPPED.
STOP fans and PLACE handswitch in PULl-TO-LOCK, manually CLOSE dampers.
STOP fans and PLACE handswitcl1 in PULl-TO-LOCK.
NOTE
- 19.
ENSURE AS GEN SUP & EXH dampers CLOSED.
- 20.
ENSURE MeR & SPREAD RM FRESH AIR dampers CLOSED:
- FCV-31-3_
- FCV-31-4.
21 of 28 Manually CLOSE dampers.
Manually CLOSE dampers.
(
WBN REACTOR TRIP OR SAFETY INJECTION E-O Rev 28 I Step II A.ctionfExpectecl Response II Response Not Obtained A.PPH~DIXA (E-O)
Page B of 10 EQU1PMENT VERIFICATION H.
CHECK FUEL HANDLlN(3 EXH fans STOPPED, Fuel and Cask roading dampers CLOSED:
- m.
ENSURE AB GENSUPPLY and EXH fans STOPPED.
STOP fans and PLACE handswitch in PULL-TO-LOCK, manually CLOSE dampers.
STOP fans and PLACE handswitch in PULL-TO-LOCK.
NOTE
- Dampers 1-HS-3D-*158 and 2-HS-30-27D remain open during,A.BI.
- 9.
ENSURE AB GEN SUP & EXH dampers CLOSED.
- 20.
ENSURE MCR g SPREAD m..1 FRESH A.iR dampers CLOSED:
- FCV-31-3.
- FCV-31-4.
21 of 28 Manually CLOSE dampers.
Manually CLOSE dampers.
WBN REACTOR TRIP OR SAFETY INJECTION E-O Rev 28 I Step II Action/Expected Response II Response Not Obtained APPENDIX A (E-O)
Page 9 of 10 EQUIPM ENT VERIFICATION
- 21.
ENSURE at least one CB EMER CLEANUP fan RUNNING :and associated damper OPEN:
- CB EMERG CLEANUP FAN A-A, OR Fan B-B RUNNiNG.
- fCO-31-8, OPEN.
OR fCO-31-7, OPEN.
- 22.
ENSURE at least one CB EMER PRESS fan RUNNING and associated damper OPEN:
- CB EMERG PRESS FAN A-A, OR FAN B-8 RUNNING.
- fCO-31-6, OPEN.
OR fCO-31-5, OPEN.
220128 Manually START fan.
NOTIFY TSC if at least one damper NOT OPEN.
Manually START fan.
NOTIFY TSC if at least one damper NOT OPEN.
i \\
WBN REACTOR TRIP OR SAFETY INJECTION E-O Rev 28 lhlifiJ I A.dion/Expected Response II Response Not Obtained APPENDIX A.
(E-O)
Page 9 of iO EQUIPMENT VERIFICATION
- 21.
ENSURE at least one CB EMER CLEJl,NUP fan RUNN1NG and associated damper OPEN:
- CB EMERG CLEANUP FAN.A-A, OR Fan B-B RU~mING.
- FCO-31-H, OPEN.
OR FCO-31-7, OPEN.
- 22.
ENSURE at least one CB EMER PRESS fan RUNNING and associated damper OPEN:
- CB Er\\o1ERG PRESS Fft,r--J A-.t:J,.,
OR FAN B-B RUNN1NG.
- FCO-31-13. OPEN.
OR FCO-31-5, OPEN.
22of28 ManuaHy START fan.
NOTIFY TSC if at least one damper NOT OPEr--J.
Manually START fan.
NOTIFY TSC if at least one damper NOT OPEN.
WBN REACTOR TRIP OR SAFETY INJECTION E-O Rev 28 I Step II Action/Expected Response II Response Not Obtained APPENDIX A
{E-O)
Page 10 of 10 EQUIPMENT VERIFICATION
- 23.
ENSURE Control Building fans STOPPED and dampers CLOSED:
- 24.
INITIATE Appendix B.
23 of 28 Manually STOP fans.
NOTIFY TSC if any damper NOT CLOSED.
{
WBN REACTOR TRIP OR SAFETY INJECTION E-O Rev 28 I Step II Action/Expected Response II Response Not Obtained APP Er*J DIX A (E-O)
Page 0 of 10 EQUIPMENT VERIFICATION
- 23.
ENSURE Control BLlilding fans STOPPED and dampers CLOSED:
- 24.
INITIATE Appendix B.
23 of 28 Manually STOP fans.
NOTIFY TSC if any damper NOT CLOSED.
WBN REACTOR TRIP OR SAFETY INJECTION E-O Rev 28 I Step II ActionlExpected Response II Response Not Obtained APPENiJlXB (E-O)
Page 1 of 1 PHASE B PIPE BREAK CONTINGENCIES CHECK PHASE B actuated.
(MISSP XX-55-6C, -60)
- 2.
ENSURE 1-FCV-32-110 CLOSED.
(CISP XX-55-6E)
[A-train,. window 13]
- 3.
ENSURE 1-FCV-67-107 CLOSED.
(CISP XX-55-6E)
[A -train, window 43]
- 4.
ENSURE 1-FCV-10-92 CLOSED.
(CISP XX-55-6E)
[A -train, window 73]
- 5.
ENSURE 1-FCV-70-140 CLOSED.
(CISP XX-55~6F)
[8 -train, windo'N 74]
240i28 WHEN PHASE 8 actuation occurs; THEN GOTO step 2.
DISPATCH AUO to perform ATTACHMENT 81.
DISPATCH AUO to perform ATTACHMENT 82.
DISPATCH AUO to perform ATTACHMENT 83.
DISPATCH AUO to perform ATTACHMENT 84.
WBN REACTOR TRIP OR SAFETY INJECTION E-Q Re**... 2B I Step II Action/expected Response II Response Not Obtained
'"l L.
- 3.
- 4.
- 5.
A.PPENDIX B (E-O)
Page 1 of 1 PHASE B PIPE BREAK CONTINGENCIES CH ECI{ PHA.SE B actuated.
(MISSP XX-55-6C, -I3D)
ENSURE '1-FCV-32-11O CLOSED.
(CISP XX-55-6E)
[A.-tr.ain, '#lndo'~'i131 ENSURE '1-FCV-67 -107 CLOSED.
(C;:ISP - *1-XX-5E.-6E)
[A -train. 'Nindovl 43]
ENSURE '1-FCV-70-SI2 CLOSED.
(C.ISP -
-XX-56-fiE)
[A -train. window 73]
ENSURE 1-FCV-70-140 CLOSED.
(CISP XX-55-f3F}
[6 -train. windov;, 74]
24of2B WHEN PHA,SE B actuation occurs; THEN GO TO step 2.
DISPATCH AUO to perform
,A.TTACHMENT BL DISPATCH AUO to perform A.TTACHMENT B2.
DISPATCH AUO to perform!
ATTACHMENT B3.
DISPATCH AUO to perfoml ATTACHMENT B4.
AOI-l1 WBN TURBINE TRIP Revision 43 NOTE:
ATTACHMENT 1 Page 10(3 Page 21 of 26 TURBINE BUILDING NAUO DUllES FOLLOWING A TURBINE TRIP Steps 1, 2, 3, and 4 shall be given priolily. Step 1 shall be performed as soon as the #3 HDTPS are secured.. The remainder of the steps duties may be performed in any order Wtth the UO notified when work is complete.
- 1. WHEN #3 HDTPs are removed from service, THEN BYPASS #3 HDT to condenser:
PRESS MANUAl button on1-UC-6-105, #3 HEATER DRAIN TANK LEVEL [,70S/east end of #3 HOT], ANI)
VERIFY MANUAL button is LIT.
PRESS the", (ra.ise) button until controUer output indicates 100%.
VERIFY 1-LCV-6-105A and -1059, #3 HE.4.TER DRA1N TANK BYPASS TO CONDENSER, are OPEN [685JT3E].
- 2. ENSURE the following valves are OPEN to unisolate #2 Feedwater Heater Hi-level bypass to condenser LCVs [6S51T3Ej.
1-15V-6-22, MFW HTR A2 COND BYP DN5TR ISOL 1-15V-6-23, MFW HTR B2 COND BYP DN5TR ISOL 1-15V-6-24, MFW HTR C2 COND BYP DNSTR 150L
- 3.
RESTORE air to the # 2 Feedwater Heater Hf-leveillypass to condenser LCVs by OPENING the following valves. [70'8 T10j:
1-15V-32-9131, CONTROL AIR ISOLATION VALVE TO UC-6-1988 1-15V-32-9132. CONTROL AIR ISOLATION VALVE TO UC-6-1989 1-15V-32-9133, CONTROL AIR ISOLATION VALVE TO UC-6-1990
- 4.
CLOSE MSR HP drains to #1 heaters [EI108ITurb Bldg sooth end 01#1 heaters}:
MFW HEAlER A1 SHELL SIDE INlElIS0l, 1-ISV-6-575 MFW HEATER 9lSHElL SIDE INLET ISOl, 1-ISV-6-576.
MPN HEATER C1 SHEll SIDE INLET ISOL, 1-ISV-6-571.
- 5.
STOP turbine EHC pumps USING 1-HB-47-9 EH flUID PUMP 1A alid 1-HS-47-14, EH FLUID PUMP 1B by placing both pumps in STOPIPULl-l0-l0CK beginning with standby. pump first [at EHC mezzanine, TB, eL 140].
- 6.
PLACE 1-HS-5-94, EX SlM lOW POINT DRN COMMON CNTl SW to OPEN,
[locally on lP Heater deck, T6H/724]L
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AOI-17 WBN TURBINE TR1P Revision 43 NOTE:
ATTACHMENT 1 Pa';)B 1 of 3 Page 21 of 26 TURBINE BUILmNG NAUO DUTIES fOLLOWING A TURBINE TRIP Steps 1, 2, 3, alid 4 shall be given priori'.y. Step 1 shall t)e performed as soon as the #3 HDTPS are secured. nle remainder of the steps duties may' be performed in any order witI'! the UO nomied,,./hen ',',:ork is complete.
- 1. WHEN #3 HDTPs are rer-love::! from sen'ice. THEN BYPASS #3 HDT G:J condenser:
PRESS M.A.NUAll)utton on 1-UC-6-105, #3 HE}l..TER ORlI.lN TANK LE\\/EL [7D8ieast end of #3 HDT], AND VERIFY !'.!1tINU;'.L button is LIT.
PRESS the 1\\ (raLse:: :)utton until contfO~ler outDU: ind!ca;:Bs 1 OD~f.J.
VERIFY 1-LCV-6-1Q5.4. and -1058, #3 HEfnER DRPdN TA~~K BYP.4.S8 TO GONDE~JSER, are OPEN [6H5fT3E].
- 2. ENSURE the follO'.'1ing valves are OPEN to unisolate #2 Feed'water Heater Hi-level bypass to condenser LCVs 168E./T.EJ.
1-IS\\/-6-22, MFIlV' HTR,42 COND 6YP DNSTR ISOL
'1-ISV-6-23, MF'N HTR 62 COND B\\'P DNSTR ISOL 1-ISV-6-24, MF"IV HTR C2 COND m"p DNSTR !SOL
- 3.
RESTORE air t:J me :# 2 Fsscl'.lIater Heater Hi-levellJypass '):) c:on::JeriSer LC\\/s C)y OPENING the follo'wing valves [7oB T10J:
1-IS\\I-32-913"1, CONTROL.AIH ISOUH10N V,A.LVE TO UC-6-1938
'1-ISV-32-~j132, CONTR.oL.A.IH ISOU.,.TiON VA.LVE TO LlC-6-'1989 1-ISV-32-9133, CONTROL.A.IR ISOLATION 'VA.LVE TO UC-6-'J990 4,
CLOSE r',*lSR. HP drains to #1 heaters [=170arrurb Bld.~south end of #1 heatersJ:
MF'lo!' HEA,TER Ai SHELL SI.D= INLET ISOL, 1-18\\/-6-575 MF'N HEATER 81~SHELl SI.DE INLET [SOL 1-IS\\/-6-576-.
MF',r,/ HEATER C1 SH=LL SIDE I~JLET ISOL, 1-ISV-6-577.
E*.
STOP turl)ine EHC pumps USING 1-HS-47-9 EH FLUID PUMP 1A and 1-HS-47-14, EH FLUI.D PUMP 1 B b~i plaGin'~ both pumps in STOPl?ULL-TO-LOCK beginnin,;) with stamj!)y pump first {at EHC mezzanine, TB, e1740J.
- 6.
PLACE 1-HS-5-94, =X 8TM LO'>!'i POINT DRN COMf<... 1mJ CNTL S'N to OPEN,
[locally on LP Heater clec~\\, T6H/724l.
(
WBN TURBINE TRlP ATTACHMENT 1 Page 2of3 AOI-l1 Revision 43 Page 22 0126 TURBINE BUILDING NAUO DUTIES FOLLOWING A TURBINE TRIP (continued)
- 1.
OPEN MSR startup vent isolation valves [located at high press. end of MSR]:
ISOLATION VALVE FORUSR 1A-1 STARTUP VENT, 1-ISV-5.-:204Q ISOLATION VALVE FOR USR 1B-1 STARTUP VENT, 1-ISV-6-2041 ISOLATION VALVE FOR MSR 1C-1 STARTUP VENT, H8V-6-2042 ISOL4.TION VALVE FOR USR 1A-2 STARTUP VENT, 1-ISV-6-2043 ISOLATION VALVE FOR USR 1 B-2 STARTUP VENT, 1-ISV-6-2044 ISOLATION VALVE FOR MSR 1C-2 STARTUP VENT, 1-18V-6-2045 NOTE 1 Coordinate with UO based on plant conditions and planned evolutions.
NOTE 2 If the unit is to remain in Hot Standby in the following step, re-alignment of main steam traps may not be required.
- 8.
REALIGN main steam trap drains USING SOI-1.01, Main Steam System, if required by plant conditions.
- 9.
ENSURE the hydrogen seal oil system amI stator cooling water system operating normaUy wIth system temp maintaining between 95'" and 105"F (may require RCW isolation if TCV has excessive leakage). Refer to SOI-35.02 and SOI-35.03 respecti.... ely for guidance.
1-TI-35-264, H2 SIDE OIL FILTER OUT. TEMP.
1-TI-35-251, AS OIL FILTER OUTlET TEMP.
1-TI-35-97, STAT COIL'NTR INt TEMP [155fSW GEN SKIRT].
OR 1-TIC-24-13, AIR SIDE SEAL OIL CtR TEMP INO CNTLR.
1-TIC-24-74, H2 SIDE SEAL OIL CLR TEMP IND CNTLR
- 10. AFTER turbine drops to tess than 600 rpm, THEN ENSURE turning gear oil pump, seal oil hackup pump and bearing lift oil pump has started as required and pu mp press are normal.
1-HS-47-62, TURNING GEAR Oil PUMP.
1-HS-47-61B, TURBINE SEAL OIL BACK-UP PUMP_
1-HS-47-10B, BEARING UFT OIL PUMP.
- 11. AFTER turbrne drops to zero rpm, THEN ENSURE turbine is Oli turning gear with 1i0 turbine almormafities observed.
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WBN TURBINE TRIP ATIACHMENT 1 Page 2 of 3 AOI-17 Revision 43 Page 22 oi25 TURBINE BUILDiNG NAUO DUTIES FOLLOWING ATURBINE TRIP (continued)
- 7.
OPEN MSR S~artLlp vent is!Jla:ion valves [located ~a< higt'l press end of !*IlSR]:
ISOU",Tlm~ \\',t:..LlE: FOR MSR I.A.-1 ST.A.RTJ? VENT, HSV-6-2040 ISOL,-\\ TION \\',A.L\\/E: FOR MSR 1. B-1 ST.A.RTU? \\/ENT, HS'V-6-2041 ISOLA.TION \\/,A.LVE: FOR MSR 1C-"1 ST.t.,.RTUP VENT. 1-ISV'-e-2042 ISOLATlmJ1l,",.LV'E FOR MSR 1.A.-2 STARTU? "'/E~JT, 1-1SV-6-2043 ISOLATION VALV::: FOR r,lSR 1 B-2 STARTU? VE~JT, 1-IS\\/-6-2044 ISOLATION \\i,b.,LVE: FOR MSR lC-2 STP,R.TUP \\/ENT 1-18'\\,'-6-2045 NOTE 1 Coordin3!:ewith UO based on Dlant cond1:ions anoj planned evolutions.
NOTE 2 If tit',e uni~ is to remain in HOi Standi)), in the follov.'lng step, re-a!ii~nmen~
of main s:8am :raps may not be required.
fL REALIGN main ste-arl trap drains USiNG SOI-1.01, Main S~eam System, if required I)), plant conditions.
- 9.
ENSURE :l"le hy,jmgen seal oil systelTland stator coollng '.vater sys:em operatin';;J nOrl,ally
'Nith sys:em temp maintaining be;t-,,"eEH1 '}5 C and 1 05<F (may require RC'"". isolation if Te\\!
has e);:cessi.... e !ea~;age). Refer to SOI-35.02 and 801-35.03 resDec::ively for guldam:e.
1-TI-35-264, H2 SID::: OIL FILTER OUT. TEMP.
1-TI-35-25"L AS OIL FIL TE:R OUTLET TEMP.
1-TI-35-97, STAT COil \\'\\iTR INL TEr,..1p [755JS"N GE:~,J SKIRT].
OR 1-TIC-24-73,.A.I.R SIDE SE,4L OIL CLR TEr',1P I~,JD CNTLR.
1-TIC-24-74, H2 SIDE SEAL OIL GLR TEMP I~,m CNTLR
- 10. AFTER tu:r!)ine drops to less than 600 rpm, THEN ENSURE :uming gear oil pump, sI&al oil bac~;Llp PLlr:lP and t,earing lift oj! pump has started as required and pump press are normal.
1-HS-47-.fi2, TURt,JING GEAR Oil PUMP.
1-HS-47-61B, TURBINE SEA.L OIL BACK-UP PUMP.
1-HS-47-1DB, S=:,t..RING LIFT OIL ?UMP.
- 11. AFTER turl)ine drops to zero rpm, THEN ENSURE :uri:'lne is on turning gear with no turbine abnormalities observed.
WBN TURBINE TRfP ATTACHMENT 1 Page 3 of3 1\\01-11 Revision 43 Page 23 of 26 TURBINE BUILDING NAUO DUTIES FOllOWING A TURBINE TRIP {conUnued)
HSV-1-611, MFPT 1.1\\ HP STEAM SUPPLY ISOL 1-ISV-1-612, MFPT 18 HP STEAM SUPPLY ISOL.
- 13. AFTER main feed pump (MFP) turbirve drops to zero rpm, THEN ENSURE MFP turbine is 00 turning gear wITn no tUJoine abnormalities observed.
NOTE: The following step will isolate main steam from the building heat exchangers on a trip to prevent the vacuum breakers on the heat exchangers from opening and allowing d irvtrusion into the hotwell.
- 14. IF Building Heat is in service from #3 extraction, THEN
- a. NOTIFY Control Room to evaluate shutdown of Aux Bui~ding Supply and Exhaust Fans.
- b. ISOLATE stearn from building heat exchangers using 801-44.01 section for Removing BHS Hx From Service,,,,,rhell From #:3 Extractioll.
- c. PLACE Au); Boiters in service.
- d. WHEN Aux. Boilers placed in service, THEN PLACE bull£ling heat exchangers in service, If required, using SOI-44.01 section for Placing Bullding Heating System Heat Exc.hallgBrs In Service.
- 15. IF Steam Generator Blowdown is secured, THEN PERFORM shutdown of SGBD Radiation Monitors 1-RM-90-120/121 in accordance with 301-15.01.
- 16. IF Condensate Demilleralizer{s) ~n service, THEN ENSURE polisher f1ovt' meets minimum flow requiirement or secure polisher in accordance with 301-14.01
- 17. ISOLATE injection water to the follOwing pumps per SOI-54.01 to prevent water intrusion into the oil:
- 3 Heater DrailiTaink Pumps.
- 7 Heater Drain Tank Pumps.
Condensate Booster Pumps.
(
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WBN TURBINE TRIP ATTACHMENT 1 Page 3 of 3.
AOI-17 Revision 43 Page 23 of 25 TURBiNE BUILDING NAUO DUTIES FOLLOWING A TURBINE TRIP (continuecij "12. ENSURE selec.ted II,/'IF:::> HP Steam Supply valves CLOSED:
1-15\\/-1-131.1. MFPT lA HP ST~?,M SU?PLY [SOL.
1-13\\/-1-612, MFPT 18 'HP ST~?'f... 'I SU?PL Y ISOL
- 13. AFTER main feed Dumo (MFP) :url)lne drops to zero rpm, THEN ENSURE MFP turl)ir;;e is on turning gear 'Nith no turbine almomlalities observed, NOTE: Trle follo...,.jng stepw'iil isolate r1ain steam from trle ;mildil1g heat exchangers on a trip t.o prevent tl'"le vacuum breakers on the heat Bxcrlangers from opening and allo..... ing 0 2 intmsJon into the hot'/,ell.
14 IF BUJlding Hea: is in service from #3 extraction, THEN a, NOTIFY Control R.oom to evaluate shutdovvn of Au:.: Building Supply and Exl'Jaus:
Fans.
b, ISOLATE stearn from :milding flea: exchan'Jers using 801-44.01 section for RerlovinJ BHS !Hx From Ser..-ice 'y"ihen From # :3 Extraction.
- c. PLACE.A.ux Bollers in ser'/liee, d, WHEN,t.,ux. Boilers placed in sePliee, THEN PLACE Imilding hea:. exel'langers in serllice,lf required, using 801-44.01 section for Placing Building Heatlng System Hear,: Excrl~mg8rs. In Ser-,'jee.
15, IF Ste a r1 (3 e nerato r B10wdovm is secu red, THEN PERFORM shutdown of SGBD Radiation Monitors 1-Rf'.. 1-90-120!121. in accordance
'.vith 801-15.01.
- 16. IF Condensa~B Demineralizer(s} in seMee, THEN ENSURE polisfler flm*,>, meets minimum flow requirement OJ secure polisher in accordante with 801-14.01
- 17. ISOLATE lnjectiollwater to the following c*umps per 801-54.01 to pre'lent 'vvater intruslon into the oil:
- 3 Hea~er Drain Tank, Pumps.
- 7 Hea:ef Drain Tank. Pumps.
Condensate Booster Pumps.
WBN LOSS OF REACTOR OR SECONDARY COOLANT APPENDIXA (E-1 )
Page 1 of 1 CLA BREAKER OPERATION E-1 Re..... 15 CLOSE the following to restore power to cold leg accumulator isolation valves:
BOARD COMPT NOMENCLA TU RE 480 V Reactor
-BKR-63-118A MOV Board 3F2 SIS CL ACCUM 1 OUT 1A1-A ISOL (1-FCV-63-118) 480 V Reactor 1-BKR-63-80A MOY Board 17F2 SIS CL ACCUM 3 OUT 1A1-A ISOL (1-FCV-63-80) 4BO Y Reactor 1-BKR-63-9BA MOY Board 3F2 SIS CL ACCUM 2 OUT 1B1-B ISOL (1-FCV-63-98) 480 V Reactor 1-BKR-63-67A MOY Board 16F2 SIS CL ACCUM 4 OUT 1B1-B ISOL (1-FCV-63-67) 18 of 22
(
(
WBN LOSS OF REACTOR OR SECONDARY COOLANT AF'PENDtX A (E-1 )
Page 1 of 1 CLA BREAKER OPERATION E-1 Rev '15 CLOSE the follov/ing to restore pm,ver to cold leg accumulator isolation "/alves:
BOARD COMPT NOMENCLATURE 480 \\/ Reactor
!-BKR-6:3-'J !8A r,,.1()V Board
- 3F2 SIS CL ACCUf'.,1 1 OUT 1ft.1-A ISOL ('l-FC:\\1 -~33-1.( 8) 480
'f l
'.f Reactor 1-BKR-i33-80A r,.. 10V Board 17F2 SIS CL ACCurvt '-:) OUT v'
1ft:1-A ISOL (1-FC/-l33-BO) 480 \\/ Reactor 1-BKR->33-fj8A f\\:10\\,l Board 3F2 SIS CL ACCurv12 OUT 1B1-B IS OL (1-F CV 98')
480
\\.' v Reactor
'l-BKR-63-67 A
[".. 10\\1 Board 113F2 SIS CL ACCurvi 4 OUT 1B1-B ISOL (1-FCV-63-6T) 18 of 22
WBN lOSS OF REACTOR OR SECONDARY COOLANT APPENDIXB (E-1)
Page 1 of 1 ICE CONDENSER AHU BREAKER OPERATION E-1 Rev 15 OPEN the following to remove power from ice condenser air handling units:
BOARD COMPT NOMENCLATURE 480 V Reactor 1-BKR-232-A/13D Vent Board 13D ICE COND 1-AHU 1 A-A 114/8/12/16/20/24128 480 V Reactor 1-BKR-232-Aft40 Vent Board 140 ICE CONO 1-AHU 1 A-A 317111/13/15/19/23/27 480 V Reactor 1-BKR-232-B/130 Vent Board 13D ICE COND 1-AHU 1B-B 216/10/14118/22/26/30 480 V Reactor 1-BKR-232-B/14D Vent Board 14D ICE CONO 1-AHU 1B-8 5f9f13/17/21/25/29 190(22
(
WBN lOSS OF REACTOR OR SECONDARY COOLANT AF'PE~~DlX B (E-1)
Page 1 of 1 ICE CONDENSER AHU BREAKER OPERATION E-1 Rev 15 OF E N the follo'vving to remO\\/e povler from ice condenser air handling units:
BOARD COMPT NOMENCLATURE 480 \\/ Reactor 1-BKR-232-Ai13D
\\/ent Board 13D ICE CO~',lD 1-A.H U-6'1-1 A.-A.
114 1Fn ")11 R '20'242'"'
- ,..
.i:...j _(!j, oJi' ,I. 0 480 \\,/ Reactor 1-BKR-232-A/14D Vent Board 140 ICE COND 1-A.HU 1 A.-A .~ 1J/'11 /1,:. 115/'1 gn'J ]')7 VI,' f ,_i"! lL*,.-I) L 480 \\j Reactor 1-BKR-232-8/130 Vent Board 130 ICE CONO l-A.H U-~3 - 1B-8 2/6/10/14/18/22/213/30 480 \\! Reactor 1-BKR-232-B!140 Vent Board '140 ICE COr',lD 1-A.HU 18-8 5!EW13t17l2H25l29 19 of 22
WBW LOSS OF REACTOR OR SECONDARY COOLANT APPENDIX C (E-1 ) Page 1 of 1 1*FCV*63*1 BREAKER OPERATlON E-1 Rev 15 CLOSE the following to restore power to 1-FCV-63-1: BOARD COMPT NOMENCLATURE 4BO V Reactor ~1-BKR-63-1A Board 2E1 RWST TO RHR SUeT 1A1-A (1-FCV-83-1) 200fll ( ( ( WBN LOSS OF REACTOR OR SECONDARY COOLANT APPENDIX C (E-1 ) Page 1 of '1 1*FCV*63*1 BREAKER OPERATION E-1 Rev 15 CLOSE the follo'v.ling to restore po\\*ver to 1-FCV-63-1: BOARD COMPT NOMENCLATURE 480 V Reactor 'I-BKR-6:3-tA, Board 2E1 RIlVST TO RH R S U CT i A.1-A. (1-FCV-63-'1 ) 20 of 22
( WBN lOSS OF REACTOR OR SECONDARY COOLANT APPENDIX 0 (E-1 ) Page 1 of 1 1-FCV-63-22 BREAKER OPERATlON E-1 Rev 15 CLOSE the followin.g to restore power to 1-FCV-63-22: BOARD COMPT NOMENCLATURE 480 V Reador 1-BKR-63-22A MOV Board 2F2 SIP COLD LEG 181-8 INJECTION (1-FCV-63-22) SHUNT TRIP BREAKER 21 of 22 ( ( WBN lOSS OF REACTOR OR SECONDARY COOLANT APPENDIX 0 (E-1"j Page -1 of 1 1.. FCV*63*22 BREAKER OPERATION E-1 Re"\\i"15 CLOSE the fol!ovling to restore pO\\*ller to 1-FC\\/-63-22: BOARD COMPT NOMENCLATURE 4,30 'l Reactor
- 1-BKR-G3-22,A.
r',*10V' Board 2F2 SIP COLD LEG 18'1-8 INJECTION ( -FCV-63-22) SHUNT TR!P BREAKER 21 of 22
SHIFT TURNOVER CHECKLIST age 0 P 1 f2 SHIFT TURNOVER CHECKLIST Page ___ of -- 0 SM IZI USIMCR Unit 0 UO Unit Off-going - Name 0 AUO Station 0 STA (STA Function) On-coming - Name Part 1 - Completed by off-going shiftlReviewed by on-coming shift: Abnonnal equipment lineup/conditions: lA Containment SEray System (CSS) EumE is out of service for bearing r92lacement, and is current1~ disassembled. LCO 3.6.6, Containment Spray System, Condition A was entered 6 hours ago. The lA CSS pump is expected to be returned to service in 16 hours. SIITest in progress/planned: (including need for new brief) Major ActivitieslProcedures in progress/planned: Maintain 100% ]2ower. Current RCS boron concentration is 877 EEm. Train AlChannel I Work Week. I Control Bank D is at 220 steps. Train AlChannel I Work Week. Radiological changes in plant during shift: None ]2lanned Part 2 - Performed by on-coming shift 0 A review of the Operating Log since last held shift or 3 days, whichever is less (N/A for AUOs) 0 A review of the Rounds sheets/Abnonnal readings (AUOs only) Review the following programs for changes since last shift turnover: 0 Standing Orders 0 LCO(s) in actions (N/A for AUOs) 0 PER review 0 Immediate required reading 0 TACF (N/A for AUOs) (N/A for AUOs) Part 3 - Performed by both off-going and on-coming shift 0 A walkdown of the MCR control boards (N/ A for AUOs) Relief Time: Relief Date: TVA 40741 [06-2008] Page 1 ofl OPDP-l-l [06-12-2008] SHIFT TURNOVER CHECKLIST ( P 1 f2 age 0 SHIFT TVRNOVER CHECKLIST Page of D SM ~ VS/MCR Vnit D VO Vnit Off-going - Name D AVO Station D STA (STA Function) On-coming - Name Part 1 - Completed by off-going shiftlReviewed by on-coming shift: Abnonnal equipment lineup/conditions: IA Containment Spray System (CSS) £um£ is out of service for bearing re£lac=ent, and is currently disassembled. LCO 3.6.6, Containment Spray System, Condition A was entered 6 hours ago. The IA CSS £um£ is ex£ected to be returned to service in 16 hours. SiiTest in progress/planned: (including need for new brief) Major Activities/Procedures in progress/planned: Maintain 100% power. Current RCS boron concentration is 877 ppm. Train AlChannel I Work Week. I Control Bank D is at 220 steps. Train AlChannel I Work Week. ( Radiological changes in plant during shift: None planned Part 2 - Performed by on-coming shift D A review of the Operating Log since last held shift or 3 days, whichever is less (N/A for AVOs) D A review ofthe Rounds sheets/Abnonnal readings (AVOs only) Review the following programs for changes since last shift turnover: D Standing Orders D LCO(s) in actions (N/A for AVOs) D PER review D Immediate required reading D TACF (N/A for AVOs) (N/A for AVOs) Part 3 - Performed by both off-going and on-coming shift D A walkdown ofthe MCR control boards (N/A for AVOs) Relief Time: Relief Date: TVA 40741 [06-2008] Page 1 of 1 OPDP-l-l [06-12-2008] (
SHIFT TURNOVER CHECKLIST age 0 P 2 f2 SHIFT TURNOVER CHECKLIST Page ___ of -- D SM D VS/MCR Vnit ~ VO Vnit Off-going - Name D AVO Station D STA (STA Function) On-coming - Name Part 1 - Completed by off-going shiftlReviewed by on-coming shift: Abnonnal equipment lineup/conditions: IA Containment S.eray Si:stem (CSS) EumE is out of service for bearing replacement, and is currentli: disassembled. LCO 3.6.6, Containment SEray System, Condition A was entered 6 hours ago. The lA CSS.eum.e is ex,eected to be returned to service in 16 hours. SIITest in progress/planned: (including need for new brief) Major ActivitieslProcedures in progress/planned: Maintain 100% Eower. Current RCS boron concentration is 877.e.em. Train AlChannel I Work Week. Control Bank D is at 220 st~s. Train AlChannel I Work Week. Radiological changes in plant during shift: Part 2 - Performed by on-coming shift D A review of the Operating Log since last held shift or 3 days, whichever is less (N/A for AVOs) D A review of the Rounds sheets/ Abnonnal readings (AVOs only) Review the following programs for changes since last shift turnover: D Standing Orders D LCO(s) in actions (N/A for AVOs) D PER review D Immediate required reading D TACF (N/A for AVOs) (N/A for AVOs) Part 3 - Performed by both off-going and on-coming shift D A walkdown of the MCR control boards (N/A for AVOs) Relief Time: Relief Date: TVA 40741 [06-2008] Page 1 of 1 OPDP-l-l [06-12-2008] SHIFT TURNOVER CHECKLIST P 2 f2 age 0 ( SHIFT TURNOVER CHECKLIST Page of D SM D US/MCR Unit ~ UO Unit Off-going - Name D AUO Station D STA (STA Function) On-coming - Name Part 1 - Completed by off-going shiftlReviewed by on-coming shift: Abnormal equipment lineup/conditions: I A Containment Spray System (CSS) £umJ2 is out of service for bearing replacement, and is currently disassembled. LCO 3.6.6, Containment Spray System, Condition A was entered 6 hours ago. The lA CSS J2umJ2 is eXJ2ected to be returned to service in 16 hours. SiiTest in progress/planned: (including need for new brief) Major Activities/Procedures in progress/planned: Maintain 100% Rower. Current RCS boron concentration is 877 ppm. Train AlChannel I Work Week. Control Bank D is at 220 steps. Train AlChannel I Work Week. ( Radiological changes in plant during shift: Part 2 - Performed by on-coming shift D A review of the Operating Log since last held shift or 3 days, whichever is less (N/A for AUOs) D A review of the Rounds sheets/Abnonnal readings (AUOs only) Review the following programs for changes since last shift turnover: D Standing Orders D LCO(s) in actions (N/A for AUOs) D PER review D Innnediate required reading D TACF (N/A for AUOs) (N/A for AUOs) Part 3 - Performed by both off-going and on-coming shift D A walkdown of the MCR control boards (N/A for AUOs) Relief Time: Relief Date: TVA 40741 [06-2008] Page 1 of 1 OPDP-l-l [06-12-2008] (
p\\.ppendix D Scenario Outline* Form ES-D-1 *1 Facility: Watts Bar Fall NRC Scenario No.: 2 OpTest No.: 1 Exam 2009 Examiners: Operators: SRO RO BOP Initial Conditions: 88% power, MOL. Boron concentration is 951 ppm. Control Bank "D" is at 1-93 steps. Turnover: 1A MD AFW Pump tagged for pump bearing replacement. Tech Spec 3.7.5.b was entered 6 hours ago. Expected return-to-service in 16 hours. The unit is returning to power following 1-B MFP trip 8 hours ago. The pre-conditioned power level is 96%. Power escalation to 95% is in progress. Continue power escalation. Train A Week Channel I. Event Malf. No. Event Type* Event Description No. 1 N/A R-RO Power escalation to 95%. N-BOP 2 RX11A 100 C-RO 1-PT-1-73 fails HIGH, causing continuous rod withdrawal. RO places rod TS-SRO control in MANUAL. Enter AOI-2, "Malfunction of Reactor Control System." Requires Tech Spec evaluation. 3 FW51B C-BOP 1 B Main Feed Pump shaft shears. BOP manually trips the 1 B MFP in order to initiate the required turbine runback. Enter AOI-16, "Loss of Normal Feedwater." 4 RC07B 25 C~RO 1-PCV-68-340, Pressurizer PORV fails partially open, causing a rapid TS-SRO RCS pressure reduction. RO manually closes PORV and its block valve. Enter AOI-18, "Malfunction of Pressurizer Pressure Control System." Requires Tech Spec evaluation. 5 ED07D C-BOP 1 D 6.9 KV Unit Board trips. Loss of the Standby MFP requires a load reduction to less than 800 MWE. Enter AOI-16, "Loss of Normal Feedwater," for loss of the Standby MFP. 6 FW20A50 M -ALL Feedwater break outside containment. Enter E-O, "Reactor Trip or Safety Injection." 7 FW50B 80 M-ALL Loss of Heat Sink, requiring entry into FR-H.1. FW22C (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Appendix D Watts Bar NRC Exam May 2009 NUREG 1021 Revision 9 [Appendix 0 Scenario Outline Form ES-O-1 Facility: Watts Bar Fall NRC Scenario No.: 2 Op Test No.: 1 Exam 2009 ( Examiners: Operators: SRO RO BOP Initial Conditions: 88% power, MOL. Boron concentration is 951 ppm. Control Bank "0" is at 193 steps. Turnover: 1A MD AFW Pump tagged for pump bearing replacement. Tech Spec 3.7.5.b was entered 6 hours ago. Expected return-to-service in 16 hours. The unit is returning to power following 1-B MFP trip 8 hours ago. The pre-conditioned power level is 96%. Power escalation to 95% is in progress. Continue power escalation. Train A Week Channel I. Event Malf. No. Event Type* Event Description No. 1 N/A R-RO Power escalation to 95%. N-BOP 2 RX11A 100 C-RO 1-PT-1-73 fails HIGH, causing continuous rod withdrawal. RO places rod TS-SRO control in MANUAL. Enter AOI-2, "Malfunction of Reactor Control System." Requires Tech Spec evaluation. 3 FW51B C-BOP 1 B Main Feed Pump shaft shears. BOP manually trips the 1 B MFP in order to initiate the required turbine runback. Enter AOI-16, "Loss of Normal Feedwater." ( 4 RC07B 25 C~RO 1-PCV-68-340, Pressurizer PORV fails partially open, causing a rapid TS-SRO RCS pressure reduction. RO manually closes PORV and its block valve. Enter AOI-18, "Malfunction of Pressurizer Pressure Control System." Requires Tech Spec evaluation. 5 ED07D C-BOP 106.9 KV Unit Board trips. Loss of the Standby MFP requires a load reduction to less than 800 MWE. Enter AOI-16, "Loss of Normal Feedwater," for loss of the Standby MFP. 6 FW20A50 M -ALL Feedwater break outside containment. Enter E-O, "Reactor Trip or Safety Injection." 7 FW50B 80 M-ALL Loss of Heat Sink, requiring entry into FR-H.1. FW22C (N)ormal, (R)eactivity, (I )nstru ment, (C)omponent, (M)ajor Appendix 0 Watts Bar NRC Exam May 2009 NUREG 1021 Revision 9
Kppendix D Initial Condition Turnover Event 1 Event 2 Event 3 Event 4 EventS Event 6 Event? I Critical Task 1 Critical Task 2 Appendix D Scenario Outline Form ES-D-1 Scenario 2 - Summary 88% power, MOL. Boron concentration is 951 ppm. Control Bank "0" is at 193 steps. 1A MO AFW Pump tagged for pump bearing replacement. Tech Spec 3.7.5.b was 1 entered 6 hours ago. Expected return-to-service in 16 hours. The unit is returning to power following 1-B MFP trip 8 hours ago. The pre-conditioned power level is 96%. Power escalation to 95% is in progress. Continue power escalation. Train A Week Channell. Power Escalation to 95%. 1-PT-1-73 fails HIGH, causing continuous rod withdrawal. Requires the RO to place rod control in MANUAL. Requires entry into AOI-2, "Malfunction of Reactor Control System." Requires Tech Spec evaluation. 1 B Main Feed Pump shaft shears. Requires the BOP operator to manually trip the 1 B MFP in order initiate the required turbine runback. Requires entry into AOI-16, "Loss of Normal Feedwater." 1-PCV-68-340, Pressurizer PORV fails partially open, causing a rapid RCS pressure reduction. Requires RO to manually close PORV and its block valve. Requires entry into AOI-18, "Malfunction of Pressurizer Pressure Control System." Requires Tech Spec evaluation. 10 Unit Board trips. This results in the loss of the 1 C Hotwell Pump, 1 C #3 Heater Drain Pump and the Standby MFP. Loss of the Standby MFP requires a load reduction to less than 800 MWE. Requires entry into AOI-16, "Loss of Normal Feedwater," to address actions for the loss of the Standby MFP. Feedwater break inside containment, requiring the crew to make the decision to trip the reactor and manually isolate the feedwater and condensate systems. Requires the crew to enter E-O, "Reactor Trip or Safety Injection," transition to E-2, "Faulted Steam Generator Isolation," and then terminate the SI USing ES-1.1, "SI Termination." Loss of Heat Sink, requiring entry into FR-H.1. After BOP requests venting of the TOAFW pump, the pump will be made available. This will allow for exit of FR-H.1. Establish feedwater flow into at least one SG before RCS bleed and feed is required. Establish the minimum required feedVliater flow rate to the SGs before SG dryout. I Watts Bar NRC Exam May 2009 NUREG 1021 Revision 9 ( ( ( fA\\ppendix 0 Initial Condition Turnover Event 1 Event 2 Event 3 Event 4 Event 5 Scenario Outline Form ES-O-1 Scenario 2 - Summary 88% power, MOL. Boron concentration is 951 ppm. Control Bank "0" is at 193 steps. 1A MO AFW Pump tagged for pump bearing replacement. Tech Spec 3.7.5.b was 1 entered 6 hours ago. Expected return-to-service in 16 hours. The unit is returning to power following 1-B MFP trip 8 hours ago. The pre-conditioned power level is 96%. Power escalation to 95% is in progress. Continue power escalation. Train A Week Channel I. Power Escalation to 95%. 1-PT-1-73 fails HIGH, causing continuous rod withdrawal. Requires the RO to place rod control in MANUAL. Requires entry into AOI-2, "Malfunction of Reactor Control System." Requires Tech Spec evaluation. 1 B Main Feed Pump shaft shears. Requires the BOP operator to manually trip the 1 B MFP in order initiate the required turbine runback. Requires entry into AOI-16, "Loss of Normal Feedwater." 1-PCV-68-340, Pressurizer PORV fails partially open, causing a rapid RCS pressure reduction. Requires RO to manually close PORV and its block valve. Requires entry into AOI-18, "Malfunction of Pressurizer Pressure Control System." Requires Tech Spec evaluation. 10 Unit Board trips. This results in the loss of the 1 C Hotwell Pump, 1 C #3 Heater Drain Pump and the Standby MFP. Loss of the Standby MFP requires a load reduction to less than 800 MWE. Requires entry into AOI-16, "Loss of Normal Feedwater," to address actions for the loss of the Standby MFP. Event 6 Feedwater break inside containment, requiring the crew to make the decision to trip the reactor and manually isolate the feedwater and condensate systems. Requires the crew to enter E-O, "Reactor Trip or Safety Injection," transition to E-2, "Faulted Steam Generator Isolation," and then terminate the SI using ES-1.1, "SI Termination." Event 7 Loss of Heat Sink, requiring entry into FR-H.1. After BOP requests venting of the TOAFW pump, the pump will be made available. This will allow for exit of FR-H.1. I J Critical Task 1 Establish feedwater flow into at least one SG before RCS bleed and feed is required. Critical Task 2 Establish the minimum required feedwater flow rate to the SGs before SG dryout. Appendix 0 Watts Bar NRC Exam May 2009 NUREG 1021 Revision 9
Sin. ~br Console Operators Instructions NRC Scenario 2 SIMULATOR SETUP INFORMATION
- 1.
ENSURE NRC Examination Security has been established.
- 2.
Right click on 348, and then select RESET.
- 3.
Enter the password.
- 4.
Select "Yes" on the INITIAL CONDITION RESET pop-up window.
- 5.
ENSURE the following information appears on the Director Summary Screen: hs-3-355 intentionally left blank R 00:00:00 hs-3-355-2 hs-3-355 indicating lights R 00:00:00 fw07a electric afw pump a trip M 00:00:00 hs-3-11Sa hs-3-11Sa auxiliary feedwater pump a-a motor sw R 00:00:00 hs-3-11Sa-1 01160 aux fw pmp a-a motor sw R 00:00:00 hs-3-355-1 hs-3-355 indicating lights R 00:00:00 fw50b afw pump b bearing wear M 00:00:00 fw22c airbound tdafw pump M 00:00:00 rx11a impulse pressure transmitter 1-73 fail to position M 1 00:00:00 fw1Sb feed water pump turbine vibration pump b M 2 00:00:00 fw51b main fw pump b sheared shaft M 2 00:00:10 rc07b przr porv pcv-6S-340 fail to any position M 3 00:00:00 ed07d loss of 6.9 kv unit board 1 d M 4 00:00:00 fw20 feed water line break M 5 00:00:00
- 6.
Place simulator in RUN and acknowledge any alarms. 00:00:00 close 00:00:00 Off 00:00:00 InActive 00:00:00 ptlock 00:00:00 ' Off 00:00:00 Off 00:00:00 SO 00:00:00 InActive 00:00:00 100 00:00:00 60 00:00:00 Active 00:00:15 25 00:00:00 Active 00:02:00 10
- 7.
Place 1-HS-3-118A, AFW PUMP A-A handswitch in the STOP-PULL-TO-LOCK position. Hang HOLD NOTICE card on handswitch. Hang HOLD NOTICE card on 1-HS-3-355, MD AFWP 1-A RECIRC VALVE.
- 8.
ENSURE Rod Bank Update reflects current step counter positions, in order to clear 83-0 Computer alarm. Page 1 of 4 close Off Active ptlock Off Off SO Active 91.0044 0 InActive 0 InActive 0 Sin. .or Console Operators Instructions NRC Scenario 2 SIMULATOR SETUP INFORMATION
- 1.
ENSURE NRC Examination Security has been established.
- 2.
Right click on 348, and then select RESET.
- 3.
Enter the password.
- 4.
Select "Yes" on the INITIAL CONDITION RESET pop-up window.
- 5.
ENSURE the following information appears on the Director Summary Screen: Key Description Type Event Delay Inserted Ramp Initial Final hs-3-355 intentionally left blank R 00:00:00 00:00:00 close hs-3-355-2 hs-3-355 indicating lights R 00:00:00 00:00:00 Off fw07a electric afw pump a trip M 00:00:00 00:00:00 InActive hs-3-118a hs-3-118a auxiliary feedwater pump a-a motor sw R 00:00:00 00:00:00 ptlock hs-3-118a-1 01160 aux fw pmp a-a motor sw R 00:00:00 00:00:00 Off hs-3-355-1 hs-3-355 indicating lights R 00:00:00 00:00:00 Off fw50b afw pump b bearing wear M 00:00:00 00:00:00 80 fw22c airbound tdafw pump M 00:00:00 00:00:00 InActive rx11 a impulse pressure transmitter 1-73 fail to position M 1 00:00:00 00:00:00 100 fw18b feed water pump turbine vibration pump b M 2 00:00:00 00:00:00 60 fw51b main fw pump b sheared shaft M 2 00:00:10 00:00:00 Active rc07b przr porv pcv-68-340 fail to any position M 3 00:00:00 00:00:15 25 ed07d loss of 6.9 kv unit board 1 d M 4 00:00:00 00:00:00 Active fw20 feed water line break M 5 00:00:00 00:02:00 10
- 6.
Place simulator in RUN and acknowledge any alarms.
- 7.
Place 1-HS-3-118A, AFW PUMP A-A handswitch in the STOP-PULL-TO-LOCK position. Hang HOLD NOTICE card on handswitch. Hang HOLD NOTICE card on 1-HS-3-355, MD AFWP 1-A RECIRC VALVE.
- 8.
ENSURE Rod Bank Update reflects current step counter positions, in order to clear 83-0 Computer alarm. Page 1 of 4 Value close Off Active ptlock Off Off 80 Active 91.0044 0 InActive 0 InActive 0
Sir.. ,or. Console Operators Instructions NRC Scenario 2 SIMULATOR SETUP INFORMATION
- 9.
ENSURE the "Train A Week - Channell" sign is placed on 1-M-30.
- 10.
Open Insight Files "Exam Data" and "auo", and display on second simulator computer monitor in the booth.
- 11.
Place simulator in FREEZE. Page 2 of4 SirL .or Console Operators Instructions NRC Scenario 2 SIMULATOR SETUP INFORMATION
- 9.
ENSURE the "Train A Week - Channel I" sign is placed on 1-M-30.
- 10.
Open Insight Files "Exam Data" and "auo", and display on second simulator computer monitor in the booth.
- 11.
Place simulator in FREEZE. Page 2 of 4
Simulator Console Operators Instructions NRC Scenario 2 EVENT INITIATION AND ROLE PLAY DESCRIPTION/ROLE PLAy 1 Power escalation to 100%. 2 l' 1-PT-1-73 fails HIGH. ROLE PLA Y: As work control, when contacted, inform the MeR that it will be an hour or more before the work package to trouble shoot and repair the failed channel is complete. ROLE PLA Y: As work control, when contacted to initiate performance of IMI-160, reply that the instrument shop will be notified and instructed to contact the control room before the IMI is to be performed. 3 2 1 B Main Feed Pump shaft shears. ROLE PLA Y: As the Turbine Building AUO, state that the shaft on the MFP has sheared. ROLE PLA Y: As work control, when contacted, inform the MeR that it will be an hour or more before the work package to trouble shoot and repair the failed channel is complete. 4 3 1-PCV-68-340, Pressurizer PORV fails open. ROLE PLA Y: As work control, when contacted, inform the MeR that it will be an hour or more before the work package to trouble shoot the PORV and its circuit. S 4 1 D 6.9 KV Unit Board trips. ROLE PLA Y: As Turbine Building AUO, when contacted, state that there is no apparent damage to any of the pumps lost when the 1 D Unit board tripped. ROLE PLA Y: As the Support Operator, when contacted state that the breaker for the 1 D Unit board tripped on instantaneous overcurrent. 6 S Feedwater break inside containment. ROLE PLA Y: NONE Page 3 of 4 ( ( Simulator Console Operators Instructions NRC Scenario 2 EVENT INITIATION AND ROLE PLAY Exam Event Simulator Event DESCRIPTION/ROLE PLAY 1 Power escalation to 100%. 2 l' 1-PT-1-73 fails HIGH. ROLE PLA Y: As work control, when contacted, inform the MCR that it will be an hour or more before the work package to trouble shoot and repair the failed channel is complete. ROLE PLA Y: As work control, when contacted to initiate performance of IMI-160, reply that the instrument shop will be notified and instructed to contact the control room before the IMI is to be performed. 3 2 1 B Main Feed Pump shaft shears. ROLE PLA Y: As the Turbine Building AUO, state that the shaft on the MFP has sheared. ROLE PLA Y: As work control, when contacted, inform the MCR that it will be an hour or more before the work package to trouble shoot and repair the failed channel is complete. 4 3 1-PCV-68-340, Pressurizer PORV fails open. ROLE PLA Y: As work control, when contacted, inform the MCR that it will be an hour or more before the work package to trouble shoot the PORV and its circuit. 5 4 10 6.9 KV Unit Board trips. ROLE PLA Y: As Turbine Building AUO, when contacted, state that there is no apparent damage to any of the pumps lost when the 1 D Unit board tripped. ROLE PLA Y: As the Support Operator, when contacted state that the breaker for the 1 D Unit board tripped on instantaneous overcurrent. 6 5 Feedwater break inside containment. ROLE PLA Y: NONE Page 3 of 4
Simulator Console Operators Instructions NRC Scenario 2 EVENT INITIATION AND ROLE PLAY Simulator Event 7 6 1 B MD AFW trips. ROLE PLA Y: As the Control Building AUO. when requested state that the 1 B MD AFW pump tripped on instantaneous overcurrent. 8 7 TD AFW pump steam bound. ROLE PLA Y: As the Auxiliary Building AUO, state that the TD AFW Pump casing and discharge line are extremely hot to the touch. When requested report that venting of the pump will begin. Report that venting of the TD AFW pump is successful. Page 4 of4 ( ( Simulator Console Operators Instructions NRC Scenario 2 EVENT INITIATION AND ROLE PLAY Exam Event Simulator Event DESCRIPTIONIROLE PLAY 7 6 1 B MO AFW trips. ROLE PLA Y: As the Control Building AUO. when requested state that the 1 B MD AFW pump tripped on instantaneous overcurrent. 8 7 TO AFW pump steam bound. ROLE PLA Y: As the Auxiliary Building AUO, state that the TD AFW Pump casing and discharge line are extremely hot to the touch. When requested report that venting of the pump will begin. Report that venting of the TD AFW pump is successful. Page 4 of 4
I Appendix 0 Required Operator Actions Form ES-O-2 I OpTest No.: NRC Scenario # 2 Event # --.;... ____ Page of 25 Event
Description:
Commence power escalation to 95%. Time II Position ~ Applicant's Actions or Behavior EXAMINER: Crew will continue power increase from 88% by periodically performing GO-4, "Normal Power Operation," Section 5.2 Step [39.1]. The plant is currently at 88%, so .the crew is waiting for power to reach 95% to perform Step [41]. BOP Increase turbine load as directed. BOP Start secondary equipment as directed. RO Withdraw control rods as directed. RO Perform dilutions as directed. SRO Direct reactivity manipulations. EXAMINER: The following actions are from 501-62.02, "Boron Concentration Control," Section 6.6, Minor Dilution. NOTES
- 1) Section 6.6, Minor Dilution, may be reproduced, laminated, displayed, reused, etc. as desired.
- 2) Minor Dilution is defined as the addition of Primary Water done several times each shift to compensate for fuel burn-up, and maintain Tavg on program.
RO [1] ENSURE 1-HS-68-341 H, BACKUP HEATER C, is ON, to equalize Pzr:-RCS CB. RO [2] ADJUST 1-FQ-62-142, PW BATCH COUNTER, for required quantity. RO [3] PLACE 1-HS-62-140B, VCT MAKEUP MODE inDIL. RO [4] TURN 1-HS-62-140A, VCT MAKEUP CONTROL, to START. [4.1] CHECK Red light is LIT. RO [5] MONITOR the following parameters: 1-PI-62-122 1-M-6 VCT PRESS 1-L1-62-129A 1-M-6 VCT LEVEL 1-FI-62-142 1-M-6 PW TO BLENDER FLOW 1-FQ-62-142 1-M-6 PW BATCH COUNTER 1-FQ-62-139 1-M-6 PW BATCH COUNTER RO [6] WHEN dilution is COMPLETE, AND.1-FCV-62-:128 is closed, THEN PLACE 1-HS-62-140B, VCT MAKEUP MODE, in AUTO. RO [7] TURN1-HS-62-140A, VCT MAKEUP CONTROL, to START. [7.1] CHECK Redlight is LIT EXAMINER: The following actions are from GO-4, "Normal Power Operation," Section 5.2 at Step [40]. SRO [40] IF startup is following refueling, THEN CONTINUE ascension to 90% RTP by performing the following:: Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # ......;.... _____ Page of 25 ( Event
Description:
Commence power escalation to 95%. Time Position II Applicant's Actions or Behavior EXAMINER: Crew will continue power increase from 88% by periodically performing GO-4, "Normal Power Operation," Section 5.2 Step [39.1]. The plant is currently at 88%, so the crew is waiting for power to reach 95% to perform Step [41]. BOP Increase turbine load as directed. BOP Start secondary equipment as directed. RO Withdraw control rods as directed. RO Perform dilutions as directed. SRO Direct reactivity manipulations. EXAMINER: The following actions are from SOI-62.02, "Boron Concentration Control," Section 6.6, Minor Dilution. NOTES
- 1) Section 6.6, Minor Dilution, may be reproduced, laminated, displayed, reused, etc. as desired.
- 2) Minor Dilution is defined as the addition of Primary Water done several times each shift to compensate for fuel burn-up, and maintain Tavg on program.
( RO [1] ENSURE 1-HS-68-341 H, BACKUP HEATER C, is ON, to equalize pzr-RCS CB. RO [2] ADJUST 1-FQ-62-142, PW BATCH COUNTER, for required quantity. RO [3] PLACE 1-HS-62-140B, VCT MAKEUP MODE in DIL. RO [4] TURN 1-HS-62-140A, VCT MAKEUP CONTROL, to START. [4.1] CHECK Red light is LIT. RO [5] MONITOR the following parameters: 1-PI-62-122 1-M-6 VCT PRESS 1-Ll-62-129A 1-M-6 VCT LEVEL 1-FI-62-142 1-M-6 PW TO BLENDER FLOW 1-FQ-62-142 1-M-6 PW BATCH COUNTER 1-FQ-62-139 1-M-6 PW BATCH COUNTER RO [6] WHEN dilution is COMPLETE, AND 1-FCV-62-128 is closed, THEN PLACE 1-HS-62-140B, VCT MAKEUP MODE, in AUTO. RO [7] TURN 1-HS-62-140A, VCT MAKEUP CONTROL, to START. [7.1] CHECK Red light is LIT EXAMINER: The following actions are from GO-4, "Normal Power Operation," Section 5.2 at Step [40]. SRO [40] IF startup is following refueling, THEN CONTINUE ascension to 90% RTP by performing the following:: Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # ......;.. _____ Page 2 of 25 ( Event
Description:
Commence power escalation to 95%. Time II Position ~ Applicant's Actions or Behavior
- 1) Power escalation should be per the most conservative of either the fuel pre-conditioning guidelines of TI-45 or the Turbine loading recommendations of SOI-47.02.
- 2) Turbine load change may be stopped by depressing the HOLD push button, using VPL, or by depressing the MANUAL push button
[40.1] IF during any of the following steps the REFERENCE changes BOP in an undesired manner THEN ADJUST VPL to stop turbine load rise. OR PUSH TURBINE MANUAL to place the turbine control mode in manual mode and proceed to section 5.6 BOP [40.2] SET VALVE POSITION LIMIT at 95% or as desired above the Gov Control Indication. BOP [40.3] SETLOAD RATE at predetermined value. BOP [40.4] PUSH REFERENCE CONTROL b.. (raise) button to set desired load in SETTER display. NOTE RCS should be diluted to raise TAVG, then Turbine load raised along with TAVG. Control rods will be used along with diJution to maintain b..1 and, if needed, for temperature. [40.5] PUSH GO button. [40.6] MONITOR Generator Megawatts RISING. [40.7] CHECK that load rise has STOPPED when reference display equals setter OR IF desired to stop the load change THEN STOP the load change by depressing the HOLD pushbutton. [40.8] WHEN desired to resume the load change, THEN PRESS the GO push button and continue to monitor load. [41] BEFORE raising above 80% power, THEN ENSURE the following: [41.1] 1-LCV-6-1 06A controlling properly. [41.2] 1-LCV-6-105A and 105B are NOT open. Since power is above 80% this step is CIRCLED AND SLASHED. in GO-4, indicating that it has already been performed. NOTES
- 1) After operations less than 85% Reactor power for more than 2 weeks, Reactor Engineering evaluation of Hot Channel Factors per 1-51-0-20 is required, before exceeding 90% power.
- 2) Performing NIS check and adjustment relatively close to 100% power may eliminate the need to RE-PERFORM these actions upon reaching 100% power.
"Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 I Appendix 0 Required Operator Actions Form ES-O-2 I Op Test No.: NRC Scenario # 2 Event # Page 2 of 25 ( Event
Description:
Commence power escalation to 95%. Time Position II Applicant's Actions or Behavior
- 1) Power escalation should be per the most conservative of either the fuel pre-conditioning guidelines of TI-45 or the Turbine loading recommendations of SOI-47.02.
- 2) Turbine load change may be stopped by depressing the HOLD push button, using VPL, or by depressing the MANUAL push button
[40.1] IF during any of the following steps the REFERENCE changes BOP in an undesired manner THEN ADJUST VPL to stop turbine load rise. OR PUSH TURBINE MANUAL to place the turbine control mode in manual mode and proceed to section 5.6 BOP [40.2] SET VALVE POSITION LIMIT at 95% or as desired above the Gov Control Indication. BOP [40.3] SET LOAD RATE at predetermined value. BOP [40.4] PUSH REFERENCE CONTROL Il (raise) button to set desired load in SETTER display. NOTE RCS should be diluted to raise TAVG, then Turbine load raised along with TAVG. Control rods will be used along with dilution to maintain III and, if needed, for temperature. [40.5] PUSH GO button. ( [40.6] MONITOR Generator Megawatts RISING. [40.7] CHECK that load rise has STOPPED when reference display equals setter OR IF desired to stop the load change THEN STOP the load change by depressing the HOLD pushbutton. [40.8] WHEN desired to resume the load change, THEN PRESS the GO push button and continue to monitor load. [41] BEFORE raising above 80% power, THEN ENSURE the following: [41.1]1-LCV-6-1 06A controlling properly. [41.2]1-LCV-6-105A and 105B are NOT open. Since power is above 80% this step is CIRCLED AND SLASHED in GO-4, indicating that it has already been performed. NOTES
- 1) After operations less than 85% Reactor power for more than 2 weeks, Reactor Engineering evaluation of Hot Channel Factors per 1-SI-0-20 is required, before exceeding 90% power.
- 2) Performing NIS check and adjustment relatively close to 100% power may eliminate the need to RE-PERFORM these actions upon reaching 100% power.
- Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # ......;.. _____ Page 3 of 25 Event
Description:
Commence power escalation to 95%. Time ~ Position II Applicant's Actions or Behavior [42] WHEN power is at or above 95%, THEN PERFORM the following [42.1] ADJUST PR NIS per 1-SI-92-1, NIS Daily Comparison. [42.2] IF evaluation of Hot Channel Factors is required, THEN ENSURE 1-SI-0-20, COMPLETE. [42.3] ENSURE MIG performs 1-SI-68-30 within 24 hours after power stabilizes at 90% or above (N/A if NOT applicable). [42.4] ENSURE the following level controllers maintaining levels within normal ranges: A. Feedwater heaters. B. MSR drain tanks Simulator operator enters Event 2. Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 I Appendix 0 Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # Page 3 of 25 Event
Description:
Commence power escalation to 95%. Time Position Applicant's Actions or Behavior [42] WHEN power is at or above 95%, THEN PERFORM the following [42.1] ADJUST PR NIS per 1-SI-92-1, NIS Daily Comparison. [42.2] IF evaluation of Hot Channel Factors is required, THEN ENSURE 1-SI-0-20, COMPLETE. [42.3] ENSURE MIG performs 1-SI-68-30 within 24 hours after power stabilizes at 90% or above (N/A if NOT applicable). [42.4] ENSURE the following level controllers maintaining levels within normal ranges: A. Feedwater heaters. B. MSR drain tanks Simulator operator enters Event 2. Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # _2~ ____ Page 4 of 25 Event
Description:
1-PT-1-73 Turbine Impulse Pressure Transmitter fails HIGH. Time II Position II Applicant's Actions or Behavior Indications available: 94-A TAVG-T REF DEVIATION Control Rods withdraw at 72 steps/minute. RO Diagnose and announce failure. May place Control Rods in Manual, after monitoring the generator RO megawatt meter and determining that no legitimate load* rejection/tl.Jrbine runback is in progress.. Enter and direct actions of AOI-2, "Malfunction Of Reactor Control SRO System", Section 3.2, "Continuous Rod Withdrawaillnsertion" and directs crew actions. EXAMINER: The following actions are from AOI-2,"Malfunction of Reactor Control System," Sub Section 3.2,"Continuous Rod Withdrawal/Insertion." RO
- 1. PLACE control rods in MAN.
RO
- 2. CHECK control rod movement STOPPED.
- 3. MAINTAIN T-avg on PROGRAM. (Reference Attachment 1)
USE control rods. RO OR ADJUST turbine load.. RO
- 4. CHECK loop T-avg channels NORMAL.
RO
- 5. CHECK Auct Tavg NORMAL on 1-TR-68-2B.
RO
- 6. CHECK NIS power range channels NORMAL.
- 7. CHECK the following:
BOP Turbine impulse pressure channeI1-PI-1-73, NORMAL. Tref and Auct Tavg NORMALon 1-TR-68-2B (Reference )
- 7. RESPONSE NOT OBTAINED PLACE steam dumps in pressure mode as follows:
- a. PLACE steam dumps to OFF.
- b. PLACE mode selector HS to STEAM PRESS.
BOP
- c. ADJUST steam dump demand to zero.
- d. PLACE steam dumps to ON.
- e. ENSURE controller set at 84% (1 092 psig).
- f. WHE.Ncondilions allow,THEN REFER TOSOI:-1.02 a~d pLACE steam dumps in TAVG Mode.
Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 I Appendix 0 Required Operator Actions Form ES-O-2 I Op Test No.: NRC Scenario # 2 Event # ..;;..2 _____ Page 4 of 25 Event
Description:
1-PT-1-73 Turbine Impulse Pressure Transmitter fails HIGH. Time II Position II Applicant's Actions or Behavior Indications available: 94-A TAVG-T REF DEVIATION Control Rods withdraw at 72 steps/minute. RO Diagnose and announce failure. May place Control Rods in Manual, after monitoring the generator RO megawatt meter and determining that no legitimate load rejection/turbine runback is in progress. Enter and direct actions of AOI-2, "Malfunction Of Reactor Control SRO System", Section 3.2, "Continuous Rod Withdrawal/Insertion" and directs crew actions. EXAMINER: The following actions are from AOI-2,"Malfunction of Reactor Control System," Sub Section 3.2,"Continuous Rod Withdrawal/Insertion." RO
- 1. PLACE control rods in MAN.
RO
- 2. CHECK control rod movement STOPPED.
- 3. MAINTAIN T-avg on PROGRAM. (Reference Attachment 1)
USE control rods. ( RO OR ADJUST turbine load. RO
- 4. CHECK loop T-avg channels NORMAL.
RO
- 5. CHECK Auct Tavg NORMAL on 1-TR-68-2B.
RO
- 6. CHECK NIS power range channels NORMAL.
- 7. CHECK the following:
BOP Turbine impulse pressure channeI1-PI-1-73, NORMAL. Tref and Auct Tavg NORMAL on 1-TR-68-2B (Reference )
- 7. RESPONSE NOT OBTAINED PLACE steam dumps in pressure mode as follows:
- a. PLACE steam dumps to OFF.
- b. PLACE mode selector HS to STEAM PRESS.
BOP
- c. ADJUST steam dump demand to zero.
- d. PLACE steam dumps to ON.
- e. ENSURE controller set at 84% (1092 psig).
- f. WHEN conditions allow, THEN REFER TO SOI-1.02 and PLACE steam dumps in TAVG Mode.
Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
I Appendix 0 Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # ...;;.,2 _____ Page 5 of 25 Event
Description:
1-PT-1-73 Turbine Impulse Pressure Transmitter fails HIGH. Time ~ Position II Applicant's Actions or Behavior
- 8. MONITOR core power distribution parameters:
Power range channels. ~ Flux Indicators. RO T-avg. Loop ~T. Incore TCs. Feed flow/Steam flow.
- 9. INITIATE repairs to failed equipment.
SRO Contacts Work Control to initiate troubleshooting and repairs to 1-PT-1-73, Turbine Impulse Pressure Transmitter.
- 10. REFER TO Tech Specs:
3.3.1-1, SRO 16.f. Turbine Impulse Pressure. P-13. Condition S. Verify interlock is in required state for existing unit conditions, within 1 hour OR be in Mode 2 within 7 hours. CAUTION Allowing at least 5 minutes between any rod control input (i.e., T-avg, T-ref, or NIS) change and placing rods in AUTO, will help prevent undesired control rod movement.
- 11. NOTIFY Chemistry of any reactor power changes greater than SRO 15% in one hour. (Step is NIA since the power change experienced did not exceed 15%)
12 IF loop ~ T and loop Tavg channels were defeated due to Tavg SRO channel failure, and Tavg channel has been repaired, THEN '" (Step is conditional and will be N/A'ed) SRO 13.WHEN conditions allow auto rod control, THEN: (Step is conditional and will be N/A'ed) SRO
- 14. WHEN conditions allow auto pzr level control, THEN... (Step is conditional and will be N/A'ed)
SRO
- 15. RETURN TO Instruction in effect.
SRO Crew Brief - conduct for this event as time 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 Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 I Appendix 0 Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # 2 Page 5 of 25 Event
Description:
1-PT-1-73 Turbine Impulse Pressure Transmitter fails HIGH. Time II Position II Applicant's Actions or Behavior
- 8. MONITOR core power distribution parameters:
Power range channels. L'1 Flux Indicators. RO T-avg. Loop L'1T. Incore TCs. Feed flow/Steam flow.
- 9. INITIATE repairs to failed equipment.
SRO Contacts Work Control to initiate troubleshooting and repairs to 1-PT-1-73, Turbine Impulse Pressure Transmitter.
- 10. REFER TO Tech Specs:
3.3.1-1, SRO 16.f. Turbine Impulse Pressure, P-13, Condition S. Verify interlock is in required state for existing unit conditions, within 1 hour OR be in Mode 2 within 7 hours. ( CAUTION Allowing at least 5 minutes between any rod control input (Le., T-avg, T-ref, or NIS) change and placing rods in AUTO, will help prevent undesired control rod movement.
- 11. NOTIFY Chemistry of any reactor power changes greater than SRO 15% in one hour. (Step is N/A since the power change experienced did not exceed 15%)
12 IF loop L'1T and loop Tavg channels were defeated due to Tavg SRO channel failure, and Tavg channel has been repaired, THEN... (Step is conditional and will be N/A'ed) SRO 13.WHEN conditions allow auto rod control, THEN: (Step is conditional and will be N/A'ed) SRO
- 14. WHEN conditions allow auto pzr level control, THEN... (Step is conditional and will be N/A'ed)
SRO
- 15. RETURN TO Instruction in effect.
SRO Crew Brief - conduct for this event as time 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 f \\ Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # ...;2~ ____ Page 6 of 25 Event
Description:
1-PT-1-73 Turbine Impulse Pressure Transmitter fails HIGH. Time II Position II Applicant's Actions or Behavior Operations Management - Shift Manager. SRO Maintenance Personnel - Maintenance Shift Supervisor (MSS). (Note: Maintenance notification may be delegated to the Shift Manager). Simulator operator enters Event 3 Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 ReviSion 9 I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # 2 Page 6 of 25 Event
Description:
1-PT-1-73 Turbine Impulse Pressure Transmitter fails HIGH. Time Position II Applicant's Actions or Behavior Operations Management - Shift Manager. SRO Maintenance Personnel-Maintenance Shift Supervisor (MSS). (Note: Maintenance notification may be delegated to the Shift Manager). Simulator operator enters Event 3 ( ( Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # _3~ ____ Page 7 of 25 Event
Description:
1 B MFP shaft shears. I Time II Position II Applicant's Actions or Behavior Indications: 50-B, MFPT 1 B ABNORMAL 53-0 TURBINE VIBRATION HI 54-0 PUMP VIBRATION HI 57-B, #3 HEATERS FW SUPPLY PRESS HI 58-A MFP 1 B FLOW LO 58-B, SG FEEDWATER FLOW HI 63-F SG LEVEL DEVIATION BOP Diagnose and announce failure as sheared shaft on the 1 B MFP. Enter and direct actions of AOI-:-16, "Loss of Normal Feedwater", SRO Subsection 3.5, "Loss of MFWP Greater than or Equal to 800 MWe (67% Turbine Load.)" SRO May direct the BOP to manually trip the 1 B MFP to initiate the runback per ARI 58-A Corrective Actions.. RO When the 1 B MFWP is tripped, the ROinserts control rods manually, due to the previous failure of 1-PT-1-73. EXAMINER: The following actions are from ARI 58-A, MFP 1 B FLOW LO BOP [1] CHECK MFP 1 B flow on 1-FI-3-84 [1-M-3] to confirm alarm. [2] CHECK the following instruments on 1-M-3 for indication of failure: BOP 1-PI-1-33, MAIN STEAM PRESS
- 1-PI-3-1, #1 HTR INLET PRESS SRO
[3] IF instrument failure, THEN... STEP is NIA since there is no instrument failure. [4] IF flow less than or equal to 1.72 X 106Ibs/hr, THEN: [a] ENSURE 1-FCV-3-84, MAIN FW PUMP B FLOW CONTROL BOP VLV, OPEN. [b] IF both Main Feed Pumps are in service, THEN TRIP the 1 B Main Feed Pump. SRO [5] REFER TO AOI-16,"Loss of Normal Feedwater", if necessary. EXAMINER: The following actions are from AOI-16, "Loss of Normal Feedwater," Section 3.5, "Loss of MFWP Greater Than or Equal to 800 MWe (67% Turbine Load.)." SRO
- 1. IF loss of S/G level is imminent, THEN TRIP reactor, and ** GO TO E-O, Reactor Trip or Safety Injection.
SRO
- 2. CHECK turbine load less than or equal to 1000 MWe (85%).
Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 I Appendix 0 Required Operator Actions Form ES-O-2 I Op Test No.: NRC Scenario # 2 Event # ~3 _________ Page 7 of 25 Event
Description:
1 B MFP shaft shears. Time II Position II Applicant's Actions or Behavior Indications: 50-B, MFPT 1 B ABNORMAL 53-D TURBINE VIBRATION HI 54-D PUMP VIBRATION HI 57-B, #3 HEATERS FW SUPPLY PRESS HI 5S-A MFP 1 B FLOW LO 5S-B, SG FEEDWATER FLOW HI 63-F SG LEVEL DEVIATION BOP Diagnose and announce failure as sheared shaft on the 1 B MFP. Enter and direct actions of AOI-16, "Loss of Normal Feedwater", SRO Subsection 3.5, "Loss of MFWP Greater than or Equal to SOO MWe (67% Turbine Load.)" SRO May direct the BOP to manually trip the 1 B MFP to initiate the runback per ARI 5S-A Corrective Actions. RO When the 1 B MFWP is tripped, the ROinserts control rods manually, due to the previous failure of 1-PT 73. ( EXAMINER: The following actions are from ARI 58-A, MFP 1 B FLOW LO BOP [1] CHECK MFP 1 B flow on 1-FI-3-S4 [1-M-3] to confirm alarm. [2] CHECK the following instruments on 1-M-3 for indication of failure: BOP 1-PI-1-33, MAIN STEAM PRESS
- 1-PI-3-1, #1 HTR INLET PRESS SRO
[3] IF instrument failure, THEN... STEP is NIA since there is no instrument failure. [4] IF flow less than or equal to 1.72 X 106Ibs/hr, THEN: [a] ENSURE 1-FCV-3-S4, MAIN FW PUMP B FLOW CONTROL BOP VLV, OPEN. [b] IF both Main Feed Pumps are in service, THEN TRIP the 1 B Main Feed Pump. SRO [5] REFER TO AOI-16,"Loss of Normal Feedwater", if necessary. EXAMINER: The following actions are from AOI-16, "Loss of Normal Feedwater," Section 3.5, "Loss of MFWP Greater Than or Equal to 800 MWe (67% Turbine Load.)." SRO
- 1. IF loss of S/G level is imminent, THEN TRIP reactor, and ** GO TO E-O, Reactor Trip or Safety Injection.
( SRO
- 2. CHECK turbine load less than or equal to 1000 MWe (S5%).
Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # _3~ ____ Page 8 of 25 Event
Description:
1 B MFP shaft shears. Time II Position II Applicant's Actions or Behavior BOP
- 3. PLACE tripped MFP recirc valve. controller in MANUAL; and CLOSErecirc valve.
BOP
- 4. CHECK turbine load less than BOO MWe (67%)
SRO
- 4. RESPONSE NOT OBTAINED ENSURE Standby MFWP running.
BOP
- 5. ENSURE MFWP speed rising to control S/G dP and levels on program.
CAUTION Continued load reductions below 800 MWe should be done using normal turbine controls at less than or equal to 5% min.
- 6. ENSURE adequate feed flow for existing conditions:
SRO Feed flow greater than or equal to steam flow. S/G levels returning to program.
- 7. ENSURE T-avg and T~ref within 3°.
RO With 1-PT-1-73 failed, the RO must use A 0/-2 Attachment 1 to determine the correct Tref for the current Tavg. CAUTION Runback may result in exceeding Tech Spec 3.2.3 limits on Axial Flux Difference (AFD). EXAMINER: It is possible for the crew to cause RCS pressure to drop below 2214 psig, which requires entry into LCO 3.4.1, DNB, Condition A, Restore parameter within 2 hours. RO B. MONITOR AFD within limitsof LCO 3.2.3. B. RESPONSE NOT OBTAINED INITIATE boration to return AFD RO within limits. Note: See SOI-62.02, Section 6.7, "Minor Boration" steps atthe back of this Scenario Guide.
- 9. IF feed flow greater than 40%, THEN ENSURE tripped MFWP turbine condenser valves CLOSED:
BOP Pump A, 1-FCV-2-205 and -210, OR Pump B, 1-FCV-2-211 and -216. BOP
- 10. MONITOR reg valves controlling S/G levels on program.
- 11. IF C-7 LOSS OF LOAD STM DUMP INTERLOCK annunciator LIT [66E],THEN BOP
- a. ENSUREsteam dump valves have zero demand.
- b. RESETloss:-of-load interlock with steam dump mode switch....
- 12. ENSURE Condensate System Pumps in service as necessary:
REFER TO GO-4, Normal Power Operation. SRO Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 I Appendix 0 Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # _3~________ Page 8 of 25 Event
Description:
1 B MFP shaft shears. Time II Position Applicant's Actions or Behavior BOP
- 3. PLACE tripped MFP recirc valve controller in MANUAL, and CLOSE recirc valve.
BOP
- 4. CHECK turbine load less than 800 MWe (67%)
SRO
- 4. RESPONSE NOT OBTAINED ENSURE Standby MFWP running.
BOP
- 5. ENSURE MFWP speed rising to control S/G liP and levels on program.
CAUTION Continued load reductions below 800 MWe should be done using normal turbine controls at less than or equal to 5% min.
- 6. ENSURE adequate feed flow for existing conditions:
SRO Feed flow greater than or equal to steam flow. S/G levels returning to program.
- 7. ENSURE T-avg and T-ref within 3°.
RO With 1-PT-1-73 failed, the RO must use AOJ-2 Attachment 1 to determine the correct Treffor the current Tavg. CAUTION Runback may result in exceeding Tech Spec 3.2.3 limits on Axial Flux Difference (AFD). ( EXAMINER: It is possible for the crew to cause RCS pressure to drop below 2214 psig, which requires entry into LCO 3.4.1, DNB, Condition A, Restore parameter within 2 hours. RO
- 8. MONITOR AFD within limits of LCO 3.2.3.
- 8. RESPONSE NOT OBTAINED INITIATE boration to return AFD RO within limits. Note: See SOI-62.02, Section 6.7, "Minor Boration" steps at the back of this Scenario Guide.
- 9. IF feed flow greater than 40%, THEN ENSURE tripped MFWP turbine condenser valves CLOSED:
BOP Pump A, 1-FCV-2-205 and -210, OR Pump B, 1-FCV-2-211 and -216. BOP
- 10. MONITOR reg valves controlling S/G levels on program.
- 11. IF C-7 LOSS OF LOAD STM DUMP INTERLOCK annunciator LIT [66E], THEN BOP
- a. ENSURE steam dump valves have zero demand.
- b. RESET loss-of-Ioad interlock with steam dump mode switch.
- 12. ENSURE Condensate System Pumps in service as necessary:
REFER TO GO-4, Normal Power Operation. SRO ( Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # _3 _______ Page 9 of 25 Event
Description:
1 B MFP shaft shears. Time Position Applicant's Actions or Behavior
- 13. IF reactor power dropped by greater than or equal to 15% in one hour, THEN NOTIFY Chemistry to initiate power change SRO sampling requirements.
(Step is N/A since the power change experienced did not exceed 15%) BOP
- 14. CHECK VALVE POS LIMIT LIT.
- 15. REDUCE turbine load setpoint using REFERENCE CONTROL V BOP (lower) AND GO button until VALVE POS LIMIT LIGHT not LIT, THEN SET valve position limiter to 95%.
SRO
- 16. INITIATE repairs on failed pump.
SRO
- 17. RETURN TO Instruction in effect.
CREW Crew Brief - conduct for this event as time allows prior to the next event. Notifications should be addressed as applicable if not specifically addressed by the procedure or in the crew brief. CREW Operations Management - Shift Manager. Maintenance Personnel - Maintenance Shift Supervisor (MSS). (Note: Maintenance notification may be delegated to the Shift Manager). Simulator operator enters Event 4 Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # ....;..3 _____ Page 9 of 25 Event
Description:
1 B MFP shaft shears. Time II Position II Applicant's Actions or Behavior
- 13. IF reactor power dropped by greater than or equal to 15% in one hour, THEN NOTIFY Chemistry to initiate power change SRO sampling requirements.
(Step is N/A since the power change experienced did not exceed 15%) BOP
- 14. CHECK VALVE POS LIMIT LIT.
- 15. REDUCE turbine load setpoint using REFERENCE CONTROL V BOP (lower) AND GO button until VALVE POS LIMIT LIGHT not LIT, THEN SET valve position limiter to 95%.
SRO
- 16. INITIATE repairs on failed pump.
SRO
- 17. RETURN TO Instruction in effect.
CREW Crew Brief - conduct for this event as time allows prior to the next event. Notifications should be addressed as applicable if not specifically addressed by the procedure or in the crew brief. CREW Operations Management - Shift Manager. Maintenance Personnel - Maintenance Shift Supervisor (MSS). (Note: Maintenance notification may be delegated to the Shift Manager). Simulator operator enters Event 4 Appendix D Watts Bar NRC Exam November 2009 NUREG1021Re~~on9
I Appendix 0 Required Operator Actions Form ES-O-2 I Op Test No.: NRC Scenario # 2 Event # _4~ ____ Page ~ of .....;2;;;.;5~-I1 Event
Description:
1-PCV-68-340, Pressurizer Power Operated Relief valve fails partially open. Time Position Applicant's Actions or Behavior 91-A PZR PORV/SAFETY OPEN 89-A PZR PORV LINE TEMP HI 90-B PZR PRESS LO-DEVN BACKUP HTRS ON BOP Diagnose and announce failure. May direct the RO to manually close 1-PT 340 and its associated SRO block valve per ARI 91-A PZR PORV/SAFETY OPEN Corrective Actions. Enter and direct actions of AOI-18, "Pressurizer Pressure Control SRO Malfunctions," or AOI-6, "Small Reactor Coolant System Leak," Either.instruction will provide actions to address the failure of the PORV. EXAMINER: The following actions are from ARI 91-A, PZR PORVISAFETY VALVE OPEN. [1] CHECK PZR pressure to determine if PZR PORV/Safety should be open. [2] CHECK other indications to determine if PZR PORV or Safety is open: Windows 89-A and 89-B 1-TI-68-330 [1-M-4] - Safety 1-TI-68-329 [1-M-4] - Safety 1-TI-68-328 [1-M-4] - Safety 1-TI-68-331 [1-M-4] - PORV [3] ENSURE PZR PORV and Safeties CLOSED when PZR pressure is below lift setpoint. CRITICAL [4] IF PZR PORV is NOT closed when PZR pressure is below lift TASK to setpoint, THEN perform [a] CLOSE associated PZR PORV block valve. prior to Rx trip or - [b] NOTIFY SRO.
- 51.
[c] REFER TO Tech Specs. Note: The ONB LCO may be entered and exited once the PORV block is closed. c EXAMINER: The following actions are from AOI-18, "Malfunction of Pressurizer Pressure Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 I Appendix 0 Required Operator Actions Form ES-O-2 I Op Test No.: NRC Scenario # 2 Event # _4 _____ Page ~ of..,;2::..;5:""'--i1 ( Event
Description:
1-PCV-68-340, Pressurizer Power Operated Relief valve fails partially open. Time II Position II Applicant's Actions or Behavior 91-A PZR PORV/SAFETY OPEN 89-A PZR PORV LINE TEMP HI 90-B PZR PRESS LO-DEVN BACKUP HTRS ON BOP Diagnose and announce failure. May direct the RO to manually close 1-PT 340 and its associated SRO block valve per ARI 91-A PZR PORV/SAFETY OPEN Corrective Actions. Enter and direct actions of AOI-18, "Pressurizer Pressure Control SRO Malfunctions," or AOI-6, "Small Reactor Coolant System Leak." Either instruction will provide actions to address the failure of the PORV. EXAMINER: The following actions are from ARI91-A, PZR PORV/SAFETY VALVE OPEN. [1] CHECK PZR pressure to determine if PZR PORV/Safety should be open. [2] CHECK other indications to determine if PZR PORV or Safety is open: Windows 89-A and 89-B ( 1-TI-68-330 [1-M-4]- Safety 1-TI-68-329 [1-M-4]- Safety 1-TI-68-328 [1-M-4]- Safety 1-TI-68-331 [1-M-4]- PORV [3] ENSURE PZR PORV and Safeties CLOSED when PZR pressure is below lift setpoint. CRITICAL [4] IF PZR PORV is NOT closed when PZR pressure is below lift TASK to setpoint, THEN perform [a] CLOSE associated PZR PORV block valve. prior to Rx trip or [b] NOTIFY SRO. SI. [c] REFER TO Tech Specs. Note: The ONB LCO may be entered and exited once the PORV block is closed. ( EXAMINER: The following actions are from AOI-18, "Malfunction of Pressurizer Pressure Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
I Appendix 0 Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # 4 Page _11_ of _2_5;"""-11 Event
Description:
1-PCV-68-340, Pressurizer Power Operated Relief valve fails partially open. Time II Position II Applicant's Actions or Behavior Control System." This is also an ACCEPTABLE procedure path. NOTE 120 AC VITAL PWR BD 1-IV [breaker 2] supplies the plugmold power strip associated with both PZR spray valves and several other instruments required to respond to this event.
- 1. CHECK pressurizer pressure stable or trending to desired pressure:
1 PI-68-340A, RO 1-PI-68-334, 1-PI-68-323, 1-PI-68-322. SRO/RO
- 1. RESPONSE NOT OBTAINED PLACE pzr master controller 1-PIC-68-340A in MANUAL and RESTORE press to normal.
RO
- 2. CHECK 1-XS-68-340D selected to a failed controlling or backup channel.
SRO/RO
- 2. RESPONSE NOT OBTAINED IF pzr press is abnormally low, THEN ** GO TO Step 6.
- 6. CHECK pzr spray valves CLOSED:
SRO/RO
- Green indicating lights LIT.
Pzr spray demand meters, 1-PIC-68-340B and1-PIC 340D indicating ZERO [1-M-4]. RO
- 7. CHECK pzr PORVs CLOSED:
EVALUATE tailpipe temperatures and acoustic monitor. RO
- 7. RESPONSE NOT OBTAINED CLOSE associated block valve.
BOP
- 8. CHECK pzr Safeties CLOSED:
EVALUATE tailpipe temperatures and acoustic monitor.
- 9. ENSURE pzr heaters on as required:
RO Control Group on at 2220 psig. Backup Groups on at 2210 psig. RO
- 10. CHECK aux spray, 1-FCV-62~84, CLOSED.
RO
- 11. CHECK pzr press STABLE or RISING.
- 12. ** GO TO Step 16.
SRO Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 I Appendix 0 Required Operator Actions Form ES-O-2 I Op Test No.: NRC Scenario # 2 Event # _4...;....-____ Page _11_ of _2;;;;.;5~~1 Event
Description:
1-PCV-68-340, Pressurizer Power Operated Relief valve fails partially open. Time Position Applicant's Actions or Behavior Control System." This is also an ACCEPTABLE procedure path. NOTE 120 AC VITAL PWR BD 1-IV [breaker 2] supplies the plugmold power strip associated with both PZR spray valves and several other instruments required to respond to this event.
- 1. CHECK pressurizer pressure stable or trending to desired pressure:
1 PI-68-340A, RO 1-PI-68-334, 1-PI-68-323, 1-PI-68-322. SRO/RO
- 1. RESPONSE NOT OBTAINED PLACE pzr master controller 1-PIC-68-340A in MANUAL and RESTORE press to normal.
RO
- 2. CHECK 1-XS-68-340D selected to a failed controlling or backup channel.
SRO/RO
- 2. RESPONSE NOT OBTAINED IF pzr press is abnormally low, THEN ** GO TO Step 6.
- 6. CHECK pzr spray valves CLOSED:
SRO/RO Green indicating lights LIT. Pzr spray demand meters, 1-PIC-68-340B and1-PIC 3400 indicating ZERO [1-M-4]. RO
- 7. CHECK pzr PORVs CLOSED:
EVALUATE tailpipe temperatures and acoustic monitor. RO
- 7. RESPONSE NOT OBTAINED CLOSE associated block valve.
BOP
- 8. CHECK pzr Safeties CLOSED:
EVALUATE tailpipe temperatures and acoustic monitor.
- 9. ENSURE pzr heaters on as required:
RO Control Group on at 2220 psig. Backup Groups on at 2210 psig. RO
- 10. CHECK aux spray, 1-FCV-62-84, CLOSED.
RO
- 11. CHECK pzr press STABLE or RISING.
- 12. ** GO TO Step 16.
SRO ( Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # --.;.4 _____ Page..1l.- of _2~5;""""'1 Event
Description:
1-PCV-68-340, Pressurizer Power Operated Relief valve fails partially open. Time Position Applicant's Actions or Behavior
- 16. WHEN pressurizer pressure stable and equipment status supports returned to normal, THEN ENSURE the following in AUTO:
SRO Pzr Master controller, Pzr spray controllers, All heater groups.
- 17. REFER TO the following Tech Specs:
3.4.11, Pressurizer Power - Operated Relief Valves. Action B. With one PORV inoperable and not capable of being manually cycled, close the associated block valve within 1 hour and remove power from the associated block valve and restore the PORV to OPERABLE status within 72 hours. SRO (NOTE: RO provides block valve breaker number by checking number above handswitch and providing to SRO when asked. SRO will direct removing power to the breaker utilizing NAUO.) 3.4.12, Cold Overpressure Mitigation System (COMS). Tracking Only. 3.4.1 DNB SRO
- 18. INITIATE repairs to failed equipment.
SRO
- 19. RETURN TO Instruction in effect.
EXAMINER: The following actions are from AOI-6, "Small Reactor Coolant System Leak" IT the SRO elects to implementAOI-6 in response to the PORV failure. NOTE During performance of this instruction the need for a rapid load reduction or Unit trip should be continuously evaluated. RO
- 1. CHECK pzr level DROPPING.
1/1 SRO
- 1. RESPONSE NOT OBTAINED: ** GO TO Step 4.
SRO 4.IF RHR Shutdown Cooling mode in service, THEN ** GO TO AOI-14, Loss of RHR Shutdown Cooling. (This step is NIA.)
- 5. MAKE plant announcement via PA:
SRO "Attention plant personnel. A primary system leak has developed. Any personnel located either inside containment or in the Auxiliary Building should exit the area immediately." (Repeat) RO
- 6. MONITOR pzr level STABLE or RISING.
CAUTION Attempts to quantify leak rate should not delay performance of the remaining steps. Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 I Appendix 0 Required Operator Actions Form ES-O-2 I Op Test No.: NRC Scenario # 2 Event # --...;.4 _____ Page ~ of _2;;;.;5~-I1 Event
Description:
1-PCV-68-340, Pressurizer Power Operated Relief valve fails partially open. Time Position Applicant's Actions or Behavior
- 16. WHEN pressurizer pressure stable and equipment status supports returned to normal, THEN ENSURE the following in AUTO:
SRO Pzr Master controller, Pzr spray controllers, All heater groups.
- 17. REFER TO the following Tech Specs:
3.4.11, Pressurizer Power - Operated Relief Valves. Action B. With one PORV inoperable and not capable of being manually cycled, close the associated block valve within 1 hour and remove power from the associated block valve and restore the PORV to OPERABLE status within 72 hours. SRO (NOTE: RO provides block valve breaker number by checking number above handswitch and providing to SRO when asked. SRO will direct removing power to the breaker utilizing NAUO.) 3.4.12, Cold Overpressure Mitigation System (COMS). Tracking Only. ( 3.4.1 DNB SRO
- 18. INITIATE repairs to failed equipment.
SRO
- 19. RETURN TO Instruction in effect.
EXAMINER: The following actions are from AOI-6, "Small Reactor Coolant System Leak" IT the SRO elects to implement AOI-6 in response to the PORV failure. NOTE During performance of this instruction the need for a rapid load reduction or Unit trip should be continuously evaluated. RO
- 1. CHECK pzr level DROPPING.
SRO
- 1. RESPONSE NOT OBTAINED: ** GO TO Step 4.
SRO
- 4. IF RHR Shutdown Cooling mode in service, THEN ** GO TO AOI-14, Loss of RHR Shutdown Cooling. (This step is NIA.)
- 5. MAKE plant announcement via PA:
SRO "Attention plant personnel. A primary system leak has developed. Any personnel located either inside containment or in the Auxiliary Building should exit the area immediately." (Repeat) RO
- 6. MONITOR pzr level STABLE or RISING.
CAUTION Attempts to quantify leak rate should not delay performance of the remaining steps. ( Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # -.;.4 _____ Page ll-of _2;;;.;5~-I1 Event
Description:
1-PCV-68-340, Pressurizer Power Operated Relief valve fails partially open. Time ~ Position II Applicant's Actions or Behavior
- 7. IF pzr level STABLE or RISING and time permits, THEN STABILIZE the plant to quantify the leak rate:
RO STOP pzr heaterlspray operation. STOP any heatuplcooldown in progress
- 8. CHECK secondary plant radiation normal:
Condenser exhaust monitors. BOP SIG blowdown monitors. Main steam line monitors. RO
- 9. CHECK safety valves CLOSED:
EVALUATE tailpipe temp and acoustic monitors.
- 10. CHECKpORVs CLOSED:
RO EVALUATE tailpipe temp and acoustic monitors.
- 10. RESPONSE NOT OBTAINED: CLOSE leaking PORV block valve.
REFER TO Tech Spec 3.4.11, Pressurizer Power Operated RO Relief Valves. GO TO Step 20. RO informs SRO that tailpipe temperature is elevated, and that the block valve has been closed. RO
- 20. MAINTAIN pzr level on program.
- 21. REFER TO EPIP-1, Emergency Plan Classification Flowchart:
SRO
- a. DETERMINE classification of event, and
- b. INITIATE manning the TSC. (if necessary)
NOTE The following steps Check indications to locate the leak and identify affected areas. SRO
- 22. NOTIFY RADCON for support to locally IDENTIFY and ISOLATE leak.
- 23. CHECK cntmt conditions NORMAL:
- Lower cntmt temperature.
RO/BOP
- Radiation monitors.
- Rx bldg sumps.
- 24. INITIATE 1-SI-68-32, Reactor Coolant System Water Inventory BOP Balance.
Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 I Appendix 0 Required Operator Actions Form ES-O-2 I Op Test No.: NRC Scenario # 2 Event # 4 Page ~ of _2_5'--~1 Event
Description:
1-PCV-68-340, Pressurizer Power Operated Relief valve fails partially open. Time II Position II Applicant's Actions or Behavior
- 7. IF pzr level STABLE or RISING and time permits, THEN STABILIZE the plant to quantify the leak rate:
RO STOP pzr heater/spray operation. STOP any heatup/cooldown in progress
- 8. CHECK secondary plant radiation normal:
Condenser exhaust monitors. BOP S/G blowdown monitors. Main steam line monitors. RO
- 9. CHECK safety valves CLOSED:
EVALUATE tailpipe temp and acoustic monitors.
- 10. CHECK PORVs CLOSED:
RO EVALUATE tailpipe temp and acoustic monitors.
- 10. RESPONSE NOT OBTAINED: CLOSE leaking PORV block valve.
REFER TO Tech Spec 3.4.11, Pressurizer Power Operated ( RO Relief Valves. GO TO Step 20. RO informs SRO that tailpipe temperature is elevated, and that the block valve has been closed. RO
- 20. MAINTAIN pzr level on program.
- 21. REFER TO EPIP-1, Emergency Plan Classification Flowchart:
SRO
- a. DETERMINE classification of event, and
- b. INITIATE manning the TSC. (if necessary)
NOTE The following steps check indications to locate the leak and identify affected areas. SRO
- 22. NOTIFY RADCON for support to locally IDENTIFY and ISOLATE leak.
- 23. CHECK cntmt conditions NORMAL:
- Lower cntmt temperature.
RO/BOP
- Radiation monitors.
- Rx bldg sumps.
- 24. INITIATE 1-SI-68-32, Reactor Coolant System Water Inventory BOP Balance.
Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # _4~ ________ Page 14 of 25 Event
Description:
1-PCV-68-340, Pressurizer Power Operated Relief valve fails partially open. Time II Position II Applicant's Actions or Behavior
- 25. CHECK aux bldg radiation for RCS leakage paths:
BOP
- Area monitor recorders 1-RR-90-1 and 0-RR-90-12A aux bldg points NORMAL.
- Vent monitor recorder 0-RR-90-1 01 NORMAL*
BOP
- 26. CHECK TURB/AUXlRX BLDG FLOODED annunciator [167-D]
DARK. RO
- 27. CHECK 1-TI-68-21, Flange LeakoffTemp, less than 120°F.
- 28. CHECK vessel head vent NORMAL:
RO
- 1-FSV-68-394 and 68-395 CLOSED or power removed.
- 1-TI-68-398, RX HEAD VENT TEMP at AMBIENT.
- RX HEAD VENT TEMP HI annunciator [88-E] DARK.
- 29. CHECK RCP thermal barrier flows NORMAL [O-M-27B]:
RO
- Less than 50 gpm per RCP.
- Return temp less than 115°F.
- 30. CHECK excess letdown normal:
RO
- Outlet temperature, less than or equal to 200°F.
SRO
- 31. INITIATE leak repair.
- 32. EVALUATE continued operation:
- Cntmt conditions.
SRO
- RCP status.
- Leakage within Tech Spec 3.4.13, RCS Operational Leakage limits.
- S/G and secondary plant leakage.
SRO
- 33. RETURN TO Instruction in effect.
CREW Crew Brief - conduct for this event as time allows prior to the next event. Notifications should be addressed as applicable if not specifically addressed by the procedure or in the crew brief. CREW Operations Management - Shift Manager. Maintenance Personnel - Maintenance Shift Supervisor (MSS). (Note: Maintenance notification may be delegated to the Shift Manager). Simulator operator enters Event 5 Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 I Appendix 0 Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # _4...;.....-____ Page 14 of 25 Event
Description:
1-PCV-68-340, Pressurizer Power Operated Relief valve fails partially open. Time Position II Applicant's Actions or Behavior
- 25. CHECK aux bldg radiation for RCS leakage paths:
BOP
- Area monitor recorders 1-RR-90-1 and 0-RR-90-12A aux bldg points NORMAL.
- Vent monitor recorder 0-RR-90-1 01 NORMAL BOP
- 26. CHECK TURBJAUXlRX BLDG FLOODED annunciator [167-D]
DARK. RO
- 27. CHECK 1-TI-68-21, Flange LeakoffTemp, less than 120°F.
- 28. CHECK vessel head vent NORMAL:
RO
- 1-FSV-68-394 and 68-395 CLOSED or power removed.
- 1-TI-68-398, RX HEAD VENT TEMP at AMBIENT.
- RX HEAD VENT TEMP HI annunciator [88-E] DARK.
- 29. CHECK RCP thermal barrier flows NORMAL [0-M-27B]:
RO
- Less than 50 gpm per RCP.
- Return temp less than 115°F.
- 30. CHECK excess letdown normal:
( RO
- Outlet temperature, less than or equal to 200°F.
SRO
- 31. INITIATE leak repair.
- 32. EVALUATE continued operation:
- Cntmt conditions.
SRO
- RCP status.
- Leakage within Tech Spec 3.4.13, RCS Operational Leakage limits.
- SJG and secondary plant leakage.
SRO
- 33. RETURN TO Instruction in effect.
CREW Crew Brief - conduct for this event as time allows prior to the next event. Notifications should be addressed as applicable if not specifically addressed by the procedure or in the crew brief. CREW Operations Management - Shift Manager. Maintenance Personnel-Maintenance Shift Supervisor (MSS). (Note: Maintenance notification may be delegated to the Shift Manager). Simulator operator enters Event 5 Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # _5..;;....-____ Page ~ of ...;2~5;"""-l1 Event
Description:
10 6.9 KV Unit Board Trips, resulting in the loss of the Standby MFP, 1C Hotwell Pump and 1 C #3 HDT pump. Time II Position II Applicant's Actions or Behavior Indications: 9-D 4BOV UNIT BD 1A UV/FAILUREITRANSFER 11-B 6.9 UNIT BD 10 UV/CONTROL PWR FAILURE 14-E M-1 THRU M-6 MOTOR TRIPOUT 63-F SG LEVEL DEVIATION 165-B CCW/HPFP/RCW MOTOR TRIPOUT BOP Diagnoses and announces failures. Determines that the loss of the Standby Main Feed pump is the SRO failure that must be addressed first, based on theresponse of the SG water level control system. SRO Enters and directs actions of AOI-16, "Loss of Normal Feedwater," Subsection 3.3, "Standby MFP tripwith Main Turbine in service." EXAMINER: The following actions are from AOI-16, "Loss of Normal Feedwater," Subsection 3.3, "Standby MFP trip with Main Turbine in service." SRO
- 1. IF loss of S/G level is imminent, THEN TRIP reactor, and ** GO TO E-O, Reactor Trip or Safety Injection.
SRO
- 2. IF both MFWPs in service, THEN:
Step is NIA since conditions are not met. BOP
- 3. CHECK one MFWP in service.
BOP
- 4. CHECK turbine load less than BOO MWe(67%).
BOP
- 4. RESPONSE NOT OST AINED REDUCE turbine load to within MFWP capability with valve position limiter.
RO
- 5. MONITOR reactor power controlled to match turbine power.
- 6. ENSURE adequate feed flow for existing conditions:
BOP Feed flow greater than or equal to steam flow. S/G levels returning to program.
- 7. IF reactor power dropped by greater than or equal to 15% in one SRO hour, THEN NOTIFY Chemistry to initiate power change sampling requirements.
Step is NIA since conditions are not met. B. IF C-7 LOSS OF LOAD STM DUMP INTERLOCK annunciator LIT [66E], THEN BOP
- a. ENSURE steam dump valves have zero demand.
- b. RESET loss-of-Ioad interlock with steam dump mode switch.
Step is NIA since conditions are not met. Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # 5 Page 12-- of _2::..;5~-I1 ( Event
Description:
10 6.9 KV Unit Board Trips, resulting in the loss of the Standby MFP, 1 C Hotwel! Pump and 1 C #3 HOT pump. Time II Position II Applicant's Actions or Behavior Indications: 9-D 480V UNIT BD 1A UV/FAILUREITRANSFER 11-B 6.9 UNIT BD 1 D UV/CONTROL PWR FAILURE 14-E M-1 THRU M-6 MOTOR TRIPOUT 63-F SG LEVEL DEVIATION 165-B CCW/HPFP/RCW MOTOR TRIPOUT BOP Diagnoses and announces failures. Determines that the loss of the Standby Main Feed pump is the SRO failure that must be addressed first, based on the response of the SG water level control system. SRO Enters and directs actions of AOI-16, "Loss of Normal Feedwater," Subsection 3.3, "Standby MFP trip with Main Turbine in service." EXAMINER: The following actions are from AOI-16, "Loss of Normal Feedwater," Subsection 3.3, "Standby MFP trip with Main Turbine in service." SRO
- 1. IF loss of S/G level is imminent, THEN TRIP reactor, and ** GO TO E-O, Reactor Trip or Safety Injection.
SRO
- 2. IF both MFWPs in service, THEN:
Step is NIA since conditions are not met. BOP
- 3. CHECK one MFWP in service.
BOP
- 4. CHECK turbine load less than 800 MWe (67%).
BOP
- 4. RESPONSE NOT OST AINED REDUCE turbine load to within MFWP capability with valve position limiter.
RO
- 5. MONITOR reactor power controlled to match turbine power.
- 6. ENSURE adequate feed flow for existing conditions:
BOP Feed flow greater than or equal to steam flow. S/G levels returning to program.
- 7. IF reactor power dropped by greater than or equal to 15% in one SRO hour, THEN NOTIFY Chemistry to initiate power change sampling requirements.
Step is NIA since conditions are not met.
- 8. IF C-7 LOSS OF LOAD STM DUMP INTERLOCK annunciator LIT
[66E], THEN BOP
- a. ENSURE steam dump valves have zero demand.
- b. RESET loss-of-Ioad interlock with steam dump mode switch.
Step is NIA since conditions are not met. Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # _5.;..-.____ Page.!.2..- of _2 .... 5'"--11 Event
Description:
10 6.9 KV Unit Board Trips, resulting in the loss of the Standby MFP, 1 C Hotwell Pump and 1 C #3 HDT pump. Time ~ Position II Applicant's Actions or Behavior BOP
- 9. CHECK VALVEPOS L1MITLIGHT L.rt.
- 10. REDUCE turbine load setpoint using REFERENCE CONTROLV BOP lower) AND GO button until VALVE POS LIMIT LIGHT not LIT, THEN SET valve position limiterto 95%.
SRO
- 11. RETURN TO Instruction in effect.
EXAMINER: The following actions are from ARI11-B, UNIT BD 1D UV/CONTROL PWR FAILURE. [1] IF 6.9kV Unit Bd 1 D is energized, AND motor breakers have not tripped, THEN [a] DISPATCH Operator to the board to check DC power SRO available (red indicating light lit if available). [b] IF DC power is not available, THEN REFER TO SOI-201.04, 6.9KV UNIT BOARD 10, to transfer DC to the alternate source. SRO [2] INITIATE corrective action as conditions dictate. EXAMINER: The following actions are from ARI 165-B, CCW/HPFP/RCW MOTOR TRIPOUT. BOP [1] DETERMINE which motor tripped. SRO [2] REFER TO GOI-7, Generic Equipment Operating Guidelines. (No actions are required at this point.) [3] ENSURE adequate pumps in service to replace tripped pump SRO and start additional pumps, if necessary. Since the other 3 CCW pumps are already in service, this step requires no action. SRO [4] IF a Fire Pump has tripped, THEN REFER TO Tech Specs. Step is NIA since no Fire Pump tripped. [5] IF a Raw Cooling Water Pump has tripped, THEN REFER TO SRO AOI-46, Loss of Raw Cooling Water. Step is NIA since no Raw Cooling Water pump tripped. SRO [6] NOTIFY Work Control to initiate corrective action, if necessary. Crew Brief - conduct for this event as time allows prior to the next event. CREW CREW Notifications should be addressed as applicable if not specifically addressed by the procedure or in the crew brief. Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 ( ( I Appendix 0 Required Operator Actions Form ES-O-2 I Op Test No.: NRC Scenario # 2 Event # ~5 _____ Page ~ of _2;;;.;5;""'--11 Event
Description:
10 6.9 KV Unit Board Trips, resulting in the loss of the Standby MFP, 1 C Hotwell Pump and 1 C #3 HDT pump. Time Position II Applicant's Actions or Behavior BOP
- 9. CHECK VALVE POS LIMIT LIGHT LIT.
- 10. REDUCE turbine load setpoint using REFERENCE CONTROL V' BOP lower) AND GO button until VALVE POS LIMIT LIGHT not LIT, THEN SET valve position limiter to 95%.
SRO
- 11. RETURN TO Instruction in effect.
EXAMINER: The following actions are from ARI 11-B, UNIT BD 10 UV/CONTROL PWR FAILURE. [1] IF 6.9kV Unit Bd 1 D is energized, AND motor breakers have not tripped, THEN [a] DISPATCH Operator to the board to check DC power SRO available (red indicating light lit if available). [b] IF DC power is not available, THEN REFER TO SOI-201.04, 6.9KV UNIT BOARD 10, to transfer DC to the alternate source. SRO [2] INITIATE corrective action as conditions dictate. EXAMINER: The following actions are from ARI165-B, CCW/HPFP/RCW MOTOR TRIPOUT. BOP [1] DETERMINE which motor tripped. SRO [2] REFER TO GOI-7, Generic Equipment Operating Guidelines. (No actions are required at this point.) [3] ENSURE adequate pumps in service to replace tripped pump SRO and start additional pumps, if necessary. Since the other 3 CCW pumps are already in service, this step requires no action. SRO [4] IF a Fire Pump has tripped, THEN REFER TO Tech Specs. Step is NIA since no Fire Pump tripped. [5] IF a Raw Cooling Water Pump has tripped, THEN REFER TO SRO AOI-46, Loss of Raw Cooling Water. Step is NIA since no Raw Cooling Water pump tripped. SRO [6] NOTIFY Work Control to initiate corrective action, if necessary. Crew Brief - conduct for this event as time allows prior to the next event. CREW CREW Notifications should be addressed as applicable if not specifically addressed by the procedure or in the crew brief. Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario# 2 Event # _5~ ____ Page.!Z.- of _2.....;5~-I1 Event
Description:
10 6.9 KV Unit Board Trips, resulting in the loss of the Standby MFP, 1C Hotwell Pump and 1 C #3 HDT pump. Time Position I Applicant's Actions or Behavior Operations Management - Shift Manager. Maintenance Personnel - Maintenance Shift Supervisor (MSS). (Note: Maintenance notification may be delegated to the Shift Manager). Simulator operator enters Event 6 Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 ( I Appendix 0 Required Operator Actions Form ES-O-2 I Op Test No.: NRC Scenario # 2 Event # ......;..5 _____ Page ~ of _2;;;.;5~-I1 Event
Description:
10 6.9 KV Unit Board Trips, resulting in the loss of the Standby MFP, 1C Hotwell Pump and 1 C #3 HOT pump. Time II Position II Applicant's Actions or Behavior Operations Management - Shift Manager. Maintenance Personnel - Maintenance Shift Supervisor (MSS). (Note: Maintenance notification may be delegated to the Shift Manager). Simulator operator enters Event 6 Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # _6;;;...;;;;an~d;;...7~ __ . Page 1L of ....;2;;.;5~-I1 Event
Description:
Feedwater break outside containment. 1 B MD AFW Pump shaft seizes. TD AFW Pump is steam bound. Time II Position Applicant's Actions or Behavior Indications: Makeup flow to the condenser increasing. Hotwell level decreasing. Narrow range level decreasing on ALL SGs. 168-B TURB FDN SUMP LEVEL HI BOP Diagnose and announces leak outside containment. Enters and directs actions of AOI-38,"Main Steam or Feedwater SRO Line Break." Once determination is made that the steam leak is in the Turbine Building and 'a threat to personnel, orders a reactor trip, MSIV closure and isolation of conde nsatel feed water system. EXAMINER: The following actions are from AOI-38,"Main Steam or Feedwater Line Break."
- 1. IF leak threatens personnel safety, THEN:
- a. TRIP Rx.
SRO
- b. CLOSE the following:
MSIVs. MSIV bypass valves.
- c. ** GO TO E-O, Reactor Trip or Safety Injection.
EXAMINER: The following steps are from E-O,"Reactor Trip or Safety Injection." NOTE 1 Steps 1 thru 4 are IMMEDIATE ACTION STEPS. NOTE 2 Status Trees ISPDS should be monitored when transitioned to another instruction.
- 1. ENSURE reactor trip:
Reactor trip and bypass breakers OPEN. RO RPls at bottom of scale. Neutron flux DROPPING. RO
- 2. ENSURE Turbine Trip:
All turbine stop valves CLOSED.
- 3. CHECK 6.9 kV shutdown boards:
- a. At least one board energized from:
RO CSST (offsite), OR DIG (blackout). Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 ( ( ( I Appendix 0 Required Operator Actions Form ES-O-2 I Op Test No.: NRC Scenario # 2 Event # 6 and 7 Page ~ of _2_5_...,1 Event
Description:
Feedwater break outside containment. 1 B MD AFW Pump shaft seizes. TO AFW Pump is steam bound. Time II Position II Applicant's Actions or Behavior Indications: Makeup flow to the condenser increasing. Hotwellievel decreasing. Narrow range level decreasing on ALL SGs. 168-B TURB FDN SUMP LEVEL HI BOP Diagnose and announces leak outside containment. Enters and directs actions of AOI-38,"Main Steam or Feedwater SRO Line Break." Once determination is made that the steam leak is in the Turbine Building anda threat to personnel, orders a reactor trip, MSIV closure and isolation of condensatelfeedwater system. EXAMINER: The following actions are from AOI-38,"Main Steam or Feedwater Line Break."
- 1. IF leak threatens personnel safety, THEN:
- a. TRIP Rx.
SRO
- b. CLOSE the following:
MSIVs. MSIV bypass valves.
- c. ** GO TO E-O, Reactor Trip or Safety Injection.
EXAMINER: The following steps are from E-O,"Reactor Trip or Safety Injection." NOTE 1 Steps 1 thru 4 are IMMEDIATE ACTION STEPS. NOTE 2 Status Trees I SPDS should be monitored when transitioned to another instruction.
- 1. ENSURE reactor trip:
Reactor trip and bypass breakers OPEN. RO RPls at bottom of scale. Neutron flux DROPPING. RO
- 2. ENSURE Turbine Trip:
All turbine stop valves CLOSED.
- 3. CHECK 6.9 kV shutdown boards:
- a. At least one board energized from:
RO CSST (offsite), OR DIG (blackout). Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
I Appendix 0 Op Test No.: Event
Description:
Required Operator Actions Form ES-D-2 I NRC Scenario # 2 Event # _6 _an_d_7 ___ Page.1L of _2_5_-11 Feedwater break outside containment. 1 B MD AFW Pump shaft seizes. TO AFW Pump is steam bound. Time II Position II Applicant's Actions or Behavior
- 4. CHECK SI actuated:
- a. Any SI annunciator LIT.
RO
- b. Both trains SI ACTUATED.
- 1-XX-55-6C
- 1-XX-55-60
- 4. RESPONSE NOT OBTAINED: DETERMINE if SI required:
- a. IF ANY of the following exists:
- S/G press less than 675 psig, OR RO
- RCS press less than 1870 psig, OR
- Cntmt press greater than 1.5 psig THEN ACTUATE SI manually. IFSI NOT required, THEN GO TO ES-0.1, Reactor Trip Response.
SRO Transitions to ES-0.1, "REACTOR TRIP RESPONSE". SRO Assigns Status Tree Performance to Surrogate ST A. EXAMINER: The following steps are from ES-O.1, "REACTOR TRIP RESPONSE." CAUTION Plant conditions, AFW pump start signals and flow requirements should be evaluated as time allows.
- 1. MONITOR SI actuation criteria:
SRO
- IF SI actuation occurs during the performance of this Instruction, THEN ** GO TO E-O, Reactor Trip or Safety Injection.
BOP
- 2. CHECK Generator PCBs OPEN.
- 3. MONITOR RCS temperature stable at or trending to 55rF:
- IF any RCP running, THEN MONITOR RCS Loop T-avg trending to 5SrF.
OR RO
- IF NO RCP running, THEN MONITOR RCS Loop T-cold trending to 55rF.
Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 ( ( I Appendix D Op Test No.: Event
Description:
Required Operator Actions Form ES-D-2 I NRC Scenario # 2 Event # _6;;...;;;;an;.;.;d;;..7~ __ Page 1.L of ....;2;;;.;5~-I1 Feedwater break outside containment. 1 B MD AFW Pump shaft seizes. TO AFW Pump is steam bound. Time II Position II Applicant's Actions or Behavior
- 4. CHECK SI actuated:
- a. Any SI annunciator LIT.
RO
- b. Both trains SI ACTUATED.
- 1-XX-55-6C
- 1-XX-55-60
- 4. RESPONSE NOT OBTAINED: DETERMINE if SI required:
- a. IF ANY of the following exists:
- S/G press less than 675 psig, OR RO
- RCS press less than 1870 psig, OR
- Cntmt press greater than 1.5 psig THEN ACTUATE SI manually. IF SI NOT required, THEN GO TO ES-0.1, Reactor Trip Response.
SRO Transitions to ES-0.1, "REACTOR TRIP RESPONSE". SRO Assigns Status Tree Performance to Surrogate ST A. EXAMINER: The following steps are from ES-O.1, "REACTOR TRIP RESPONSE." CAUTION Plant conditions, AFW pump start signals and flow requirements should be evaluated as time allows.
- 1. MONITOR SI actuation criteria:
SRO
- IF SI actuation occurs during the performance of this Instruction, THEN ** GO TO E-O, Reactor Trip or Safety Injection.
BOP
- 2. CHECK Generator PCBs OPEN.
- 3. MONITOR RCS temperature stable at or trending to 55rF:
- IF any RCP running, THEN MONITOR RCS Loop T-avg trending to 55rF.
OR RO
- IF NO RCP running, THEN MONITOR RCS Loop T-cold trending to 55rF.
Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
I Appendix 0 Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 2 Event # _6;;...;;;;an~d;...;7~ __ Page ~ of _2_5 __ -11 Event
Description:
Feedwater break outside containment. 1 B MD AFW Pump shaft seizes. TO AFW Pump is steam bound. Time Position Applicant's Actions or Behavior
- 4. ENSURE AFW operation:
- a. AFW established:
- Both MD AFW pumps RUNNING.
BOP
- TD AFW pump RUNNING.
- LCVs in AUTO or controlled in MANUAL.
- b. Heat sink available:
- Total feed flow greater than 410 gpm, OR
- At least one S/G NR level greaterthan29%.
- 4. RESPONSE NOT OBTAINED SRO
- a. ESTABLISH feed flow from AFW or MFW as necessary.
. b. IF heat sink can NOT be established, THEN ** GO TO FR-H.1, Loss Of Secondary Heat Sink. SRO Transitions to FR-H.1, "LOSS OF SECONDARY HEAT SINK". Note: Crew may trip the TDAFW pump as a precautionary measure. Not required by procedure. EXAMINER: The following steps are from FR-H.1, "LOSS OF SECONDARY HEAT SINK." CAUTION Iftotal feed flow CAPABILITY of 410 gpm is available, this Instruction should NOT be performed. If an Intact S/G is available, feed flow should NOT be reestablished to any faulted S/G. 1. CHECK if secondary heat sink is required: SRO
- a. RCS pressure greater than any Intact S/G pressure.
- b. RCS temperature greater than 375°F [360°F ADV].
SRO
- 2. ENSURE at leastone charging pump RUNNING.
CAUTION RCS bleed and feed criteria must be monitored for immediate response if the criteria is exceeded.
- 3. DETERMINE if RCS bleed and feed required:
- a. CHECK RCS bleed and feed required:
SRO
- AnyTHREE S/G WR levels less than or equal to 26% [36%
ADV]. OR j"
- RCS pressure greater th;:m or equal to 2335 psig.
Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9* ( I \\, I Appendix 0 Op Test No.: Event
Description:
Required Operator Actions Form ES-O-2 I NRC Scenario # 2 Event # 6 and 7 Page ~ of _2;;;.;5;....-..~1 Feedwater break outside containment. 1 B MD AFW Pump shaft seizes. TD AFW Pump is steam bound. I Time II Position II Applicant's Actions or Behavior
- 4. ENSURE AFW operation:
- a. AFW established:
- Both MD AFW pumps RUNNING.
BOP
- TD AFW pump RUNNING.
- LCVs in AUTO or controlled in MANUAL.
- b. Heat sink available:
- Total feed flow greater than 410 gpm, OR
- At least one S/G NR level greater than 29%.
- 4. RESPONSE NOT OBTAINED SRO
- a. ESTABLISH feed flow from AFW or MFW as necessary.
- b. IF heat sink can NOT be established, THEN ** GO TO FR-H.1, Loss Of Secondary Heat Sink.
SRO Transitions to FR-H.1, "LOSS OF SECONDARY HEAT SINK". Note: Crew may trip the TDAFW pump as a precautionary measure. Not required by procedure. EXAMINER: The following steps are from FR-H.1, "LOSS OF SECONDARY HEAT SINK." CAUTION If total feed flow CAPABILITY of 410 gpm is available, this Instruction should NOT be performed. If an Intact S/G is available, feed flow should NOT be reestablished to any faulted S/G.
- 1. CHECK if secondary heat sink is required:
SRO
- a. RCS pressure greater than any Intact S/G pressure.
- b. RCS temperature greater than 375°F [360°F ADV].
SRO
- 2. ENSURE at least one charging pump RUNNING.
CAUTION RCS bleed and feed criteria must be monitored for immediate response if the criteria is exceeded.
- 3. DETERMINE if RCS bleed and feed required:
- a. CHECK RCS bleed and feed required:
SRO
- Any THREE S/G WR levels less than or equal to 26% [36%
ADV]. OR
- RCS pressure greater than or equal to 2335 psig.
Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
I Appendix D Op Test No.: Event
Description:
Required Operator Actions Form ES-D-2 I NRC Scenario # 2 Event # _6;;..;;;;an~d;;...;7~ __ Page ~ of ....;2;;;.;5~-I1 Feedwater break outside containment. 1 B MD AFW Pump shaft seizes. TD AFW Pump is steam bound. Time II Position II Applicant's Actions or Behavior 3.a. RESPONSE NOT OBTAINED SRO
- a. MONITOR RCS bleed and feed criteria: WHEN criteria are met,
. THEN PERFORM Substep 3b.
- GO TO step 4.
- 4. ENSURE S/G blowdown ISOLATED.
BOP
- 5. MONITOR CST volume greater than 200,000 gal.
NOTE If the use of condensate flow is anticipated, then a higher pzr level will better accommodate the level shrink from S/G cooldown and depressurization. RO
- 6. CONTROL pzr levelbetween 29% and 63% [47% and 58%
ADV].
- 7. ESTABLISH MD AFW pump flow:
BOP Based on reports from the field, the MD AFW pumps will not be available for use in the near term. The SRO may direct the BOP to address this step, while FR-H.1 performance continues. CRITICAL TASK (prior to BOP
- 8. ESTABLISH TD AFW pump flow:
bleed and feed) EXAMINER: Based on reports from the field, the TDAFW pump is steam bound. Approximately 5 minutes after the TDAFW pump is shutdown to support venting, the AUO will report back to the control room that venting was successful, and the SRO will direct the BOP to feed SGs using the TDAFW pump. After AFW flow is established, TERMINA TE the scenario. Actions will continue per FR-H.1 until TD AFW pump is vented. See back of this Scenario Guide for detailed steps on venting the TD AFW pump. RO
- 9. STOP all four RCPs.
- 10. IF Secondary pumps will be used to feed S/Gs; THEN REFER BOP TO Appendix A (FR-H.1), Establishing MFW following Reactor Trip, while continuing this Instruction.
CAUTION
- If offsite power is lost after 51 reset, manual action will be required to restart the 51 pumps and RHR pumps due to loss of 51 start signal.
- If plant conditions degrade after automatic 51 is blocked, manual actuation may be required.
NOTE After the low steam line pressure 51 signal is blocked, main steamline isolation will occur if the high steam pressure rate setpoint is exceeded. RO
- 11. BLOCK SI signals:
Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 ( \\ ( ( I Appendix 0 Op Test No.: Event
Description:
Required Operator Actions Form ES-O-2 I NRC Scenario # 2 Event # 6 and 7 Page ~ of _2_5_-11 Feedwater break outside containment. 1 B MD AFW Pump shaft seizes. TO AFW Pump is steam bound. Time II Position II Applicant's Actions or Behavior 3.a. RESPONSE NOT OBTAINED SRO
- a. MONITOR RCS bleed and feed criteria: WHEN criteria are met, THEN PERFORM Substep 3b.
- GO TO step 4.
- 4. ENSURE S/G blowdown ISOLATED.
BOP
- 5. MONITOR CST volume greater than 200,000 gal.
NOTE If the use of condensate flow is anticipated, then a higher pzr level will better accommodate the level shrink from S/G cooldown and depressurization. RO
- 6. CONTROL pzr level between 29% and 63% [47% and 58%
ADV].
- 7. ESTABLISH MD AFW pump flow:
BOP Based on reports from the field, the MD AFW pumps will not be available for use in the near term. The SRO may direct the BOP to address this step, while FR-H.1 performance continues. CRITICAL TASK (prior to BOP
- 8. ESTABLISH TO AFW pump flow:
bleed and feed) EXAMINER: Based on reports from the field, the TDAFW pump is steam bound. Approximately 5 minutes after the TDAFW pump is shutdown to support venting, the AUO will report back to the control room that venting was successful, and the SRO will direct the BOP to feed SGs using the TDAFW pump. After AFW flow is established, TERMINA TE the scenario. Actions will continue per FR-H. 1 until TD AFW pump is vented. See back of this Scenario Guide for detailed steps on venting the TD AFW pump. RO
- 9. STOP all four RCPs.
- 10. IF Secondary pumps will be used to feed S/Gs, THEN REFER BOP TO Appendix A (FR-H.1), Establishing MFW following Reactor Trip, while continuing this Instruction.
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.
- If plant conditions degrade after automatic SI is blocked, manual actuation may be required.
NOTE After the low steamline pressure SI signal is blocked, main steamline isolation will occur if the high steam pressure rate setpoint is exceeded. RO
- 11. BLOCK SI signals:
Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
I Appendix D Op Test No.: Event
Description:
Required Operator Actions Form ES-D-2 I NRC Scenario # 2 Event # ......;..6..;.;.an;,;..d;...7 ___ Page ~ of _2;...5'---11 Feedwater break outside containment. 1 B MD AFW Pump shaft seizes. TO AFW Pump is steam bound. Time II Position II Applicant's Actions or Behavior
- a.
INITIATE RCS depressurization to less than 1912 psig: IF letdown in service, THEN ALIGN aux spray USING Appendix B (FR-H.1), ALIGN AUX SPRAY. EXAMINER: The following steps are from FR-H.1, "LOSS OF SECONDARY HEAT SINK," Appendix B, "Align Aux Spray." RO
- 1. ENSURE at least one charging pump running.
- 2. IF charging is not aligned, THEN ALIGN charging:
RO a) CLOSE RCP seal flow controI1-FCV-62-89. b) OPEN charging isolation 1-FCV-62-90 and 1-FCV-62-91. c) ENSURE charging 1-FCV-62-85 or 1-FCV-62-860PEN. CAUTION If RCS is on cold leg recirc, seal return isolation valves should not be opened (prevents sump inventory from diverting to VCT). d) OPEN seal return 1-FCV-62-61 and 1-FCV~62-63. RO
- 3. ENSURE BIT outlet valves 1-FCV-63-25 AND 1-FCV-63-26 CLOSED.
NOTE Aux spray flow can be maximized by closing the normal pzr spray valve(s).
- 4. CONTROL aux spray flow:
a) OPEN aux spray 1-FCV-62-84. b) CLOSE charging 1-FCV-62-85 and 1-FCV-62-86. RO c) MODULATE Pzr Spray valves as needed to control Pzr pressure. d) ADJUST aux spray flow rate with 1-FCV-62-93 and 1-FCV 89 as needed. END OF SCENARIO >>.c ~ i c..... Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 ( ( I Appendix D Op Test No.: Event
Description:
Required Operator Actions Form ES-D-2 I NRC Scenario # 2 Event # ....;;..6.;..a;.;..nd;;..7~ __ Page ~ of _2;;;;.;5~-I1 Feedwater break outside containment. 1 B MD AFW Pump shaft seizes. TD AFW Pump is steam bound. Time II Position II Applicant's Actions or Behavior
- a.
INITIATE RCS depressurization to less than 1912 psig: IF letdown in service, THEN ALIGN aux spray USING Appendix B (FR-H.1), ALIGN AUX SPRAY. EXAMINER: The following steps are from FR-H.1, "LOSS OF SECONDARY HEAT SINK," Appendix B, "Align Aux Spray." RO
- 1. ENSURE at least one charging pump running.
- 2. IF charging is not aligned, THEN ALIGN charging:
RO a) CLOSE RCP seal flow controI1-FCV-62-89. b) OPEN charging isolation 1-FCV-62-90 and 1-FCV-62-91. c) ENSURE charging 1-FCV-62-85 or 1-FCV-62-86 OPEN. CAUTION If RCS is on cold leg recirc, seal return isolation valves should not be opened (prevents sump inventory from diverting to VCT). d) OPEN seal return 1-FCV-62-61 and 1-FCV-62-63. RO
- 3. ENSURE BIT outlet valves 1-FCV-63-25 AND 1-FCV-63-26 CLOSED.
NOTE Aux spray flow can be maximized by closing the normal pzr spray valve(s).
- 4. CONTROL aux spray flow:
a) OPEN aux spray 1-FCV-62-84. b) CLOSE charging 1-FCV-62-85 and 1-FCV-62-86. RO c) MODULATE Pzr Spray valves as needed to control Pzr pressure. d) ADJUST aux spray flow rate with 1-FCV-62-93 and 1-FCV 89 as needed. END OF SCENARIO Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
WBN Boron Concentration Control SOI-62J12 Unit1 Rev. 0048 PaQe 29 of 62 Date INITIALS '6.7 Minor Boration NOTES
- 1)
Section 6.1, Minor Boration, may be reproduced, laminated, displayed, reused, etc. as desired.
- 2)
Minor Boration is defined as the addition of Boric Acid done se..... eral times each shift early in core life, to compensate for burnable poisofl bum-up, and maintain Tav9 on program. (1J ENSURE 1-HS-68-341H, BACKUP HEATER C (1-M-4], is ON, to equalize RCS-pzr Ca. D (2] ADJUST 1-FC-62-139, BATO BLENDER [1-M-6], for desired flow rate. D (3] ADJUST 1-FQ-62-139, BA BATCH COUNTER [1-M-6], for required quantity_ D (4] PLACE 1-HS-62-140B, VCT MAKEUP MODE [1-M-6], in BOR D [5] TURN 1-HS-62-140A, VCT MAKEUP CONTROL [1-M-6], to START. D [5.1] CHECK Red light is LIT. D [6] MONITOR the following parameters: Instrument Location Parameters 1-PI-62-122 1-M-6 VCTPRESS 1-Ll-62-129A 1-M-6 VCT LEVEL 1-FI-62-139 1-M-6 BA TO BLENDER fLOW 1-FQ-62-139 1-M-6 BA BATCH COUNTER 1-FI-62-142 1-M-6 PW TO BLENDER FLOW 1-FQ-62-142 1-M-6 PW BATCH COUNTER 1-U-62-238 1-M-6 BAT A LEVEL 1-U-62-242 1-M-6 BAT C LEVEL [7] IF DESIRED to flush affected piping, THEN PERFORM Section 6.3. D [8] WHEN Boration is COMPLETE, THEN PLACE 1-HS-62-140B, VCT MAKEUP MODE, in AUTO. D (9] TURN 1-HS-62-140A, VCT MAKEUP CONTROL, to START. D (9.1] CHECK Red light is LIT. D Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 ( WBN Boron Concentration Control 501-*62.02 Unit 1 Rev. 0048 Page 29 of 62 Date INITIALS £.7 Minor Bomtion NOTES Section 6,7,.Minor Boration, may' be reproduced, laminated, display'ed, feused, etc. as desired.
- 2)
Minor Bor3tion is defined as the addition of Boric,/l,cid done several times each shift earl}' ill core life, to compensate for burnable poison burn-LIp, and maintain Ta\\{g on
- program, (2]
[3] HlSURE 1-HS-l38-341H, BACKUP HEATER C ['1-M-4]. is ON. to equalize RCS-Pzr C3, ADJUST 'I-FC-52-139, SA. TO BLENDER [1-M-5], for desired fli)',/\\{ ra te. ADJUST 'l-FQ-52-139. BA BATCH COUNTER ['i-M-6]. for required quantity. PLACE 1-HS-52-14C1B, \\/CT MA.KEUP MODE ['l-M-51, in BOR TURN 'l-HS-62-140,A.,VCT MAKEUP CONTROL ['I-M-6]. to START, [50,1] CHECK Red light is LIT, [6] MONITOR the following parameters: Instrument Location Parameters '1-PI-62-122 'l-M-6 \\/CT PRESS 1-U-62-'129.,c", 1-M-6 VCT LEVEL 1-FI-62-139 'l-M-6 Bf.!, TO SLENDER FlO'I' 1-FQ-62-H9 "-M-6 Bf.!. BA.TCH COUNTER 1-FI-52-142 1-M-6 PV'l TO BLENDER FLOV" 1-FQ-62-'142 'l-M-6 PV'", B.ATCH COUNTER 1-U-62-238 I-M-6 BA T A LE\\lEL 1-U-62-242 1-M-6 B,A,T C LE\\fEL [7] IF DESIRED to flush affected piping, THEN PERFORMSectiofi 6.3. ra] WHEN Boration is COMPLETE, THEN PLACE '1-HS-62-140B, \\fCT MAKEUP MODE, in AUTO, (9] TURN 1-HS-62-'140A, VCT ',AAKEUP CONTROL, to START, (9,1] CHECK Fl,ed light is LIT, D D D D D D D D D D Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
( Venting of TD AFW Pump Examiner: Only the applicable sections of 501-3.02 for the Turbine Driven Aux. Feed Pump are included here. WBN Auxiliary Feedwater System SOI-l.02 Unit 1 Rev. 0046 Palle 55 of 92 Date __ Initials 8.1 Venting of A'iW Pumps Source Notes 1,2,4,6,7 applies to this section. WARNINGS
- 1)
The AFW pumps may start at any time, without waming.
- 2)
Keep dear of the pumps' shafts and other moving parts while venting the pumps.
- 3)
Water will spray from the vent line if the pump stans while venting.
- 4)
Be prepared to close the vent valve at all times during the venting process. CAUTION Radioactive steam may be present when venting AFW pumps. NOTE IF venting due to vapor binding, it may also be: necessary to vent AFW Pump Discharge Header to ensure system is returned to Standby condition. Unused portions of this section may be III/A'd. (1] NOTIFY RADCON of possible radiological hazards. Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 ( ( f ~. Venting of TO AFW Pump Examiner: Only the applicable sections of 501-3.02 for the Turbine Driven Aux. Feed Pump are included here. WBN Auxiliary Feedwater System SOI-3.02 Unit 1 Rev. 0046 Page 55 of 92 Date Initials 8.7 Venting of AFW Pumps Source Notes 12,4,6,7 applies to this section. WARNINGS I') The AF'N pumps may start at any time, 'Nithout ',',farning.
- 2)
Keep clear of the pumps' shafts and other moving parts \\.vhile venting the pumps,
- 3)
"/'v'ater v,iill spray from the vent line if the pump starts... :hile venting.
- 4)
Be prepared to close the..... ent valve at all times during the venting process. CAUTION Radioacti\\le stearn may be present 'Nhef1 venting AFV'I pumps. NOTE IF venting due to vapor binding. it may also be necessary to vent,AF'."'" Pump Disc.harge Header to ensure s'y'stem is returned to Standby condition. Unused portions of this section may be N/A'd. [1] NOTiFY RADCOt\\) of possible radiological hazards. Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
( WBN Auxiliary FeedwaterSystem 501-3.02 Unit 1 Rev. 0046 Page 56 of 92 Date --- 8.7 Venting of AFW Pumps (continued) [3.3] WHEN solid stream of water exists, THEN CLOSE 1-VTV-3-932, AUX FEEDWATER PMP 1 B-B CASING VENT. [3.4] NOTIFY UO that AFW PUMP 1 B-B vented. Initials IV ( ( ( WBN Auxiliary FeedwaterSystem 501-3.02 Unit 1 Rev. 0046 Page 56 of 92 Date --- 8.7 Venting of AFW Pumps (continued) [3.3] WHEN solid stream of water exists, THEN CLOSE 1-VTV-3-932, AUX FEEDWATER PMP 1 B-B CASING VENT. [3.4] NOTIFY UO that AFW PUMP 1 B-B vented. Initials IV
WBN Auxiliary Feedwater System SOI-3.02 Unit 1 Rev. 0046 Page 51 of 92 Date ---- 8.7 Venting *of AFW Pumps (continued} (4] PERFORM the follmi'Jing to vent TO A,P.N* Pur*/IP [A.3TI692}: 1] Appendix D NOTIFY UO of intention to vent TO AFVI/ PUMP. OPEN 1-\\lTV-3-930, TO. AUX FEED'NATER PUMP CASING VENT. WHEN so!.id stream of water exists, THEN CLOSE 1-VTV-3-930, T.D. AUX FEEDl.IVATER pm..1p CASI~,jG \\lENT. NOTIFY UO that TD AFVV PUMP \\iented. Watts Bar NRC Exam November 2009 Initials IV NUREG 1021 Revision 9 ( ( ( WBN Auxiliary Feedwater System SOI-3.02 IJ nit 1 Rev. 0046 Page 57 of 92 Date --- 8.7 Venting of AFW Pumps (continued) Appendix D PERFORM the follmving to vent TO A,F\\/!/ PUl*." P [A.3Tf692}: '1] NOTIFY UO of intention to vent TDA.F"l,l PUMP. [4.21 OPEN 1-VT'I-3-930, 1.0.,AJJX FEED'NATER PUMP CASING VENT. [4.31 WHEN solid stream of water exists, THEN CLOSE 1-\\/TV-3-930, T.D. AUX FEEOINATER PUMP CASING \\iENT. NOTIFY UO that TD AFVV PUMP vented. Watts Bar NRC Exam November 2009 Initials IV NUREG 1021 Revision 9
SHIFT TURNOVER CHECKLIST age 0 P 1 f2 SHIFT TURNOVER CHECKLIST Page ___ of -- 0 SM ~ US/MCR Unit 0 UO Unit Off-going - Name 0 AUO Station 0 STA (STA Function) On-coming - Name Part 1 - Completed by off-going shiftlReviewed by on-coming shift: Abnonnal equipment lineup/conditions: lA MD AFW PumE tagged for pump bearing reElacement. Tech SEec 3.7.5.b was entered 6 hours ago. Expected return-to-service in 16 hours. SI/Test in progress/planned: (including need for new brief) Major Activities/Procedures in progress/planned: The pre-conditioned power level is 96%. The unit is returning to power following 1-B MFP triE 8 hours ago. Power escalation to 95% is in progress. Continue power escalation Train A Week ChannelL Perfonn load escalation using Reactivity Plan provided by Reactor Engineering. Currently at Step 40 of GO-4 Section 5.2, "Unit Startup from 30% to 100% Reactor Power. Control Bank D at 193 Steps. RCS boron is 951 PEm. Train A Week ChannelL Radiological changes in plant during shift: Part 2 - Performed by on-coming shift 0 A review of the Operating Log since last held shift or 3 days, whichever is less (N/ A for AUOs) 0 A review of the Rounds sheets/Abnonnal readings (AUOs only) Review the following programs for changes since last shift turnover: 0 Standing Orders 0 LCO(s) in actions (N/A for AUOs) 0 PER review 0 hmnediate required reading 0 TACF (N/A for AUOs) (N/A for AUOs) Part 3 - Performed by both off-going and on-coming shift 0 A walkdown of the MCR control boards (N/A for AUOs) Relief Time: Relief Date: TVA 40741 [06-2008] Page 1 of 1 OPDP-I-I [06-12-2008] SHIFT TURNOVER CHECKLIST ( P 1 f2 age 0 SHIFT TURNOVER CHECKLIST Page of 0 SM ~ US/MCR Unit 0 UO Unit Off-going - Name 0 AUO Station 0 STA (STA Function) On-coming - Name Part 1 - Completed by off-going shiftlReviewed by on-coming shift: Abnonnal equipment lineup/conditions: lA MD AFW Pump tagged for pump bearing replacement. Tech S,rec 3.7.5.b was entered 6 hours ago. Expected return-to-service in 16 hours. SIITest in progress/planned: (including need for new brief) Major Activities/Procedures in progress/planned: The pre-conditioned power level is 96%. The unit is returning to power following 1-B MFP tri,r 8 hours ago. Power escalation to 95% is in progress. Continue power escalation Train A Week Channel I. Perlonn ( load escalation using Reactivity Plan provided by Reactor Engineering. Currently at Step 40 of GO-4 Section 5.2, "Vnit Startup from 30% to 1 00% Reactor Power. Control Bank D at 193 Steps. RCS boron is 951 ppm. Train A Week Channel I. Radiological changes in plant during shift: Part 2 - Performed by on-coming shift 0 A review of the Operating Log since last held shift or 3 days, whichever is less (N/ A for AVOs) 0 A review of the Rounds sheets/Abnonnal readings (AVOs only) Review the following programs for changes since last shift turnover: 0 Standing Orders 0 LCO(s) in actions (N/A for AUOs) 0 PER review 0 limnediate required reading 0 TACF (N/A for AVOs) (N/A for AUOs) Part 3 - Performed by both off-going and on-coming shift 0 A walkdown of the MCR control boards (N/A for AUOs) Relief Time: Relief Date: TVA 40741 [06-2008] Page 1 of 1 OPDP-l-l [06-12-2008]
SHIFT TURNOVER CHECKLIST P 2 f2 age 0 SHIFT TURNOVER CHECKLIST Page ___ of -- 0 SM 0 USIMCR Unit ~ UO Unit Off-going - Name 0 AUO Station 0 STA (STA Function) On-coming - Name Part 1 - Completed by off-going shiftlReviewed by on-coming shift: Abnonnal equipment lineup/conditions: lA MD AFW PumE tagged for pumE bearing replacement. Tech SEec 3.7.5.b was entered 6 hours ago. EXEected retum-to-service in 16 hours. SVTest in progress/planned: (including need for new brief) Major ActivitieslProcedures in progress/planned: The Ere-conditioned Eower level is 96%. The unit is returning to Eower following I-B MFP triE 8 hours ago. Power escalation to 95% is in Ero~ess. Continue power escalation Train A Week Channel I. Perfonn load escalation using Reactivity Plan Erovided by Reactor Engineering. Currentl~ at SteE 40 of 00-4 Section 5.2, "Unit Startup from 30% to 100% Reactor Power. Control Bank D at 193 Steps. RCS boron is 951 E}2m. Train A Week Channel I. Radiological changes in plant during shift: Part 2 - Performed by on-coming shift 0 A review of the Operating Log since last held shift or 3 days, whichever is less (N/A for AUOs) 0 A review of the Rounds sheets/Abnonnal readings (AUOs only) Review the following programs for changes since last shift turnover: 0 Standing Orders 0 LCO(s) in actions (N/A for AUOs) 0 PER review 0 Immediate required reading 0 TACF (N/A for AUOs) (N/A for AUOs) Part 3 - Performed by both off-going and on-coming shift 0 A walkdown oftheMCR control boards (N/A for AUOs) Relief Time: Relief Date: TVA 40741 [06-2008] Page 1 'of 1 OPDP-1-1 [06-12-2008] SHIFT TURNOVER CHECKLIST P 2 f2 age 0 ( SHIFT TURNOVER CHECKLIST Page ___ of -- D SM D US/MCR Unit rgj UO Unit Off-going - Name D AUO Station D STA (STA Function) On-coming - Name Part 1 - Completed by off-going shiftlReviewed by on-coming shift: Abnormal equipment lineup/conditions: lA MD AFW Pump tagged for rump bearing r~lacement. Tech Spec 3.7.5.b was entered 6 hours ago. Expected return-to-service in 16 hours. SVTest in progress/planned: (including need for new brief) Major Activities/Procedures in progress/planned: The pre-conditioned power level is 96%. The unit is returning to power following I-B MFP triE 8 hours ago. Power escalation to 95% is in progress. Continue power escalation Train A Week ChannelL Perfonn load escalation using Reactivity Plan provided by Reactor Engineering. Currently at Step 40 of GO-4 Section 5.2, "Unit Startup from 30% to 100% Reactor Power. Control Bank D at 193 Steps. RCS boron is 951 Epm. Train A Week ChannelL Radiological changes in plant during shift: Part 2 - Performed by on-coming shift D A review ofthe Operating Log since last held shift or 3 days, whichever is less (N/A for AUOs) D A review ofthe Rounds sheets/Abnormal readings (AUOs only) Review the following programs for changes since last shift turnover: D Standing Orders D LCO(s) in actions (N/A for AUOs) D PER review D Immediate required reading D TACF (N/A for AUOs) (N/A for AUOs) Part 3 - Performed by both off-going and on-coming shift D A walkdown ofthe MCR control boards (N/A for AUOs) Relief Time: Relief Date: TVA 40741 [06-2008] Page 1 of 1 OPDP-l-l [06-12-2008]
I Appendix 0 Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 3 Event # _5~ ____ Page..12.- of ...:2;;;.4~-I1 Event
Description:
Steam Generator Pressure transmitter 1-PT-1-9A fails LOW. BOP takes manual control of #3 SG main feed water regulating valve to control level. Enters AOI-16. Tech Spec Evaluation. Time II Position II Applicant's Actions or Behavior 62-C SG 3 STM-FW FLOW MISMATCH 118-A SG 3 PRESS LO 122-A SG 3 PRESS NEG RATE 58-B SG FEEDWATER FLOW HI BOP Diagnose and announce failure of SG#3 steam pressure transmitter low. BOP May place SG #3 main feed water regulating valve in MANUAL to return SG level to normal as a PRUDENT OPERATOR ACTION. May place main feed water pump MASTER CONTROLLER in BOP MANUAL to prevent MFPs from slowing down due to failed input to the speed control program as a PRUDENT OPERATOR ACTION, SRO Enter and direct actions of AOI-16, "Loss of Normal Feedwater," Sub Section 3.6, "MFW reg or bypass reg valve control failure." EXAMINER: The following actions are from AOI-16, Sub Section 3.6. BOP
- 1. CONTROL failed MFW reg or bypass reg valve in MANUAL.
SRO
- 2. EVALUATE placing control rods in MANUAL.
NOTE If the main reg. valve is malfunctioning, the bypass reg. valve for the affected loop may be manually positioned as necessary up to 0.85 x 106 Iblhr flow to dampen oscillations in feedwater flow. A power tilt in the affected core quadrant may occur due to a rise in bypass flow. Flows above 84,500 Ibmlhr in the bypass line will invalidate the value of computer point U1118. BOP
- 3. CHECK SG levels on bypass reg valve control.
SRO
- 3. RESPONSE NOT ost AINED ** GO TO Step 5.
BOP
- 5. CHECK S/G levels returning to PROGRAM.
BOP
- 6. MONITOR TDMFW Pump speed normal for current power level.
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 Ib/hr.
- 7. WHEN any S/G MFW flow drops to less than 0.55 x 106Ib/hr, THEN INITIATE manual anti-water hammer actions:
SRO Anti-water hammer actions are not required for the failure in progress - N/A. CAUTION Power range N41 controls SIG 1 and SIG 4 MFW reg valves. N42 controls SIG 2 and SIG 3 MFW reg valves. NOTE All power range monitors input to auctioneered high anticipatory circuit for bypass FW reg valves. Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 ( ( I Appendix 0 Required Operator Actions Form ES-O-2 I Op Test No.: NRC Scenario # 3 Event # _5,;;..-. ____ Page ~ of _2;;..4~-I1 Event
Description:
Steam Generator Pressure transmitter 1-PT-1-9A fails LOW. BOP takes manual control of#3 SG main feed water regulating valve to control level. Enters AOI-16. Tech Spec Evaluation. Time Position Applicant's Actions or Behavior 62-C SG 3 STM-FW FLOW MISMATCH 118-A SG 3 PRESS LO 122-A SG 3 PRESS NEG RATE 58-B SG FEEDWATER FLOW HI BOP Diagnose and announce failure of SG #3 steam pressure transmitter low. BOP May place SG #3 main feed water regulating valve in MANUAL to return SG level to normal as a PRUDENT OPERATOR ACTION. May place main feed water pump MASTER CONTROLLER in BOP MANUAL to prevent MFPs from slowing down due to failed input to the speed control program as a PRUDENT OPERATOR ACTION. SRO Enter and direct actions of AOI-16, "Loss of Normal Feedwater," Sub Section 3.6, "MFW reg or bypass reg valve control failure." EXAMINER: The following actions are from AOI-16, Sub Section 3.6. BOP
- 1. CONTROL failed MFW reg or bypass reg valve in MANUAL.
SRO
- 2. EVALUATE placing control rods in MANUAL.
NOTE If the main reg. valve is malfunctioning, the bypass reg. valve for the affected loop may be manually positioned as necessary up to 0.85 x 106 Ib/hr flow to dampen oscillations in feedwater flow. A power tilt in the affected core quadrant may occur due to a rise in bypass flow. Flows above 84,500 Ibm/hr in the bypass line will invalidate the value of computer point U1118. BOP
- 3. CHECK SG levels on bypass reg valve control.
SRO
- 3. RESPONSE NOT OBTAINED ** GO TO Step 5.
BOP
- 5. CHECK S/G levels returning to PROGRAM.
BOP
- 6. MONITOR TDMFW Pump speed normal for current power level.
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 1061b/hr.
- 7. WHEN any S/G MFW flow drops to less than 0.55 x 106Ib/hr, THEN INITIATE manual anti-water hammer actions:
SRO Anti-water hammer actions are not required for the failure in progress - N/A. CAUTION Power range N41 controls S/G 1 and S/G 4 MFW reg valves. N42 controls S/G 2 and S/G 3 MFW reg valves. NOTE All power range monitors input to auctioneered high anticipatory circuit for bypass FW reg valves. Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
( \\ I Appendix D Op Test No.: Event
Description:
Required Operator Actions Form ES-D-2 I NRC Scenario # 3 Event # ....;..5 _____ Page _11_ of _2;;;..4~-I1 Steam Generator Pressure transmitter 1-PT-1-9A fails LOW. BOP takes manual control of #3 SG main feed water regulating valve to control level. Enters AOI-16. Tech Spec Evaluation. Time II Position II Applicant's Actions or Behavior RO
- 8. CHECK power range N41 through N44 NORMAL.
NOTE Steps 7 & 8 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 anyone channel will have minimal effect on the affected S/G level. BOP
- 9. CHECK controlling steam flow Channels NORMAL.
- 9. RESPONSE NOT OBTAINED
- a.
SELECT operable channel. BOP
- b.
EVALUATE effect of the failed channel on the MFPs Speed Control and ADJUST in MANUAL as necessary while continuing this section. BOP
- 10. CHECK controlling FW flow channels NORMAL.
BOP
- 11. CHECK press compensation channel(s) NORMAL.
- 11. RESPONSE NOT OBTAINED REFER TO Tech Specs:
3.3.2 Function 1.e, Steam Line Pressure -Low, Condition D With one channel inoperable, place the channel in trip within 72 hours OR be in Mode 3 within 78 hours AND mode 4 within 84 hours. Function 4.d (1) Steam Line Pressure - Low, Condition D With SRO one channel inoperable, place the channel in trip within 72 hours OR be in Mode 3 within 78 hours AND mode 4 within 84 hours. 3.3.3, Function 25 Steam Generator 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. NOT APPLICABLE
- 12. IF affected S/G controlling channel and level NORMAL, THEN BOP
- a. RETURN MFW reg valve to AUTO.
- b. RETURN TDMFWP Speed Control to AUTO (if in MANUAL).
Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 ( ( ( \\ I Appendix D Op Test No.: Event
Description:
Required Operator Actions Form ES-D-2 I NRC Scenario # 3 Event # 5 Page _11_ of ....;2=-4~-I1 Steam Generator Pressure transmitter 1-PT-1-9A fails LOW. BOP takes manual control of #3 SG main feed water regulating valve to control level. Enters AOI-16. Tech Spec Evaluation. Time Position Applicant's Actions or Behavior RO
- 8. CHECK power range N41 through N44 NORMAL.
NOTE Steps 7 & 8 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 anyone channel will have minimal effect on the affected S/G level. BOP
- 9. CHECK controlling steam flow Channels NORMAL.
- 9. RESPONSE NOT OBTAINED
- a.
SELECT operable channel. BOP
- b.
EVALUATE effect of the failed channel on the MFPs Speed Control and ADJUST in MANUAL as necessary while continuing this section. BOP
- 10. CHECK controlling FW flow channels NORMAL.
BOP
- 11. CHECK press compensation channel(s) NORMAL.
- 11. RESPONSE NOT OBTAINED REFER TO Tech Specs:
3.3.2 Function 1.e, Steam Line Pressure -Low, Condition D With one channel inoperable, place the channel in trip within 72 hours OR be in Mode 3 within 78 hours AND mode 4 within 84 hours. Function 4.d (1) Steam Line Pressure - Low, Condition D With SRO one channel inoperable, place the channel in trip within 72 hours OR be in Mode 3 within 78 hours AND mode 4 within 84 hours. 3.3.3, Function 25 Steam Generator 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. NOT APPLICABLE
- 12. IF affected S/G controlling channel and level NORMAL, THEN BOP
- a. RETURN MFW reg valve to AUTO.
- b. RETURN TDMFWP Speed Control to AUTO (if in MANUAL).
Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 3 Event # -:;.5_____ Page 11-of....;2;;;.4':""--11 Event
Description:
Steam Generator Pressure transmitter 1-PT-1-9A fails LOW. BOP takes manual control of #3 SG main feed water regulating valve to control level. Enters AOI-16. Tech Spec Evaluation. Time II Position II Applicant's Actions or Behavior
- 13. WHEN conditions allow auto rod control, THEN,
- a. ENSURE T-avg and T-refwithin 1°F.
RO
- b. ENSURE zero demand on control rod position indication [1-M-4].
- c. PLACE rods in AUTO.
EXAMINER: With the auctioneering circuit malfunction, the crew will NOT be able to place control rods in AUTO. SRO
- 13. INITIATE repairs to failed equipment.
SRO
- 14. RETURN TO Instruction in effect.
SRO Crew Brief - conduct for this event as time allows prior to the next event. SRO Notifications should be addressed as applicable if not specifically addressed by the procedure or in the crew brief. Operations Management - Shift Manager. SRO Maintenance Personnel - Maintenance Shift Supervisor (MSS). (Note: Maintenance notification may be delegated to the Shift Manager). Simulator operator enters Event 6 Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 ( ( I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 3 Event # ..,;;.5 _____ Page ~ of....;2=..4':""-"'1 Event
Description:
Steam Generator Pressure transmitter 1-PT-1-9A fails LOW. BOP takes manual control of#3 SG main feed water regulating valve to control level. Enters AOI-16. Tech Spec Evaluation. Time II Position II Applicant's Actions or Behavior
- 13. WHEN conditions allow auto rod control, THEN,
- a. ENSURE T -avg and T -ref within 1°F.
RO
- b. ENSURE zero demand on control rod position indication [1-M-4].
- c. PLACE rods in AUTO.
EXAMINER: With the auctioneering circuit malfunction, the crew will NOT be able to place control rods in AUTO. SRO
- 13. INITIATE repairs to failed equipment.
SRO
- 14. RETURN TO Instruction in effect.
SRO Crew Brief - conduct for this event as time allows prior to the next event. SRO Notifications should be addressed as applicable if not specifically addressed by the procedure or in the crew brief. Operations Management - Shift Manager. SRO Maintenance Personnel - Maintenance Shift Supervisor (MSS). (Note: Maintenance notification may be delegated to the Shift Manager). Simulator operator enters Event 6 Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 3 Event # --.;.6 _____ Page ~ of _2_4_-11 Event
Description:
Steam leak inside containment. Enter AOI-38 to determine location and severity of leak. Time II Position II Applicant's Actions or Behavior 144-A ICE COND INLET DOOR OPEN 103-B CNTMT MOISTURE HI 160-C RX BDLG POCKET SUMP LEVEL HI RO Announces ice condenser doors open alarm. BOP Monitors radiation monitors and determines from the absence of alarms that a steam leak is in progress. SRO Enters and direct actions of AOI-38. "Main Steam or Feedwater Line Leak." EXAMINER: The following actions are from AOI-38,"Main Steam or Feedwater Line Leak."
- 1. IF leak threatens personnel safetY,THEN:
- a. TRIP Rx.
SRO
- b. CLOSE the following:
- MSIVs.
- MSIV bypass valves.
- c. ** GO TO E-O, Reactor Trip or Safety Injection.
BOP
- 2. CHECK S/G PORVs CLOSED.
BOP
- 3. CHECK steam dump valves CLOSED.
- 4. CHECK reactor power less than or equal to 100%:
RO Loop AT. NIS power range monitors.
- 4. RESPONSE NOT OBTAINED REDUCE turbine load to 90% with valve position limiter.
RO/BOP IF Rx power returns to 100%, THEN.
- a. TRIP Rx.
- b. CLOSE all MSIVs and bypass valves.
- c. ** GO TO E-O, Reactor Trip or Safety Injection.
RO
- 5. ENSURE T -avg and T -ref. within 3°F.
Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 ( ( I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 3 Event # 6 Event
Description:
Steam leak inside containment. Enter AOI-38 to determine location and severity of leak. Time Position Applicant's Actions or Behavior 144-A ICE COND INLET DOOR OPEN 103-B CNTMT MOISTURE HI 160-C RX BDLG POCKET SUMP LEVEL HI RO Announces ice condenser doors open alarm. BOP Monitors radiation monitors and determines from the absence of alarms that a steam leak is in progress. SRO Enters and direct actions of AOI-38. "Main Steam or Feedwater Line Leak." EXAMINER: The following actions are from AOI-38,"Main Steam or Feedwater Line Leak."
- 1. IF leak threatens personnel safety, THEN:
- a. TRIP Rx.
- b. CLOSE the following:
SRO
- MSIVs.
- MSIV bypass valves.
- c. ** GO TO E-O, Reactor Trip or Safety Injection.
BOP
- 2. CHECK S/G PORVs CLOSED.
BOP
- 3. CHECK steam dump valves CLOSED.
- 4. CHECK reactor power less than or equal to 100%:
RO Loop ~T. NIS power range monitors.
- 4. RESPONSE NOT OBTAINED REDUCE turbine load to 90% with valve position limiter.
RO/BOP IF Rx power returns to 100%, THEN
- a. TRIP Rx.
- b. CLOSE all MSIVs and bypass valves.
- c. ** GO TO E-O, Reactor Trip or Safety Injection.
RO
- 5. ENSURE T -avg and T -ref. within 3°F.
Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 3 Event # _6~ ____ Page ~ of _2;;..4';""'--11 Event
Description:
Steam leak inside containment. Enter AOI-38 to determine location and severity of leak. Time Position II Applicant's Actions or Behavior NOTE It is a normal condition for Turbine load and Rx power to exhibit a nominal mismatch for loads less than 50%. Hotwell makeup will rise following a rapid runback. The makeup flow should be allowed to stabilize before making any determination of leak size.
- 6. MONITOR leak less than 3% of required steam or FW flow:
IF power greater than 50%, THEN COMPARE turbine load to BOP reactor power and Ll T. OBSERVE steam and FW flow recorders. OBSERVE hotweillevel makeup less than 950 gpm. BOP
- 7. MONITOR CST volume greater than 200,000 gallons.
BOP
- 8. ENSURE SG levels on program.
CAUTION FW or condensate leaks upstream of the FW isol valves should be promptly dealt with to limit hazards to Turbine Bldg personnel. SRO
- 9. DISPATCH personnel to perform secondary plant inspection for main steam and feedwater leaks.
- 10. CHECK Cntmt conditions NORMAL:
- Pressure (1-PDR-30-133 between -0.1 and +0.3 psig).
RO
- Temperature (Window 104-B DARK).
- Humidity (Window 103-B DARK).
- Sump level (Window 127-E DARK).
- 10. RESPONSE NOT OBTAINED ENSURE all Cntmt coolers RUNNING:
BOP
- . Upper containment coolers
- Lower containment coolers
- CRDM coolers RO
- 11. MONITOR Cntmt press stable or dropping.
- 11. RESPONSE NOT OBTAINED IF Cntmt press rising uncontrolled, THEN a TRIP Rx.
- b. ** GO TO E-O, Reactor Trip or Safety Injection.
Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 ( ( I Appendix 0 Required Operator Actions Form ES-O-2 I Op Test No.: NRC Scenario # 3 Event # ......;;..6 _____ Page ~ of _2_4_-11 Event
Description:
Steam leak inside containment. Enter AOI-38 to determine location and severity of leak. Time II Position II Applicant's Actions or Behavior NOTE It is a normal condition for Turbine load and Rx power to exhibit a nominal mismatch for loads less than 50%. Hotwell makeup will rise following a rapid runback. The makeup flow should be allowed to stabilize before making any determination of leak size.
- 6. MONITOR leak less than 3% of required steam or FW flow:
IF power greater than 50%, THEN COMPARE turbine load to BOP reactor power and Ll T. OBSERVE steam and FW flow recorders. OBSERVE hotweillevel makeup less than 950 gpm. BOP
- 7. MONITOR CST volume greater than 200,000 gallons.
BOP
- 8. ENSURE SG levels on program.
CAUTION FW or condensate leaks upstream of the FW isol valves should be promptly dealt with to limit hazards to Turbine Bldg personnel. SRO
- 9. DISPATCH personnel to perform secondary plant inspection for main steam and feedwater leaks.
- 10. CHECK Cntmt conditions NORMAL:
- Pressure (1-PDR-30-133 between -0.1 and +0.3 psig).
RO
- Temperature (Window 104-B DARK).
- Humidity (Window 103-B DARK).
- Sump level (Window 127-E DARK).
- 10. RESPONSE NOT OBTAINED ENSURE all Cntmt coolers RUNNING:
BOP
- Upper containment coolers
- Lower containment coolers
- CRDM coolers RO
- 11. MONITOR Cntmt press stable or dropping.
- 11. RESPONSE NOT OBTAINED IF Cntmt press rising uncontrolled, THEN a TRIP Rx.
- b. ** GO TO E-O, Reactor Trip or Safety Injection.
Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 3 Event # _6;;;.:,....;.7...., ;;;;;an~d;..;8;;......_ Page.:!..L of....;2=..4':"'--11 Event
Description:
Reactor fails to trip automatically and manually. Crew enters FR-S.1, "Nuclear Power Generation I ATWS." Steam line break gets worse, requiring a safety injection actuation. MSIVs fail to auto close. Time. Position II Applicant's Actions or Behavior Announces the ATWS condition, after attempting to trip the reactor RO manually 1-M-4 and then from the second reactortripswitch on 1-M-6. RO Performs IMMEDIATE ACTION of FR-S.1. BOP Performs IMMEDIATE ACTION of FR-S.1 SRO Enters and directs performance of FR-S.1, "Nuclear Power Generation/ATWS." EXAMINER: The following steps are from FR-S.1 "Nuclear Power Generation/ATWS."
- 1. ENSURE Reactor Trip:
Reactor trip and bypass breakers OPEN. RO RPls at bottom of scale. Neutron flux DROPPING. CRITICAL
- 1. RESPONSE NOT OBTAINED TASK RO Manually TRIP reactor.
IF reactor will NOT trip, THEN INSERT control rods. CRITICAL
- 2. ENSURE Turbine Trip:
TASK BOP
- All turbine stop valves CLOSED.
- 3. CHECK AFW pumps operation:
BOP a.. Both MD AFW pumps RUNNING.
- b. TD AFW pump RUNNING.
- c. LCVs in AUTO or controlled in MANUAL.
- 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 valves1-LCV-62-:132 and 1-LCV-62-133. BOP
- d. OPEN BIT outlet valves 1-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-FCy-62-138 to maintain boric acid flow greCiter than 35 gpm.
RO
- 5. CHECK pzrpressure less than 2335 psig.
Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 ( ( ( I Appendix D Op Test No.: Event
Description:
Required Operator Actions Form ES-D-2 I NRC Scenario # 3 Event # _6..;..;,....;.7...;..,.;.;;an..,.;.d..,.;.8;......-_ Page ~ of _2_4_-11 Reactor fails to trip automatically and manually. Crew enters FR-S.1, "Nuclear Power Generation / ATWS." Steam line break gets worse, requiring a safety injection actuation. MSIVs fail to auto close. Time Position Applicant's Actions or Behavior Announces the ATWS condition, after attempting to trip the reactor RO manually 1-M-4 and then from the second reactor trip switch on 1-M-6. RO Performs IMMEDIATE ACTION of FR-S.1. BOP Performs IMMEDIATE ACTION of FR-S.1 SRO Enters and directs performance of FR-S.1, "Nuclear Power Generation/ATWS." EXAMINER: The following steps are from FR-S.1 "Nuclear Power Generation/ATWS."
- 1. ENSURE Reactor Trip:
Reactor trip and bypass breakers OPEN. RO RPls at bottom of scale. Neutron flux DROPPING. CRITICAL
- 1. RESPONSE NOT OBTAINED TASK RO Manually TRIP reactor.
IF reactor will NOT trip, THEN INSERT control rods. CRITICAL
- 2. ENSURE Turbine Trip:
TASK BOP
- All turbine stop valves CLOSED.
- 3. CHECK AFW pumps operation:
BOP
- a. Both MD AFW pumps RUNNING.
- b. TD AFW pump RUNNING.
- c. LCVs in AUTO or controlled in MANUAL.
- 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 1-LCV-62-132 and 1-LCV-62-133.
BOP
- d. OPEN BIT outlet valves 1-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.
RO
- 5. CHECK pzr pressure less than 2335 psig.
Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
I Appendix D Op Test No.: Event
Description:
Required Operator Actions Form ES-D-2 I NRC Scenario # 3 Event # _6;;;..:,~7...l...'.;;;;an;.;.;d;;..;8;....-_ Page.1.2....- of _2_4_-11 Reactor fails to trip automatically and manually. Crew enters FR-S.1, "Nuclear Power Generation / ATWS." Steam line break gets worse, requiring a safety injection actuation. MSIVs fail to auto close. Time II Position II A~plicant's Actions or Behavior
- 6. VERIFY Cntmt Vent Isolation:(on 1-XX-55-6E and 1-XX-55-6F)
RO
- Train A GREEN
- Train B GREEN
- 7. IF AFW flow established, THEN BOP
- a. PLACE 1-HS-3-45 to LONG CYCLE RECIRC.
- b. PLACE MFW Bypass Reg Valves in AUTO.
SRO RO
- 8. IF SI actuated OR required, THEN PERFORM Steps 1 through 6 of E-O, Reactor Trip or Safety Injection, as time allows.
Assigns E-O, Steps 1 through 6 to the BOP. These steps are:
- 1. ENSURE reactor trip:
- Reactor trip and bypass breakers OPEN.
- RPls at bottom of scale.
- Neutron flux DROPPING.
- 2.
ENSURE Turbine Trip:
- All turbine stop valves CLOSED.
- 3.
CHECK 6.9 kV shutdown boards:
- a. At least one board energized from:
CSST (offsite), OR DIG (blackout).
- 4.
CHECK SI actuated:
- a. Any SI annunciator LIT.
- b. Both trains SI ACTUATED.
- 1-XX-55-6C
- 1-XX-55-6D
- 5.
EVALUATE support systems:
- REFER TO Appendixes A and B (E-O), Equipment Verification pages 15-28.
- 6. ANNOUNCE reactor trip and safety injection over PA system.
- 9. ENSURE the following trips: a. Reactor Trip.
EXAMINER: The RO may dispatch an AUO to open Rod Drive MG set input breakers at 480 V Unit Boards, and an AUO to open Reactor Trip breakers locally while initially inserting the control rods. Appendix D RO
- 9. RESPONSE NOT OBTAINED:
- a. DISPATCH operator to locally trip reactor:
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.
Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 ( ( ( I Appendix 0 Op Test No.: Event
Description:
Required Operator Actions Form ES-O-2 I NRC Scenario # 3 Event # 6,7, and 8 Page ~ of _2;;;..4~-I1 Reactor fails to trip automatically and manually. Crew enters FR-S.1, "Nuclear Power Generation / ATWS." Steam line break gets worse, requiring a safety injection actuation. MSIVs fail to auto close. Time II Position II Applicant's Actions or Behavior
- 6. VERIFY Cntmt Vent Isolation:(on 1-XX-55-6E and 1-XX-55-6F)
RO
- Train A GREEN
- Train B GREEN
- 7. IF AFW flow established, THEN BOP
- a. PLACE 1-HS-3-45 to LONG CYCLE RECIRC.
- b. PLACE MFW 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.
Assigns E-O, Steps 1 through 6 to the BOP. These steps are:
- 1. ENSURE reactor trip:
- Reactor trip and bypass breakers OPEN.
- RPls at bottom of scale.
- Neutron flux DROPPING.
- 2.
ENSURE Turbine Trip:
- All turbine stop valves CLOSED.
- 3.
CHECK 6.9 kV shutdown boards:
- a. At least one board energized from:
CSST (offsite), OR DIG (blackout).
- 4.
CHECK SI actuated:
- a. Any SI annunciator LIT.
- b. Both trains SI ACTUATED.
- 1-XX-55-6C
- 1-XX-55-6D
- 5.
EVALUATE support systems:
- REFER TO Appendixes A and B (E-O), Equipment Verification pages 15-28.
- 6. ANNOUNCE reactor trip and safety injection over PA system.
RO
- 9. ENSURE the following trips: a. Reactor Trip.
EXAMINER: The RO may dispatch an AUO to open Rod Drive MG set input breakers at 480 V Unit Boards, and an AUO to open Reactor Trip breakers locally while initially inserting the control rods. RO BOP Appendix 0
- 9. RESPONSE NOT OBTAINED:
- a. DISPATCH operator to locally trip reactor:
OPEN reactor trip breakers and MG set output breakers [MG set room]. OPEN breakers to MG sets [480V unit boards A and B].
- b. Turbine Trip.
Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
I Appendix D Op Test No.: Event
Description:
Required Operator Actions Form ES-D-2 I NRC Scenario # 3 Event # _6;;;.0'...;.7...,.;;;;an..:.:d;..;8~_ Page.lZ..- of....;2;;..4:"'--l1 Reactor fails to trip automatically and manually. Crew enters FR-S.1, "Nuclear Power Generation I ATWS." Steam line break gets worse, requiring a safety injection actuation. MSIVs fail to auto close. Time II Position Applicant's Actions or Behavior
- 10. MAINTAIN rod insertion UNTIL rods fully inserted.
RO Rods are fully inserted based on local operator actions already performed. SRO
- 11. REFER TO EPIP-1, Emergency Plan Classification Flowchart for ATWS event.
- 12. MONITOR reactor subcriticality:
SRO
- a. CHECK Power range channels less than 5%.
- b. CHECK Intermediate range startup rate NEGATIVE.
- c. ** GO TO Step 21.
- 21. TERMINATE emergency boration:
- a. PLACE BA transfer pumps in SLOW speed.
RO
- b. CLOSE emergency borate valve 1-FCV-62-138.
- c. IF alternate boration opened, THEN Locally CLOSE 1-ISV 929.
CAUTION Evaluation of boration requirements should consider subsequent cooldown actions in addition to current conditions.
- 22. DETERMINE shutdown margin requirements:
- a. NOTIFY Chemistry to sample RCS.
- b. REFER TO 1-SI-0-10, Shutdown Margin, OR REACTINW Com puter Program.
SRO
- c. INITIATE RCS boration as necessary:
- REFER TO SOI-62.02, CVCS BORON Concentration Control.
- d. INITIATE flushing boric acid piping as necessary:
- REFER TO AOI-34, Immediate Boration.
SRO IF SI actuated, THEN RETURN TO Instruction in effect. EXAMINER: The SRO will enter E-O, Reactor Trip or Safety Injection," at this point. Enters and directs actions of E-O,"Reactor trip or Safety Injection." SRO Steps 1-6 have already been addressed by the BOP during the performance of FR-S.1. NOTE 1 Steps 1 thru 4 are IMMEDIATE ACTION STEPS. NOTE 2 Status Trees / SPDS should be monitored when transitioned to another instruction. Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 ( I Appendix 0 Op Test No.: Event
Description:
Required Operator Actions Form ES-O-2 I NRC Scenario # 3 Event # 6,7, and 8 Page.1L... of _2_4_..,1 Reactor fails to trip automatically and manually. Crew enters FR-S.1, "Nuclear Power Generation I ATVVS." Steam line break gets worse, requiring a safety injection actuation. MSIVs fail to auto close. Time II Position II Applicant's Actions or Behavior
- 10. MAINTAIN rod insertion UNTIL rods fully inserted.
RO Rods are fully inserted based on local operator actions already performed. SRO
- 11. REFER TO EPIP-1, Emergency Plan Classification Flowchart for ATWS event.
- 12. MONITOR reactor subcriticality:
SRO
- a. CHECK Power range channels less than 5%.
- b. CHECK Intermediate range startup rate NEGATIVE.
- c. ** GO TO Step 21.
- 21. TERMINATE emergency boration:
- a. PLACE BA transfer pumps in SLOW speed.
RO
- b. CLOSE emergency borate valve 1-FCV-62-138.
- c. IF alternate boration opened, THEN Locally CLOSE 1-ISV 929.
CAUTION Evaluation of boration requirements should consider subsequent cooldown actions in addition to current conditions.
- 22. DETERMINE shutdown margin requirements:
- a. NOTIFY Chemistry to sample RCS.
- b. REFER TO 1-SI-0-10, Shutdown Margin, OR REACTINW Computer Program.
SRO
- c. INITIATE RCS boration as necessary:
- REFER TO SOI-62.02, CVCS BORON Concentration Control.
- d. INITIATE flushing boric acid piping as necessary:
- REFER TO AOI-34, Immediate Boration.
SRO IF SI actuated, THEN RETURN TO Instruction in effect. EXAMINER: The SRO will enter E-O, Reactor Trip or Safety Injection," at this point. Enters and directs actions of E-O,"Reactor trip or Safety Injection." SRO Steps 1-6 have already been addressed by the BOP during the performance of FR-S.1. NOTE 1 Steps 1 thru 4 are IMMEDIATE ACTION STEPS. NOTE 2 Status Trees / SPDS should be monitored when transitioned to another instruction. Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
I Appendix D Op Test No.: Event
Description:
Required Operator Actions Form ES-'D-2 I NRC Scenario # 3 Event # _6.;;.;,:..;7..:.,,;;;;an;.;,;d;;.,;8;;..-._ Page ~ of....;2=..4':""--11 Reactor fails to trip automatically and manually. Crew enters FR-S.1, "Nuclear Power Generation / ATWS." Steam line break gets worse, requiring a safety injection actuation. MSIVs fail to auto close. Time Position II Applicant's Actions or Behavior
- 1. ENSURE reactor trip:
Reactor trip and bypass breakers OPEN. RO RPls at bottom of scale. Neutron flux DROPPING. BOP
- 2. ENSURE Turbine Trip:
All turbine stop valves CLOSED.
- 3. CHECK 6.9 kV shutdown boards:
- a. At least one board energized from:
BOP CSST (offsite), OR DIG (blackout).
- 4. CHECK SI actuated:
- a. Any SI annunciator LIT.
RO
- b. Both trains SI ACTUATED.
1-XX-55-6C 1-XX-55-6D
- 5. EVALUATE support systems:
BOP REFER TO Appendixes A and B (E-O), Equipment . Verification pages 15-28. RO
- 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, RO OR At least one SIG NR level greater than 29% [39% ADV].
- 8. MONITOR RCS temp stable at or trending to 55rF:
IF any RCP running, THEN MONITOR RCS Loop T-avg trending to 55rF. RO OR IF NO RCP running, THEN MONITOR RCS Loop T -cold trending to 557°F. EXAMINER: The RNO steps for this step are included at the back of this Scenario Guide. Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 ( ( I Appendix 0 Op Test No.: Event
Description:
Required Operator Actions Form ES-D-2 I NRC Scenario # 3 Event # --'-'6,'""-'7....,...;..an_d_S'--_ Page ~ of _2_4_-11 Reactor fails to trip automatically and manually. Crew enters FR-S.1, "Nuclear Power Generation / ATWS." Steam line break gets worse, requiring a safety injection actuation. MSIVs fail to auto close. Time II Position II Applicant's Actions or Behavior
- 1. ENSURE reactor trip:
Reactor trip and bypass breakers OPEN. RO RPls at bottom of scale. Neutron flux DROPPING. BOP
- 2. ENSURE Turbine Trip:
All turbine stop valves CLOSED.
- 3. CHECK 6.9 kV shutdown boards:
- a. At least one board energized from:
BOP CSST (offsite), OR DIG (blackout).
- 4. CHECK SI actuated:
- a. Any SI annunciator LIT.
RO
- b. Both trains SI ACTUATED.
1-XX-55-6C 1-XX-55-6D
- 5. EVALUATE support systems:
BOP REFER TO Appendixes A and B (E-O), Equipment Verification pages 15-28. RO
- 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, RO OR At least one SIG NR level greater than 29% [39% ADV].
- 8. MONITOR RCS temp stable at or trending to 55rF:
IF any RCP running, THEN MONITOR RCS Loop T-avg trending to 55rF. RO OR IF NO RCP running, THEN MONITOR RCS Loop T-cold trending to 55rF. EXAMINER: The RNO steps for this step are included at the back of this Scenario Guide. Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 3 Event # ~6,~7..l.'.;;;an;.;,;d;;..;8;;......_ Page ~ of _2:;.4~-I1 Event
Description:
Reactor fails to trip automatically and manually. Crew enters FR-S.1, "Nuclear Power Generation I ATWS." Steam line break gets worse, requiring a safety injection actuation. MSIVs fail to auto close. Time II Position II Applicant's Actions or Behavior
- 9. ENSURE excess letdown valves CLOSED:
RO 1-FCV-62-54 1-FCV-62-55
- 10. CHECK pzr PORVs and block valves:
RO
- a. Pzr PORVs CLOSED.
- b. At least one block valve OPEN.
RO
- 11. CHECK pzr safety valves CLOSED:
EVALUATE tailpipe temperatures and acoustic monitors. RO
- 12. CHECK pzr sprays CLOSED.
NOTE Seal injection flow should be maintained to all RCPs. CRITICAL TASK to trip
- 13. CHECK if RCPs should remain in service:
all RCPs due to loss of
- a. Phase B signals DARK [MISSP].
cooling on the Phase B actuation.
- b. RCS pressure greater than 1500 psig.
- 14. CHECK S/G pressures:
SRO/RO
- All S/G pressures controlled or rising.
- All S/G pressures greater than 120 psig.
- 14. RESPONSE NOT OBTAINED SRO IF S/G pressure low OR dropping uncontrolled, THEN
- GO TO E-2, Faulted Steam Generator Isolation.
EXAMINER: The following actions are from E-2, "Faulted Steam Generator Isolation." CAUTION If a faulted S/G is NOT needed for RCS cooldown, it should remain isolated during subsequent recovery actions. CRITICAL TASK to manually close all
- 1. ENSURE all MSIVs and MSIV bypasses CLOSED.
. MSIVs and bypasses. ~,- 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. Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 ( I Appendix 0 Required Operator Actions Form ES-O-2 I Op Test No.: NRC Scenario # 3 Event # _6';':'....;.7..:..,....;.an_d_8__ Page ~ of _2_4~-I1 Event
Description:
Reactor fails to trip automatically and manually. Crew enters FR-S.1, "Nuclear Power Generation / ATWS." Steam line break gets worse, requiring a safety injection actuation. MSIVs fail to auto close. Time II Position II Applicant's Actions or Behavior
- 9. ENSURE excess letdown valves CLOSED:
RO 1-FCV-62-54 1-FCV-62-55
- 10. CHECK pzr PORVs and block valves:
RO
- a. Pzr PORVs CLOSED.
- b. At least one block valve OPEN.
RO
- 11. CHECK pzr safety valves CLOSED:
EVALUATE tailpipe temperatures and acoustic monitors. RO
- 12. CHECK pzr sprays CLOSED.
NOTE Seal injection flow should be maintained to all RCPs. CRITICAL TASK to trip
- 13. CHECK if RCPs should remain in service:
all RCPs due to loss of
- a. Phase B signals DARK [MISSPj.
cooling on the Phase B actuation.
- b. RCS pressure greater than 1500 psig.
- 14. CHECK S/G pressures:
SRO/RO
- All S/G pressures controlled or rising.
- All S/G pressures greater than 120 psig.
- 14. RESPONSE NOT OBTAINED SRO IF S/G pressure low OR dropping uncontrolled, THEN
- GO TO E-2, Faulted Steam Generator Isolation.
EXAMINER: The following actions are 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. CRITICAL TASK to manually close all
- 1. ENSURE all MSIVs and MSIV bypasses CLOSED.
MSIVs and bypasses. 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. Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
I Appendix 0 Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 3 Event # ......;.;6,~7..:..,.... an_d_S,--_ Page ~ of _2_4'---11 Event
Description:
Reactor fails to trip automatically and manually. Crew enters FR-S.1, "Nuclear Power Generation I ATWS." Steam line break gets worse, requiring a safety injection actuation. MSIVs fail to auto close. Time II Position II Applicant's Actions or Behavior CAUTION
- 2. PLACE steam dump controls OFF:
BOP 1-HS-1-103A, STEAM DUMP FSV"A". 1-HS-1-103B, STEAM DUMP FSV"B".
- 3. CHECK for at least one Intact S/G:
Any S/G pressure controlled or rising, SRO/BOP OR Any S/G pressure greater than P-sat for RCS incore temperature.
- 4. IDENTIFY Faulted S/G based on ANY of the following:
Any S/G pressure dropping in an uncontrolled manner, OR Any S/G pressure less than 120 psig, OR S/G enclosure temps high: BOP
- 1) T1 002A for 2 and 3,
- 2) T1 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.
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 S/G.
- 5. ISOLATE Faulted S/G:
- a. ISOLATE AFW flow to Faulted S/G.
- b. ENSURE MFW.ISOLATED to Faulted S/G:
BOP
- MFW Isolation and bypass isolation valves CLOSED..
- MFW reg and bypass reg valves. CLOSED.
- MFPs TRIPPED.
Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 ( ( I Appendix D Op Test No.: Event
Description:
Required Operator Actions Form ES-D-2 I NRC Scenario # 3 Event # 6,7, and 8 Page ~ of....;2;;;..4';"""-11 Reactor fails to trip automatically and manually. Crew enters FR-S.1, "Nuclear Power Generation I ATWS." Steam line break gets worse, requiring a safety injection actuation. MSIVs fail to auto close. Time II Position II Applicant's Actions or Behavior
- 2. PLACE steam dump controls OFF:
BOP 1-HS-1-103A, STEAM DUMP FSV"A". 1-HS-1-103B, STEAM DUMP FSV"B".
- 3. CHECK for at least one Intact S/G:
Any S/G pressure controlled or rising, SRO/BOP OR Any S/G pressure greater than P-sat for RCS incore tern peratu reo
- 4. IDENTIFY Faulted S/G based on ANY of the following:
Any S/G pressure dropping in an uncontrolled manner, OR Any S/G pressure less than 120 psig, OR S/G enclosure temps high: BOP
- 1) T1 002A for 2 and 3,
- 2) T1 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.
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 S/G.
- 5. ISOLATE Faulted S/G:
- a. ISOLATE AFW flow to Faulted S/G.
- b. ENSURE MFW ISOLATED to Faulted S/G:
BOP
- MFW isolation and bypass isolation valves CLOSED.
- MFW reg and bypass reg valves CLOSED.
- MFPs TRIPPED.
Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 3 Event # ~6,~7 ....,..;;.an;.;.;d;;.,8;......._ Page ~ of...;2;;;..4':"'--11 Event
Description:
Reactor fails to trip automatically and manually. Crew enters FR-S.1, "Nuclear Power Generation I ATWS." Steam line break gets worse, requiring a safety injection actuation. MSIVs fail to auto close. Time II Position II Applicant's Actions or Behavior
- c. ENSURE Faulted S/G PORVCLOSED.
- d. ENSURE Faulted S/G blowdown ISOLATED.
NOTE TD AFW pump steam supply should NOT be aligned from a S/G with a known primary to secondary leak if other AFW sources are available.
- 6. ENSURE TD AFW pump being supplied from Intact S/G.
- 7. MONITOR CST volume greater than 200,000 gal.
- 8. WHEN RCS temperature is stable or rising following Faulted S/G blowdown, THEN ADJUST'lntact S/GPORV controllers in AUTO to:
BOP 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 BOP Condenser vacuum exhaust rad monitors NORMAL. 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 subcaoling greater than 65°F [85°F ADV].
- b. CHECK secondaryheat sink available with either:
Total feed flow to Intact S/Gs greater than 410 gpm, SRO/RO OR At least one Intact S/G NR level greater than 29% [39% ADV].
- c. CHECK RCS pressure stable or rising.
- d. CHECK pzr level greater than 15% [33% ADV].
- e. ** GO TO ES-1.1,SI Termination.
EXAMINER: The following actions are from ES-1.1 SI Termination."
- 1. RESET SI, and CHECK the following:
RO SI ACTUATED permissive DARK. AUTO SI BLOCKED permissiveLIT. / Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 ( ( ( \\ I Appendix 0 Required Operator Actions Form ES-O-2 I Op Test No.: NRC Scenario # 3 Event # 6,7, and 8 Page ~ of _2=-4.:.....-~1 Event
Description:
Reactor fails to trip automatically and manually. Crew enters FR-S.1, "Nuclear Power Generation / ATWS." Steam line break gets worse, requiring a safety injection actuation. MSIVs fail to auto close. Time II Position II Applicant's Actions or Behavior
- c. ENSURE Faulted S/G PORV CLOSED.
- d. ENSURE Faulted S/G blowdown ISOLATED.
NOTE TD AFW pump steam supply should NOT be aligned from a S/G with a known primary to secondary leak if other AFW sources are available.
- 6. ENSURE TD AFW pump being supplied from Intact S/G.
- 7. MONITOR CST volume greater than 200,000 gal.
- 8. WHEN RCS temperature is stable or rising following Faulted S/G blowdown, THEN AOJUSTIntact S/G PORV controllers in AUTO to:
BOP 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. BOP Condenser vacuum exhaust rad monitors NORMAL. 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, SRO/RO OR At least one Intact S/G NR level greater than 29% [39% ADV].
- c. CHECK RCS pressure stable or rising.
- d. CHECK pzr level greater than 15% [33% ADV].
- e. ** GO TO ES-1.1,SI Termination.
EXAMINER: The following actions are from ES-1.1 SI Termination."
- 1. RESET SI, and CHECK the following:
RO SI ACTUATED permissive DARK. AUTO SI BLOCKED permissive LIT. Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
( I Appendix 0 Op Test No.: Event
Description:
Required Operator Actions Form ES-D-2 I NRC Scenario # 3 Event # 6,7, and 8 Page ~ of....;2=-4~-I1 Reactor fails to trip automatically and manually. Crew enters FR-S.1, "Nuclear Power Generation / ATWS." Steam line break gets worse, requiring a safety injection actuation. MSIVs fail to auto close. Time Position II Applicant's Actions or Behavior RO
- 2. RESET Phase A and Phase B.
- 3. ENSURE cntmt air in service:
- a. Aux air press greater than 75 psig [M-15].
BOP
- b. Cntmt air supply valves OPEN [M-15]:
- 1-FCV-32-80.
- 1-FCV-32-102.
- 1-FCV-32-110.
NOTE On SI reset failure, the non-affected train should be stopped and placed in A-AUTO. RO
- 4. ENSURE ONLY one Charging Pump running:
STOP all but one CCP and PLACE in A-AUTO. RO
- 5. CHECK RCS press stable or rising.
- 6. ALIGN charging:
- a. CLOSE RCP seal flow controI1-FCV-62-89.
- b. OPEN charging isolation valves 1-FCV-62-90 and 1-FCV 91.
RO
- c. ENSURE charging valve 1-FCV-62-85 OR 1-FCV-62-86 OPEN.
- d. CHECK RHR Suction aligned from RWST.
- e. OPEN seal return valves 1-FCV-62-61 and 1-FCV-62-63.
RO
- 7. CLOSE BIT outlet valves 1-FCV-63-25 and 1-FCV-63-26.
- 8. ADJUST 1-FCV-62-89 and 1-FCV-62-93 to maintain:
RO
- Seal injection flow between 8 and 13 gpm for each RCP.
- Pzr level stable or rising.
- 9. CONTROL charging flow to maintain pzr level:
RO
- a. IF any S/G Faulted, THEN DO NOT CONTINUE this Instruction UNTIL Faulted S/G depressurization stops.
- b. CHECK pzr level stable or rising.
EXAMINER: When Step 9 is addressed, inform crew that another crew will continue from this point, and terminate the scenario. END OF SCENARIO Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 ( ( ( I Appendix 0 Op Test No.: Event
Description:
Required Operator Actions Form ES-D-2 I NRC Scenario # 3 Event # ,...;;.:6,:....;7.....,..;;;;an;,;.;d;;..;8;;.....-_ Page ~ of.....;;;..24';""-'-11 Reactor fails to trip automatically and manually. Crew enters FR-S.1, "Nuclear Power Generation / ATWS." Steam line break gets worse, requiring a safety injection actuation. MSIVs fail to auto close. Time II PositionlJ Applicant's Actions or Behavior RO
- 2. RESET Phase A and Phase B.
- 3. ENSURE cntmt air in service:
- a. Aux air press greater than 75 psig [M-15].
- b. Cntmt air supply valves OPEN [M-15]:
BOP
- 1-FCV-32-80.
- 1-FCV-32-102.
- 1-FCV-32-110.
NOTE On SI reset failure, the non-affected train should be stopped and placed in A-AUTO. RO
- 4. ENSURE ONLY one Charging Pump running:
STOP all but one CCP and PLACE in A-AUTO. RO
- 5. CHECK RCS press stable or rising.
- 6. ALIGN charging:
- a. CLOSE RCP seal flow control 1-FCV-62-89.
- b. OPEN charging isolation valves 1-FCV-62-90 and 1-FCV 91.
RO
- c. ENSURE charging valve 1-FCV-62-85 OR 1-FCV-62-86 OPEN.
- d. CHECK RHR Suction aligned from RWST.
- e. OPEN seal return valves 1-FCV-62-61 and 1-FCV-62-63.
RO
- 7. CLOSE BIT outlet valves 1-FCV-63-25 and 1-FCV-63-26.
- 8. ADJUST 1-FCV-62-89 and 1-FCV-62-93 to maintain:
RO
- Seal injection flow between 8 and 13 gpm for each RCP.
- Pzr level stable or rising.
- 9. CONTROL charging flow to maintain pzr level:
RO
- a. IF any S/G Faulted, THEN DO NOT CONTINUE this Instruction UNTIL Faulted S/G depressurization stops.
- b. CHECK pzr level stable or rising.
EXAMINER: When Step 9 is addressed, inform crew that another crew will continue from this point, and terminate the scenario. END OF SCENARIO Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
WBN MALFUNCnON OF REACTOR CONTROL SYSTEM ATTACHMENT 1 Page 1 of 1 AOI-2 Revision 37 Page 51 51 REACTOR POWER VS TAVG/TREF TEMPERATURE AND PZR LEVEL {TGlvg-Tref vaiues rounded to one tenth of <l. degree} RX TAVG-PZR RX TAVE-PZR POWER TREF LEVEL POWER TREF LEVEL '10/ ."-.,0 557J3 of 25.7 il!il 52% 512.2 DF 43.20,*'0 4% 558.2 <'f 26.4 "I.e, 54% 572.8 '=F 43.9% 6% 558.8 Of 27.1% 56~;'~ 573A of 44.6 %) 8% 559.3 of 27.8% 58% 573.9"F 45.3 ";:;) "10% 559.'9 Of 28.5 'l,~ 130% 574.5"F 46.0% r~'o!. L. _-0 5130.5 e>f 29.2 % 62% 575.'I~F 46.7 % 14% kR,jJ of ,J:) j,w 2S1.9 % 54il!" 575.7 =-F 47.4 % 16~:{' 56'1.7 Of 30.6 '% 66% 576.3"F 48.'1 % 18% 562.3 Of 31.3 l}!olJo 68% 5713.9 t:F 48.8% 20% 562.8 Of 32.0 70% 577.4 of 49.5% 22% 563A "f 32.1 % 72rJy{; 578.0"F 50.2 % 24% 564.0 Of 33.4 ~:& 74% 578.6 OF 50.9 % 26% 5*64.. 6 of 34.1 % 76'% 579.2"F 5'1J3 % 28~fl 565.2 "f 34.B
- 78~!~
579.8"F 52.3% 30~!o 565.8 Of ':)r r % ..J~.. :J 80% 580.4"F 53.0 % 32~*b 566.3 OF 36.2 82% 580.9 OF 53.7 % 34% 566.9 Of 36.9% 84% 581.5"F 54.4% 36%, 567.5 OF 37.6 % 86% 582.'1=*1= n W 8 55.1 % 38Cjb 568. '=If 38.3 88% 582.7 "'F 55.8 ~Io 40~!o 5138.7 Of 39.0% 90% 583.3"F 56.5% 42% 5[39.3 C'f 39.7 "% 92% 583.9"F -57.2 !~J 44% 5139.8 Of 40.4 % 94% 584.4"F 57.9o.'b 46~:o 570A OF 41.1 % 96% 58S.0"F 58.6 % 48% 571.0 OF 41.8 olJo!" 98il!olJo 58S.6"'F 59.3 ~.~ 5,0% 57'1.6 "F 42.. 5 100% 586.2"'F 50.0 % Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 WBN MALFUNCTION OF REACTOR CONTROL SYSTEM ATTACHMENT 1 Page 1 of 1 AOI-2 Revision 37 Page 51 of 51 REACTOR POWER VS TAVGfTREF TEMPERATURE AND PZR LEVEL {Ta*,rg-Tref vaues rounded to one tenth of a degree} RX TAVG-PZR RX TAVE-PZR POWER TREF LEVEL POWER TREF LEVEL 2% 5S,7.6 <'F 25.7 lJ/{} 52% 572.2 ~F 43.2 ~'b 4 ~fo 5S,B.2 cg:- 26.4 % 54'Y'J 572.B t*e 43.9 ~.f:J 6% 5SB.8 "g:- 27.1 ~~ 5Ei~'~ 573.4 -.r-44.6 % I T 8% 559.3 "F 27.8 ~,~ 58~':G 573.9 "F 45.3 0;;) "10% 559.9 OF 28.5 ~,~ 60% 574.5 "F 46.0 ~/;) 12% f160.5 <oF 29.2 ~/,t} 62-l1/{J 575.1 ;:;,F 46.7 % 14% 56 O.F 29.9 % 64% 575.7 "F 47.4 ~.{) 16% 561.7.oF 30.6 'J! /{) 66'J/o 576.3 :OF 48.'1 OJ ... 0 18~~*'D 56*2.3 <'F 3'1.3 % 68% 51f3.9 =>1= I 48.8 % 20~;'b 562.B t>F 32.0 ~!'J-70%* 577.4 :'F 49.5 1)/ .. 0 22% 563.4 "'F 32.7 i{, 7~'fr/ L;~ 578.0 -r 50.2 I~;O 24% 564.0 OF 33.4 {b' i'J 74% 578.6 =-C' I 50.9 !~*b 26~'c1 5134.6 "F 34.1 % 76% 57Sf.2 =.cF
- ,1.6 0/
- 0 28%
565.2 OF 34.8 ~!. .'!} 781b 579.B ~F 52.3 ~.{) 30% 565.8 OF 35.5 % 80% 580.4 ~F 53.0 % 32~/O 566.3 OF 36.2 {}! /{! 82% 580.9 ~F 53.7 ~.'o 34~:jD 566.9 OF 36.S! % 84"%, 581.5 ~F 54.4 ~'{J 36% 567.5 OF 37.Ei o/~ 86{}/{)' 582.1 ~F 55.'1 % 38~:~ h:6P:i ,J ,->1. <'F 38.3 o/~ 88% 582.7 =~F 55.8 0/
- 0 40~Ycl 568.7 'OF 39.0 al f-ll 9O~%
583.3 =-F 56.5 ~:d 42% 5139.3 'OF 3£1.7 ~,~ 92% 583.9 ~l= 57.2 % 44% 569..8 OF 40.4 ~,s, 94% 584.4 ;:<F 57.9 1'/
- .)
46% 570.4 OF 4Ll 'IfJ /*D 96l}/l} 505.0 ~F 58.6 ~:~ 413% 571.0 'OF 41.8 ~!1} 98%, 505.6 =-F 59.3 QI /0 50~'o 571.6 OF 42.5 % 100o.*-b 506.2 :iF 60.0 % Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
WBN REACTOR TRIP OR SAFETY INJECTION E-O I Step II ActionlExp'cted Response
- 8.
- 9.
MONITOR RCS temp stable at or trending to 55rF: IF any RCP running, THEN MONITOR RCS T-a*,,'*g trending to 557'F. OR IF NO RCP running, THEN MONITOR RCS Loop T-cold trending to 557"F ENSURE excessletdovm valves CLOSED: 1-FC\\I-62-54 '1-FCV-62-55 R; nf,)F: 11 Response Not Obtained IF temp less than 55T'F, THEN Rev 28 E NSIJ RE stearll'l du m ps and SIG PORVs CLOSED. IF cooldcr'NIl continues, THEN: PLACE steam dump controls OFF. CmHROL total A'p,N flo'w to maintain greater than 410 gpm UNTIL NR level in at least one SIG greater than 29% [39% AD'vl IF cooldo'Jlm continues aner A.PN flow is controlled, THEN CLOSE t*/iSIVs. ENSURE MSIV bypasses CLOSED. IF RCS THEN greater than 5640 F, ENSURE either steam dum!)s or SIG POR\\'s OPEN. Manually CLOSE valves. Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 WBt,~ REACTOR TRIP OR SAFETY INJECTION E-O I Step II ActionlExpected Response 8,
- 9.
MONITOR ReS temp stable at or trending to 557'F: IF any Rep funning, THEN MONITOR RCS loop T-avg trending,to 55TF, OR IF NO Rep funning, THEN MONITOR RCS Loop T-cold t.rending to 55TF ENSURE excess letdo'lm valve-s CLOSED: '1-FCV-62-54 '1-F C\\/-62 -551 h rtf)R II Response Not Obtained IF temp less than 55TF, THEt~ Re"" 28 ENSURE steal"l dumps and S/G PORVs CLOSED, IF cooldm'in continues, THEN: PLACE steam durnp controls
- OFF, CONTROL total A.FW flo'"" to rflaintaill greater than 410 gpm UNTIL r~R le'/el in at least one SlG greater thaf1 29% [39%.ADVl, IF cooidowil continues after A,Fl,N flow is controlled, THEN CLOSE MSrVs, ENSURE MS IV 'bypasses CLOSED.
IF ReS temp greater than 564F, THEN ENSURE either stearn dumps or SIG PORVs OPEN, t*l1alluaily CLOSE v3lve-s, Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
0 [gj 0 0 0 SM VS/MCR VO AVO Vnit Vnit SHIFT TURNOVER CHECKLIST Pa!!e 1 of2 SHIFT TURNOVER CHECKLIST Page ___ of -- Station STA (STA Function) Off-going - Name On-coming - Name Part 1 - Completed by off-going shiftlReviewed by on-coming shift: Abnonnal equipment lineup/conditions: lA Containment Spray pump is out of service for bearing replacement. LCO 3.6.6, Containment Spray System Condition A was entered 6 hours ago. The IA Containment Spray pump is ex:eected to be returned to service in 16 hours. SiiTest in progress/planned: (including need for new brief) Major Activities/Procedures in progress/planned: Predictive Maintenance has requested the I C #3 heater drain :eump be removed from service for a shaft alignment due to concerns over the inboard motor bearing vibration trend. 0:eerations Management has requested a power reduction to 85% at a rate of I %/minute to prepare for pump shutdown. Plant is currently at 100% power, MOL. RCS boron concentration is 877 ppm. Decision to perfonn shutdown was made 30 minutes ago. Vse AOI-39, "Rapid Load Reduction," for the power reduction. infonnation for shutdown. Control Bank D is at 220 steps. Train A Week - ChannelL Radiological changes in plant during shift: Part 2 - Performed by on-coming shift 0 A review of the Operating Log since last held shift or 3 days, whichever is less (N/A for AVOs) 0 A review of the Rounds sheets/Abnonnal readings (AVOs only) Review the following programs for changes since last shift turnover: 0 Standing Orders 0 LCO(s) in actions (N/A for AVOs) 0 PER review 0 Innnediate required reading 0 TACF (N/A for AVOs) (N/A for AVOs) Part 3 - Performed by both off-going and on-coming shift 0 A walkdown of the MCR control boards (N/A for AVOs) Relief Time: Relief Date: TVA 40741 [06-2008] Page 1 of 1 OPDP-I-I [06-12-2008] SHIFT TURNOVER CHECKLIST age 0 P 1 f2 SHIFT TURNOVER CHECKLIST Page of D SM ~ US/MCR Unit D UO Unit Off-going - Name D AUO Station D STA (STA Function) On-coming - Name Part 1 - Completed by off-going shift/Reviewed by on-coming shift: Abnonnal equipment lineup/conditions: lA Containment SEray pump is out of service for bearing replacement. LCO 3.6.6, Containment SEray System Condition A was entered 6 hours ago. The lA Containment SEray Eump is eXEected to be returned to service in 16 hours. SIITest in progress/planned: (including need for new brief) Major Activities/Procedures in progress/planned: Predictive Maintenance has reguested the 1 C #3 heater drain Eump be removed from service for a shaft alignment due to concerns over the inboard motor bearing vibration trend. 0Eerations Management has requested a power reduction to 85% at a rate of 1 %/minute to prepare for pump shutdown. Plant is currently at 100% power, MOL. RCS boron concentration is 877 ppm. Decision to perfonn shutdown was made 30 minutes ago. Use AOI-39, "Rapid Load Reduction," for the power reduction. infonnation for shutdown. Control Bank D is at 220 steps. Train A Week - Channel I. Radiological changes in plant during shift: Part 2 - Performed by on-coming shift D A review ofthe Operating Log since last held shift or 3 days, whichever is less (N/A for AUOs) D A review of the Rounds sheets/Abnonnal readings (AUOs only) Review the following programs for changes since last shift turnover: D Standing Orders D LCO(s) in actions (N/A for AUOs) D PER review D Immediate required reading D TACF (N/A for AUOs) (N/A for AUOs) Part 3 - Performed by both off-going and on-coming shift D A walkdown of the MCR control boards (N/A for AUOs) Relief Time: Relief Date: TVA 40741 [06-2008] Page 1 of 1 OPDP-I-I [06-12-2008]
D SM D US/MCR Unit ~ UO Unit D AUO Station D STA (STA Function) SHIFT TURNOVER CHECKLIST Pa!!e 2 of2 SHIFT TURNOVER CHECKLIST Page ___ of -- Off-going - Name On-coming - Name Part 1 - Completed by off-going shiftlReviewed by on-coming shift: Abnormal equipment lineup/conditions: IA Containment Spray pump is out of service for bearing replacement. LCO 3.6.6, Containment Spray System Condition A was entered 6 hours ago. The IA Containment Spray pump is eXEected to be returned to service in 16 hours. SI/Test in progress/planned: (including need for new brief) Major Activities/Procedures in progress/planned: Predictive Maintenance has requested the 1 C #3 heater drain pump be removed from service for a shaft alignment due to concerns over the inboard motor bearing vibration trend. Operations Management has requested a power reduction to 85% at a rate of 1 %/minute to prepare for pump shutdown. Plant is currently at 100% power, MOL. RCS boron concentration is 877 Epm. Decision to Eerform shutdown was made 30 minutes ago. Use AOI-39, "Rapid Load Reduction," for the Eower reduction. information for shutdown. Control Bank D is at 220 steps. Train A Week - ChannelL Radiological changes in plant during shift: Part 2 - Performed by on-coming shift D A review of the Operating Log since last held shift or 3 days, whichever is less (N/A for AUOs) D A review of the Rounds sheets/Abnormal readings (ADOs only) Review the following programs for changes since last shift turnover: D Standing Orders D LCO(s) in actions (N/A for AUOs) D PER review D lImnediate required reading D TACF (N/A for AUOs) (N/A for AUOs) Part 3 - Performed by both off-going and on-coming shift D A walkdown of the MCR control boards (N/A for AUOs) Relief Time: Relief Date: TVA 40741 [06-2008] Page 1 of 1 OPDP-l-l [06-12-2008] SHIFT TURNOVER CHECKLIST P 2 f2 age 0 SHIFT TURNOVER CHECKLIST Page ___ of -- D SM D US/MCR Unit ~ UO Unit Off-going - Name D AUO Station D STA (STA Function) On-coming - Name Part 1 - Completed by off-going shiftlReviewed by on-coming shift: Abnonnal equipment lineup/conditions: IA Containment S.Qray pump is out of service for bearing replacement. LCO 3.6.6, Containment Spray System Condition A was entered 6 hours ago. The I A Containment Spray pump is eX.Qected to be returned to service in 16 hours. SIlT est in progress/planned: (including need for new brief) Major Activities/Procedures in progress/planned: Predictive Maintenance has requested the I C #3 heater drain pump be removed from service for a shaft alignment due to concerns over the inboard motor bearing vibration trend. Operations Management has requested a power reduction to 85% at a rate of I %/minute to prepare for pump shutdown. Plant is currently at 100% power, MOL. RCS boron concentration is 877.Qpm. Decision to.Qerfonn shutdown was made 30 minutes ago. Use AOI-39, "Rapid Load Reduction," for the power reduction. infonnation for shutdown. Control Bank D is at 220 steps. Train A Week - Channel I. Radiological changes in plant during shift: Part 2 - Performed by on-coming shift D A review of the Operating Log since last held shift or 3 days, whichever is less (N/A for AUOs) D A review of the Rounds sheets/Abnonnal readings (AUOs only) Review the following programs for changes since last shift turnover: D Standing Orders D LCO(s) in actions (N/ A for AUOs) D PER review D Innnediate required reading D TACF (N/A for AUOs) (N/A for AUOs) Part 3 - Performed by both off-going and on-coming shift D A walkdown of the MCR control boards (N/A for AUOs) Relief Time: Relief Date: TVA 40741 [06-2008] Page 1 ofl OPDP-I-I [06-12-2008]
~ppendix 0 Scenario Outline Form ES-D-1 Facility: Watts Bar Fall NRC Scenario No.: 3 Op Test No.: 1 Exam 2009 Examiners: Operators: SRO RO BOP Initial Conditions: 100% power, MOL. RCS boron concentration is 877 ppm. Train A/Channel III Work Week. Turnover: 1A Containment Spray pump is out of service for bearing replacement. LCO 3.6.6, Containment Spray System Condition A was entered 6 hours ago. The 1A Containment Spray pump is expected to be returned to service in 16 hours. Predictive Maintenance has requested the 1 C #3 heater drain pump be removed from service for a shaft alignment due to concerns over the inboard motor bearing vibration trend. Train A/Channel I Work Week. Event Malf. No. Event Type* Event Description No. 1 N/A R-RO Power reduction to 85% in preparation for removing 1 C #3 Heater Drain N-BOP Pump from service for repairs. 2 RX07A I-RO Controlling Pressurizer Pressure Channel Fails HIGH. RO takes manual RC08B TS-SRO control of pressurizer pressure. Tech Spec Evaluation 3 FW56C C-BOP Conditions given inthe turnover worsen. 1 C #3 heater drain pump experiences motor overload, requiring the pump to be tripped. Requires entry into AOI-37, "Turbine Runback Response." ) 4 RX18 I-RO Tavg Auctioneering circuit fails LOW. RO takes manual control of rods. 5 RX26E I-BOP Steam Generator Pressure transmitter 1-PT-1-9A fails LOW. BOP takes TS-SRO manual control of #3 SG main feed water regulating valve to control level. Enters AOI-16, "Loss of Normal Feedwater." Tech Spec Evaluation. 6 MS05B C-BOP Steam leak inside containment. Enter AOI-38, "Main Steam or Feedwater Line Leak". Leak increases requiring the crew to manually trip the reactor. After the reactor trip is successful, a steam leak inside containment occurs. 7 RP01A M-ALL Reactor fails to trip automatically and manually. Crew enters FR-S.1 for RP01B the ATWS. RP01C 8 MS28A C-BOP Failure of automatic isolation of all MSIVs. Requires BOP to manually MS28B close all 4 MSIVs. MS28C MS28D (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Appendix 0 Watts Bar NRC Exam May 2009 NUREG 1021 Revision 9 r;ppendix 0 Scenario Outline Form ES-O-1 Facility: Watts Bar Fall NRC Scenario No.: 3 Op Test No.: 1 Exam 2009 Examiners: Operators: SRO RO BOP Initial Conditions: 100% power, MOL. RCS boron concentration is 877 ppm. Train AlChannelll1 Work Week. Turnover: 1A Containment Spray pump is out of service for bearing replacement. LCO 3.6.6, Containment Spray System Condition A was entered 6 hours ago. The 1A Containment Spray pump is expected to be returned to service in 16 hours. Predictive Maintenance has requested the 1 C #3 heater drain pump be removed from service for a shaft alignment due to concerns over the inboard motor bearing vibration trend. Train AlChannel I Work Week. I Event Malf. No. Event Type* Event Description No. 1 N/A R-RO Power reduction to 85% in preparation for removing 1 C #3 Heater Drain N-BOP Pump from service for repairs. 2 RX07A I-RO Controlling Pressurizer Pressure Channel Fails HIGH. RO takes manual RC08B TS-SRO control of pressurizer pressure. Tech Spec Evaluation 3 FW56C C-BOP Conditions given in the turnover worsen. 1 C #3 heater drain pump experiences motor overload, requiring the pump to be tripped. Requires entry into AOI-37, "Turbine Runback Response." 4 RX18 I-RO Tavg Auctioneering circuit fails LOW. RO takes manual control of rods. 5 RX26E I-BOP Steam Generator Pressure transmitter 1-PT-1-9A fails LOW. BOP takes TS-SRO manual control of #3 SG main feed water regulating valve to control level. Enters AOI-16, "Loss of Normal Feedwater." Tech Spec Evaluation. 6 MS05B C-BOP Steam leak inside containment. Enter AOI-38, "Main Steam or Feedwater Line Leak". Leak increases requiring the crew to manually trip the reactor. After the reactor trip is successful, a steam leak inside containment occurs. 7 RP01A M-ALL Reactor fails to trip automatically and manually. Crew enters FR-S.1 for RP01B the ATWS. RP01C 8 MS28A C-BOP Failure of automatic isolation of all MSIVs. Requires BOP to manually MS28B close all 4 MSIVs. MS28C MS28D (N)ormal, (R)eactivity, (I)nstrument, (C)omponent, (M)ajor Appendix 0 Watts Bar NRC Exam May 2009 NUREG 1021 Revision 9
!6ppendix D Scenario Outline Form ES-D-1 Scenario 3 - Summary Initial Condition 100% power, MOL. RCS boron concentration is 877 ppm. Train AlChannel1 Work Week. Turnover 1A Containment Spray pump is out of service for bearing replacement. LCO 3.6.6, Containment Spray System Condition A was entered 6 hours ago. The 1A Containment Spray pump is expected to be returned to service in 16 hours. Predictive Maintenance has requested the 1 C #3 heater drain pump be removed from service for a shaft alignment due to concerns over the inboard motor bearing vibration trend. Train AlChannel I Work Week. Event 1 Power reduction to 85% power in preparation for removing 1 C #3 Heater Drain Pump from service. Power reduction to be accomplished at 1 %/min. rate. Event 2 The controlling pressurizer pressure channel (PT-68-340) will fail high resulting in pressurizer spray valves fully opening and requiring manual action to close to stop the RCS depressurization. The SRO will direct performance of AOI-18 to select another controlling channel and return spray control to automatic. SRO will evaluate and enter applicable Reactor Protection and ESFAS instrumentation Technical specifications. Event 3 Conditions given in the turnover worsen. 1 C #3 heater drain pump amps increase causing a motor overload, requiring the pump to be tripped. Requires entry into AOI-37. Event 4 Tavg Auctioneering circuit fails HIGH. RO takes manual control of rods. Event 5 Steam Generator Pressure transmitter 1-PT-1-9A fails LOW. BOP takes manual control of
- 3 SG main feed water regulating valve to control level. Enters AOI-16. Tech Spec Evaluation.
Event 6 Steam leak inside containment. Enter AOI-38 to determine location and severity of leak. Leak size increases requiring the crew to manually trip the reactor, per AOI-38. After the decision is made to trip the reactor, steam leak inside containment propagates. Event 7 Reactor fails to trip automatically and manually. Crew enters FR-S.1 for actions to take for the ATWS. Event 8 Failure of automatic isolation of all MSIVs. Requires BOP to manually close all 4 MSIVs. Critical Task 1 FR-S.1 -- A: Isolate the main turbine from the SGs before plant and scenario-specific criteria are exceeded. Critical Task 2 FR-S.1 -- C:lnsert negative reactivity into the core by at least one of the following methods before completing the immediate-action steps of FR-S. 1: De-energize the control rod drive MG sets, or Insert RCCAs, or establish emergency boration flow to the RCS. Critical Task 3 Trip RCPs Due to loss of cooling on a Phase B (critical only after the reactor has tripped). Critical Task 4 Close MS/Vs. Appendix D Watts Bar NRC Exam May 2009 NUREG 1021 Revision 9 ~ppendix 0 Scenario Outline Form ES-O-1 Scenario 3 - Summary Initial Condition 100% power, MOL. RCS boron concentration is 877 ppm. Train AlChannel I Work Week. Turnover 1A Containment Spray pump is out of service for bearing replacement. LCO 3.6.6, Containment Spray System Condition A was entered 6 hours ago. The 1 A Containment Spray pump is expected to be returned to service in 16 hours. Predictive Maintenance has requested the 1C #3 heater drain pump be removed from service for a shaft alignment due to concerns over the inboard motor bearing vibration trend. Train AlChannel I Work Week. Event 1 Power reduction to 85% power in preparation for removing 1 C #3 Heater Drain Pump from service. Power reduction to be accomplished at 1 %/min. rate. Event 2 The controlling pressurizer pressure channel (PT-68-340) will fail high resulting in pressurizer spray valves fully opening and requiring manual action to close to stop the RCS depressurization. The SRO will direct performance of AOI-18 to select another controlling channel and return spray control to automatic. SRO will evaluate and enter applicable Reactor Protection and ESFAS instrumentation Technical specifications. Event 3 Conditions given in the turnover worsen. 1 C #3 heater drain pump amps increase causing a motor overload, requiring the pump to be tripped. Requires entry into AOI-37. Event 4 Tavg Auctioneering circuit fails HIGH. RO takes manual control of rods. Event 5 Steam Generator Pressure transmitter 1-PT-1-9A fails LOW. BOP takes manual control of
- 3 SG main feed water regulating valve to control level. Enters AOI-16. Tech Spec Evaluation.
Event 6 Steam leak inside containment. Enter AOI-38 to determine location and severity of leak. Leak size increases requiring the crew to manually trip the reactor, per AOI-38. After the decision is made to trip the reactor, steam leak inside containment propagates. Event 7 Reactor fails to trip automatically and manually. Crew enters FR-S.1 for actions to take for the ATWS. Event 8 Failure of automatic isolation of all MSIVs. Requires BOP to manually close all 4 MSIVs. Critical Task 1 FR-S.1 -- A: Isolate the main turbine from the SGs before plant and scenario-specific criteria are exceeded. Critical Task 2 FR-S.1 -- C:lnsen negative reactivity into the core by at least one of the following methods before completing the immediate-action steps of FR-S.1: De-energize the control rod drive MG sets, or Insen RCCAs, or establish emergency boration flow to the RCS. Critical Task 3 Trip RCPs Due to loss of cooling on a Phase B (critical only after the reactor has tripped). Critical Task 4 Close MSIVs. Appendix 0 Watts Bar NRC Exam May 2009 NUREG 1021 Revision 9
Si~tor Console Operators Instructions NRC Scenario 3 SIMULATOR SETUP INFORMATION
- 1.
ENSURE NRC Examination Security has been established.
- 2.
Right click on 349, and then select RESET.
- 3.
Enter the password.
- 4.
Select "Yes" on the INITIAL CONDITION RESET pop-up window.
- 5.
ENSURE the following information appears on the Director Summary Screen: hs-72-44a-1 05040 cntmt sump hdr a fcv R 00:00:00 00:00:00 rp01c manual and automatic reactor trip signal failure (atws) M 00:00:00 00:00:00 hs-72-39a-1 05080 cs hdr a isol vlv sw. R 00:00:00 00:00:00 hs-72-34a-1 05060 cs pump a recirc fcv R 00:00:00 00:00:00 ms28b fail auto close 1-11 M 00:00:00 00:00:00 ms28d fail auto close 1-29 M 00:00:00 00:00:00 rp01a manual reactor trip signal failure (atws) M 00:00:00 00:00:00 ms28a fail auto close 1-4 M 00:00:00 00:00:00 hs-72-27a-1 06020 cntmt spray pump a mtr sw R 00:00:00 00:00:00 hs-72-22a-1 05020 rwst spray hdr a fcv R 00:00:00 00:00:00 rp01b automatic reactor trip signal failure (atws) M 00:00:00 00:00:00 ms28c fail auto close 1-22 M 00:00:00 00:00:00 (Continued on next page) Page 1 of4 00:00:00 Off On 00:00:00 InActive Active 00:00:00 Off On 00:00:00 Off Off 00:00:00 InActive Active 00:00:00 InActive Active 00:00:00 InActive Active 00:00:00 InActive Active 00:00:00 Off Off 00:00:00 Off Off 00:00:00 InActive Active 00:00:00 InActive Active Sirk~tor Console Operators Instructions NRC Scenario 3 SIMULATOR SETUP INFORMATION
- 1.
ENSURE NRC Examination Security has been established.
- 2.
Right click on 349, and then select RESET.
- 3.
Enter the password.
- 4.
Select "Yes" on the INITIAL CONDITION RESET pop-up window.
- 5.
ENSURE the following information appears on the Director Summary Screen: Key Type Event Delay Inserted hs-72-44a-1 05040 cntmt sump hdr a fcv R 00:00:00 00:00:00 rp01c manual and automatic reactor trip signal failure (atws) M 00:00:00 00:00:00 hs-72-39a-1 05080 cs hdr a isol vlv sw. R 00:00:00 00:00:00 hs-72-34a-1 05060 cs pump a recirc fcv R 00:00:00 00:00:00 ms28b fail auto close 1-11 M 00:00:00 00:00:00 ms28d fail auto close 1-29 M 00:00:00 00:00:00 rp01a manual reactor trip signal failure (atws) M 00:00:00 00:00:00 ms28a fail auto close 1-4 M 00:00:00 00:00:00 hs-72-27a-1 06020 cntmt spray pump a mtr sw R 00:00:00 00:00:00 hs-72-22a-1 05020 rwst spray hdr a fcv R 00:00:00 00:00:00 rp01b automatic reactor trip signal failure (atws) M 00:00:00 00:00:00 ms28c fail auto close 1-22 M 00:00:00 00:00:00 (Continued on next page) Page 1 of 4 Ramp Initial Final Value 00:00:00 Off On 00:00:00 InActive Active 00:00:00 Off On 00:00:00 Off Off 00:00:00 InActive Active 00:00:00 InActive Active 00:00:00 InActive Active 00:00:00 InActive Active 00:00:00 Off Off 00:00:00 Off Off 00:00:00 InActive Active 00:00:00 InActive Active
Si~tor Console Operators Instructions NRC Scenario 3 SIMULATOR SETUP INFORMATION rx07a pzr pressure transmitter fails to position chnl 1 68-340 M 1 00:00:00 ms05b main steam line leak in containment sg #2 M 19 00:00:00 fw56c hdp 3c bearing wear M 2 00:00:00 rdr01 rod control mg set #1 bkr R 20 00:00:00 rdr02 rod control mg set #2 bk R 20 00:00:00 rp51b reactor trip breaker rtb trip M 21 00:00:00 rp51a reactor trip breaker rta trip M 21 00:00:00 rx18 t-avg control signal failure M 3 00:00:00 rx26e stm gen pres transmitter failure, chnl i pt-1-20a M 4 00:00:00 ms05b main steam line leak in containment sg #2 M 5 00:00:00
- 6.
,Place simulator in RUN and acknowledge any alarms. 00:00:00 100 66.875 00:00:00 10 0 00:01:30 9.5 0 00:00:00 trip close 00:00:00 trip close 00:00:00 Active InActive 00:00:00 Active InActive 00:00:00 20 56.342 00:00:00 0 77.708 00:00:30 1 0
- 7.
Place 18-8 Containment Spray pump handswitch in the STOP-PULL-TO-LOCK position. Close, then hang HOLD NOTICE card on handswitch, 1-FCV-72-39Aand 1-FCV-72-44A. Place PROTECTED EQUIPMENT (Pink Tag) on 18-8 CSS handswitch.
- 8.
ENSURE the "Train A Week - Channell" sign is placed on 1-M-30.
- 9.
Place simulator in FREEZE. Page 2 of4 Sin.,_-"tor Console Operators Instructions NRC Scenario 3 SIMULATOR SETUP INFORMATION rx07a pzr pressure transmitter fails to position chnl 1 68-340 M 1 00:00:00 ms05b main steam line leak in containment sg #2 M 19 00:00:00 fw56c hdp 3c bearing wear M 2 00:00:00 rdr01 rod control mg set #1 bkr R 20 00:00:00 rdr02 rod control mg set #2 bk R 20 00:00:00 rp51 b reactor trip breaker rtb trip M 21 00:00:00 rp51a reactor trip breaker rta trip M 21 00:00:00 rx18 t-avg control signal failure M 3 00:00:00 rx26e stm gen pres transmitter failure, chnl i pt-1-20a M 4 00:00:00 ms05b main steam line leak in containment sg #2 M 5 00:00:00
- 6.
Place simulator in RUN and acknowledge any alarms. 00:00:00 100 66.875 00:00:00 10 0 00:01 :30 9.5 0 00:00:00 trip close 00:00:00 trip close 00:00:00 Active InActive 00:00:00 Active InActive 00:00:00 20 56.342 00:00:00 0 77.708 00:00:30 1 0
- 7.
Place 18-8 Containment Spray pump handswitch in the STOP-PULL-TO-LOCK position. Close, then hang HOLD NOTICE card on handswitch, 1-FCV-72-39A and 1-FCV-72-44A. Place PROTECTED EQUIPMENT (Pink Tag) on 18-8 CSS handswitch.
- 8.
ENSURE the "Train A Week - Channell" sign is placed on 1-M-30.
- 9.
Place simulator in FREEZE. Page 2 of4
Simulator Console Operators Instructions NRC Scenario 3 EVENT INITIATION AND ROLE PLAY Simulator Event 1 NONE Power reduction to 85% in preparation for removing 1 C #3 Heater Drain Pump from service for repairs. ROLE PLA Y: NONE 2 1 Controlling Pressurizer Pressure Channel Fails HIGH. ROLE PLA Y: When contacted as Work Control, report that the channel failure will be addressed as soon as an individual is available. 3 2 Conditions given in the turnover worsen. 1 C #3 heater drain pump amps increase causing a motor overload, requiring the pump to be tripped. Requires entry into AOI-37. ROLE PLA Y: When contacted as Turbine Bldg. AUO, report that the 1C #3 HD pump tripped due to overcurrent. As Support AUO, report #3 HD Tank levels to the BOP. Use INSIGHT auo screen to view levels. 4 3 Tavg Auctioneering circuit fails LOW. RO takes manual control of rods. ROLE PLA Y: When contacted as Work Control, report that the channel failure will be addressed as soon as an individual is available. 5 4 Steam Generator Pressure transmitter 1-PT-1-9A fails LOW. ROLE PLA Y: When contacted as Work Control, report that the channel failure will be addressed as soon as an individual is available. 6 5 Steam leak inside containment. Enter AOI-38 to determine location and severity of leak. Leak size increases requiring the crew to manually trip the reactor, per AOI-38. After the reactor trip is successful, steam leak inside containment propagates. Page 3 of 4 \\ i Simulator Console Operators Instructions NRC Scenario 3 EVENT INITIATION AND ROLE PLAY Exam Event Simulator Event DESCRIPTION/ROLE PLAY 1 NONE Power reduction to 85% in preparation for removing 1 C #3 Heater Drain Pump from service for repairs. ROLE PLA Y: NONE 2 1 Controlling Pressurizer Pressure Channel Fails HIGH. ROLE PLA Y: When contacted as Work Control, report that the channel failure will be addressed as soon as an individual is available. 3 2 Conditions given in the turnover worsen. 1 C #3 heater drain pump amps increase causing a motor overload, requiring the pump to be tripped. Requires entry into AOI-37. ROLE PLA Y: When contacted as Turbine Bldg. AUO, report that the 1C #3 HD pump tripped due to overcurrent. As Support AUO, report #3 HD Tank levels to the BOP. Use INSIGHT auo screen to view levels. 4 3 Tavg Auctioneering circuit fails LOW. RO takes manual control of rods. ROLE PLA Y: When contacted as Work Control, report that the channel failure will be addressed as soon as an individual is available. 5 4 Steam Generator Pressure transmitter 1-PT 9A fails LOW. ROLE PLA Y: When contacted as Work Control, report that the channel failure will be addressed as soon as an individual is available. 6 5 Steam leak inside containment. Enter AOI-38 to determine location and severity of leak. Leak size increases requiring the crew to manually trip the reactor, per AOI-38. After the reactor trip is successful, steam leak inside containment propagates. Page 3 of 4
Simulator Console Operators Instructions NRC Scenario 3 EVENT INITIATION AND ROLE PLAY Simulator Event 7 NONE Reactor fails to trip automatically and manually. Crew enters FR-S.1 for actions to take for the ATWS. ROLE PLA Y: 2 minutes after being dispatched to the reactor trip breakers and the Rod Drive MG set input breakers, delete the auto and manual trip failure malfunctions, and enter Event 20 to trip the rod drive mg sets, then enter Event 21 to trip the reactor trip breakers. 8 NONE Failure of automatic isolation of all MSIVs. Requires BOP to manually close all 4 MSIVs. Page 4 of 4 Simulator Console Operators Instructions NRC Scenario 3 EVENT INITIATION AND ROLE PLAY Exam Event Simulator Event DESCRIPTION/ROLE PLAY 7 NONE Reactor fails to trip automatically and manually. Crew enters FR-S.1 for actions to take for the ATWS. ROLE PLA Y: 2 minutes after being dispatched to the reactor trip breakers and the Rod Drive MG set input breakers, delete the auto and manual trip failure malfunctions, and enter Event 20 to trip the rod drive mg sets, then enter Event 21 to trip the reactor trip breakers. 8 NONE Failure of automatic isolation of all MSIVs. Requires BOP to manually close all 4 MSIVs. Page 4 of 4
[Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 3 Event # Page of _2;;;.4.;.....~ Event
Description:
Power reduction to 85% in preparation for removing 1 C #3 Heater Drain Pump from service for repairs. Time Position Al2.P.licant's Actions or Behavior EXAMINER: The following actions are from AOI-39, "Rapid Load Reduction," Section 3.2, "Power Reduction From Greater than 50% Power." CAUTION Condenser Backpressure limits are on previous page. CAUTION TURBINE MANUAL Operation requires continuous operator monitoring and control. CAUTION LOSS OF CONDENSER VACUUM may be made worse if steam dumps are actuated. AOI-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.
- 1. ESTABLISH a turbine load reduction rate less than or equal to 5% / min:
SRO
- a.
SET a desired load in the SETTER with the REFERENCE RO CONTROL.
- b. SET the LOAD RATE at less than or equal to 5% / min.
- c.
DEPRESS GO pushbutton. CAUTION Over boration may result in excessive rod withdrawal or Tavg lower than desired for at power conditions. NOTE 1 Rod Control should remain in automatic for Tavg Control. NOTE 2 The following Table assumes - 1/3 reactivity by rod insertion during the load reduction. The RCS boron concentration may be adjusted should delta I or RILs . criteria be approached. Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 I Appendix 0 . Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 3 Event # Page _1 _ of _2;;;..4~-I1 Event
Description:
Power reduction to 85% in preparation for removing 1 C #3 Heater Drain Pump from service for repairs. Time II Position II Applicant's Actions or Behavior EXAMINER: The following actions are from AOI-39, "Rapid Load Reduction," Section 3.2, "Power Reduction From Greater than 50% Power." CAUTION Condenser Backpressure limits are on previous page. CAUTION TURBINE MANUAL Operation requires continuous operator monitoring and control. CAUTION LOSS OF CONDENSER VACUUM may be made worse if steam dumps are actuated. AOI-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.
- 1. ESTABLISH a turbine load reduction rate less than or equal to 5% / min:
SRO
- a.
SET a desired load in the SETTER with the REFERENCE RO CONTROL.
- b.
SET the LOAD RATE at less than or equal to 5% / min.
- c.
DEPRESS GO pushbutton. CAUTION Over boration may result in excessive rod withdrawal or Tavg lower than desired for at power conditions. NOTE 1 Rod Control should remain in automatic for Tavg Control. NOTE 2 The following Table assumes - 1/3 reactivity by rod insertion during the load reduction. The RCS boron concentration may be adjusted should delta lor RILs criteria be approached. Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
[ Appendix 0 Required Operator Actions Form ES-D-2 I Op Test No.: Event
Description:
NRC Scenario # 3 Event # Page 2 of 24 Power reduction to 85% in preparation for removing 1 C #3 Heater Drain Pump from service for repairs. Time -II Position Ir Applicant's Actions or Behavior
- 2.
INITIATE a manual boration:
- a. DETERMINE recommended boration flowrate and volume from table belolN.
TURBINE LOAD BORATION BORIC ACID VOLUME REDUCTION RATE FLOWRATE TO REDUCE POWER (%/min) (galimin} FROM 1{)O% TO 20% 2{}/o 20 GPrvl 3°!~ 30 GPM -. 800 G.ALs >4% 40 GPM TOTAL RO
- b. INITIATE boration to maintain control rods above low-low insertion limit:
1 )ADJUST SA flow controller, 1-FC-62-139, to desired flow rate. 2)ADJUST SA batch counter 1-FQ-62-139 to required quantity. 3)PLACE mode selector 1-HS-62-140S toBOR. 4)PLACE VCT makeup controI1-HS-62-140A, to START. 5)VERIFY desired boric acid flow indicated on 1-FI-62-139. SRO REFER to EPIP-1, Emergency Plan Classification Flowchart. EXAMINER: Step is N/A for given conditions. SRO NOTIFY the Load Coordinator of the required load reduction and expected ramp rate. NOTE If reactor power is stabilized at a lower level a drop in Tavg will occur due to Xenon build up. Dilution may be required to maintain power level. SRO MONITOR Tavg and Tref: Tavg trending to Tref. RO Mismatch less than 5°F. SRO CHECK rate of power reduction is rapid enough for existing plant conditions. SRO NOTIFY Cnds Demin AUO of impending pmp shutdowns. WHEN rated thermal power change exceeds 15% in one hour, SRO NOTIFY Chemistry to initiate 1-SI-68-128. I i EXAMINER: Further steps of AOI-39, "Rapid Power Reduction" are not included, since the crew I will only reduce power to 85%, and the remainder of AOI-39 steps are power level dependent. Simulator Operator enters Event 2. Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 I Appendix 0 Op Test No.: Event
Description:
Required Operator Actions Form ES-O-2 I NRC Scenario # 3 Event # Page _2 _ of _2;;;.,4~"'1 Power reduction to 85% in preparation for removing 1 C #3 Heater Drain Pump from service for repairs. Time II Position II Applicant's Actions or Behavior
- 2.
INITIATE a manual boration:
- a. DETERMINE recommended boration flowrate and volume from table below.
TURBINE LOAD BORATION BORIC ACID VOLUME REDUCTION RATE FLOWRATE TO REDUCE POWER (%/min) (gallmin) FROM 100% TO 20% 2%/~ 20 GPI'<1 3'% 30 GPM - 800 GALs >4~!::l 40 GPM TOTAL RO
- b. INITIATE boration to maintain control rods above low-low insertion limit:
1 )ADJUST BA flow controller, 1-FC-62-139, to desired flow rate. 2)ADJUST BA batch counter 1-FQ-62-139 to required quantity. 3)PLACE mode selector 1-HS-62-140B to BOR. 4)PLACE VCT makeup controI1-HS-62-140A, to START. 5)VERIFY desired boric acid flow indicated on 1-FI-62-139. SRO REFER to EPIP-1, Emergency Plan Classification Flowchart. EXAMINER: Step is N/A for given conditions. SRO NOTIFY the Load Coordinator of the required load reduction and expected ramp rate. NOTE If reactor power is stabilized at a lower level a drop in Tavg will occur due to Xenon build up. Dilution may be required to maintain power level. SRO MONITOR Tavg and Tref: Tavg trending to Tref. RO Mismatch less than 5°F. SRO CHECK rate of power reduction is rapid enough for existing plant conditions. SRO NOTIFY Cnds Demin AUO of impending pmp shutdowns. SRO WHEN rated thermal power change exceeds 15% in one hour, NOTIFY Chemistry to initiate 1-SI-68-128. EXAMINER: Further steps of AOI-39, "Rapid Power Reduction" are not included, since the crew will only reduce power to 85%, and the remainder of AOI-39 steps are power level dependent. Simulator Operator enters Event 2. Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
[Appendix D Required Operator Actions Form ES-D-2 1 Op Test No.: NRC Scenario # 3 Event # 2 Page 3 of 24 Event
Description:
1-PT-68-340, Channell Pressurizer Pressure Transmitter, fails HIGH. Requires entry into AOI-18, :Malfunction of Pressurizer Pressure Control System." Time l[ Position A2Qlicant's Actions or Behavior Indications: 90-A PZR PRESS HI 124-B PZR PRESS HI Actual RCS pressure dropping rapidly. Both pressurizer spray valves fully open RO Diagnose and announce failure of 1-PT-68-340 high. SRO Enter and direct actions of AOI-18, "Malfunction of Pressurizer Pressure Control System." EXAMINER: The following actions are from AOI-18, "Malfunction of Pressurizer Pressure Control System." NOTE 120 AC VITAL PWR BD 1-IV [breaker 2] supplies the plugmold power strip associated with both PZR spray valves and several other instruments required to respond to this event.
- 1. CHECK pressurizer pressure stable or trending to desired pressure:
- 1-PI-68-340A, RO
- 1-PI-68-334,
- 1-PI-68-323,
- 1-PI-68-322.
- 1. RESPONSE NOT OBTAINED: PLACE pzrmaster controller 1-RO PIC-68-340A in MANUAL and RESTORE press to normal.
EXAMINER: Causes backup heaters to come ON. RO
- 2. CHECK 1-XS-68-340D selected to a failed controlling or backup channel.
- 3. RESTORE press control to normal:
- a.
SELECT operable channels for control and backup with 1-XS-68-340D.
- b.
ENSURE operable channel selected for recording with 1-XS-RO 68-340B.
- c.
ENSURE TR-68-2A placed to operable channel using 1-XS-68-2B, In RCDR TR-68-2A LOOP SELECT [1-M-5].
- d. WHEN Pressurizer pressure on program, THEN RETURN Pzr master controller 1-PIC-68-340A to AUTO.
SRO
- 4. NOTIFY Work Control to remove failed channel from service.
SRO
- 5. **GO TO Step 17.
Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 3 Event # ....;2;;..... ____ Page _3 _ of _2;;.,4;""-"'1 Event
Description:
1-PT-68-340, Channell Pressurizer Pressure Transmitter, fails HIGH. Requires entry into AOI-18, :Malfunction of Pressurizer Pressure Control System." Time II Position II Applicant's Actions or Behavior Indications: 90-A PZR PRESS HI 124-B PZR PRESS HI Actual RCS pressure dropping rapidly. Both pressurizer spray valves fully open RO Diagnose and announce failure of 1-PT-68-340 high. SRO Enter and direct actions of AOI-18, "Malfunction of Pressurizer Pressure Control System." EXAMINER: The following actions are from AOI-18, "Malfunction of Pressurizer Pressure Control System." NOTE 120 AC VITAL PWR BD 1-IV [breaker 2] supplies the plugmold power strip associated with both PZR spray valves and several other instruments required to respond to this event.
- 1. CHECK pressurizer pressure stable or trending to desired pressure:
- 1-PI-68-340A, RO
- 1-PI-68-334,
- 1-PI-68-323,
- 1-PI-68-322.
- 1. RESPONSE NOT OBTAINED: PLACE pzr master controller 1-RO PIC-68-340A in MANUAL and RESTORE press to normal.
EXAMINER: Causes backup heaters to come ON. RO
- 2. CHECK 1-XS-68-340D selected to a failed controlling or backup channel.
- 3. RESTORE press control to normal:
- a.
SELECT operable channels for control and backup with 1-XS-68-340D.
- b.
ENSURE operable channel selected for recording with 1-XS-RO 68-340B.
- c.
ENSURE TR-68-2A placed to operable channel using 1-XS-68-2B, LlT RCDR TR-68-2A LOOP SELECT [1-M-5].
- d.
WHEN Pressurizer pressure on program, THEN RETURN Pzr master controller 1-PIC-68-340A to AUTO. SRO
- 4. NOTIFY Work Control to remove failed channel from service.
SRO
- 5. **GO TO Step 17.
Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
) ) [Appendix D Required Operator Actions Form ES-D-2 1 i Op Test No.: Event
Description:
NRC Scenario # 3 Event # 2 Page 4 of _2;;;..4~-I1 1-PT-68-340, Channel I Pressurizer Pressure Transmitter, fails HIGH. Requires entry into AOI-18, :Malfunction of Pressurizer Pressure Control System." Time II Position* II Applicant's Actions or Behavior SRO
- 17. REFER TO the following Tech Specs:
3.3.1 Function 6. Overtemperature Ll T, Condition W, With one channel inoperable, place the channel in trip within 72 hours OR Be in Mode 3 within 78 hours. Function 8a. Pressurizer Pressure - Low, Condition X, With one channel inoperable, place the channel in trip within 72 hours, OR reduce THERMAL POWER to <P-7 within 78 hours. Function 8b. Pressurizer Pressure - High, Condition W, With one channel inoperable, place the channel in trip within 72 hours OR Be in Mode 3 within 78 hours. 3.3.2 Function 1.d, Pressurizer Pressure - Low, Condition D, With one channel inoperable, place the channel in trip within 72 hours OR be in Mode 3 within 78 hours AND be in Mode 4 within 84 hours. Function 8.b Pressurizer Pressure, P-11, Condition L, With one P-11 interlock channel inoperable, verify interlock is in required state for existing unit conditions within 1 hour OR be in Mode 3 within 7 hours AND be in Mode 4 within 13 hours. 3.4.1 ReS Pressure, Temperature, and Flow Departure from Nucleate Boiling (DNB) Limits Action A. One or more RCS DNB parameters not within limits, Restore RCS DNB parameter(s) to within limits within 2 hours. SRO
- 18. INITIATE repairs to failed equipment.
SRO
- 19. RETURN TO Instruction in effect.
SRO Crew Brief - conduct for this event as time allows prior to the next event. SRO Notifications should be addressed as applicable if not specifically addressed by the procedure orin the crew brief. Operations Management - Shift Manager. SRO Maintenance Personnel - Maintenance Shift Supervisor (MSS). (Note: Maintenance notification maybe delegated to the Shift Manager). Simulator operator enters Event 3 Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 I Appendix 0 Op Test No.: Event
Description:
Required Operator Actions Form ES-O-2 I NRC Scenario # 3 Event # 2 Page _4 __ of ....;2;;;..4~-I1 1-PT-68-340, Channell Pressurizer Pressure Transmitter, fails HIGH. Requires entry into AOI-18, :Malfunction of Pressurizer Pressure Control System." Time II Position II Applicant's Actions or Behavior SRO
- 17. REFER TO the following Tech Specs:
3.3.1 Function 6. Overtemperature Ll T, Condition W, With one channel inoperable, place the channel in trip within 72 hours OR Be in Mode 3 within 78 hours. Function 8a. Pressurizer Pressure - Low, Condition X, With one channel inoperable, place the channel in trip within 72 hours, OR reduce THERMAL POWER to <P-7 within 78 hours. Function 8b. Pressurizer Pressure - High, Condition W, With one channel inoperable, place the channel in trip within 72 hours OR Be in Mode 3 within 78 hours. 3.3.2 Function 1.d, Pressurizer Pressure - Low, Condition D, With one channel inoperable, place the channel in trip within 72 hours OR be in Mode 3 within 78 hours AND be in Mode 4 within 84 hours. Function 8.b Pressurizer Pressure, P-11, Condition L, With one P-11 interlock channel inoperable, verify interlock is in required state for existing unit conditions within 1 hour OR be in Mode 3 within 7 hours AND be in Mode 4 within 13 hours. 3.4.1 ReS Pressure, Temperature, and Flow Departure from Nucleate BOiling (DNB) Limits Action A. One or more RCS DNB parameters not within limits, Restore RCS DNB parameter(s) to within limits within 2 hours. SRO
- 18. INITIATE repairs to failed equipment.
SRO
- 19. RETURN TO Instruction in effect.
SRO Crew Brief - conduct for this event as time allows prior to the next event. SRO Notifications should be addressed as applicable if not specifically addressed by the procedure or in the crew brief. Operations Management - Shift Manager. SRO Maintenance Personnel-Maintenance Shift Supervisor (MSS). (Note: Maintenance notification maybe delegated to the Shift Manager). Simulator operator enters Event 3 Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
I Appendix D Required Operator Actions Form ES-D-2 ) Op Test No.: NRC Scenario # 3 Event # 3 Page 5 of 24 Event
Description:
1 C #3 Heater drain pp. is tripped due to bearing failure, requiring a load reduction. Time Position II Applicant's Actions orBehavior White light on 1 C #3 heater drain pump handswitch LIT. 14-D, M-1 THRU M-6 MOTOR OVERLOAD Increasing amps on 1 C #3 heater drain pump. BOP Announce motor overload on 1 C #3 heater drain pump. SRO Directs trip of 1 C #3 heater drain tank pump. SRO May enter and direct actions of AOI-39, "Rapid Load Reduction." SRO May enter and direct actions of AOI-37, "Turbine Runback." EXAMINER: The following actions are from AOI-39, "Rapid Load Reduction." CAUTION Condenser Backpressure limits are on previous page. CAUTION TURBINE MANUAL Operation requires continuous operator monitoring and control. CAUTION LOSS OF CONDENSER VACUUM may be made worse if steam dumps are actuated. AOI-11, "Loss of Condenser Vacuum," requires T -ave and T -ref be maintained within 3°F. NOTE If the initiating condition is corrected, the power reduction may be terminated. I I
- 1. ESTABLISH a turbine load reduction rate less than or equal to 5%/min:
- a. SET a desired load in the SETTER with the REFERENCE BOP CONTROL.
- b. SET the LOAD RATE at less than of equal to 5%/min.
- c. DEPRESS GO pushbutton.
I CAUTION Over boration may result in excessive rod withdrawal or Tavg lower than desired for at power conditions. NOTE 1 Rod Control should remain in automatic for Tavg Control. NOTE 2 The following Table assumes - 1/3 reactivity by rod insertion during the load reduction. The RCS boron concentration may be adjusted should ~I or RILs criteria be approached. -~ Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 3 Event # 3 Page _5 _ of ....;2;;..4~~1 Event
Description:
1 C #3 Heater drain pp. is tripped due to bearing failure, requiring a load reduction. Time Position II Applicant's Actions orBehavior White light on 1 C #3 heater drain pump handswitch LIT. 14-D, M-1 THRU M-6 MOTOR OVERLOAD Increasing amps on 1 C #3 heater drain pump. BOP Announce motor overload on 1 C #3 heater drain pump. SRO Directs trip of 1 C #3 heater drain tank pum p. SRO May enter and direct actions of AOI-39, "Rapid Load Reduction." SRO May enter and direct actions of AOI-37, "Turbine Runback." EXAMINER: The following actions are from AOI-39, "Rapid Load Reduction." CAUTION Condenser Backpressure limits are on previous page. CAUTION TURBINE MANUAL Operation requires continuous operator monitoring and control. CAUTION LOSS OF CONDENSER VACUUM may be made worse if steam dumps are actuated. AOI-11, "Loss of Condenser Vacuum," requires T -ave and T -ref be maintained within 3°F. NOTE If the initiating condition is corrected, the power reduction may be terminated.
- 1. ESTABLISH a turbine load reduction rate less than or equal to 5%/min:
- a. SET a desired load in the SETTER with the REFERENCE BOP CONTROL.
- b. SET the LOAD RATE at less than of equal to 5%/min.
- c. DEPRESS GO pushbutton.
CAUTION Over boration may result in excessive rod withdrawal or Tavg lower than desired for at power conditions. NOTE 1 Rod Control should remain in automatic for Tavg Control. NOTE 2 The following Table assumes - 1/3 reactivity by rod insertion during the load reduction. The RCS boron concentration may be adjusted should L\\I or RILs criteria be approached. Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
[Appendix D Required Ogerator Actions Form ES-D-2 1 Op Test No.: NRC Scenario # 3 Event # 3 Page 6 of _2;;;..4~..., Event
Description:
1 C #3 Heater drain pp. is tripped due tei bearing failure, requiring a load reduction. Time ll-position Applicant's Actions or Behavior
- 2. INITIATE a manual boratioll: **..
- a. DETERMINE recommended boration flowrate and volume from table below.
TURBINE LOAD BORATION BORIC ACID VOLUME REDUCTION RATE FLOWRATE TO REDUCE POWER (%Imin) (gallmln) FROM 100% TO 20% 2% 20GPM 3% 30GPM - 800 GALs >4% 40GPM TOTAL RO
- b. INITIATE boration to maintain control rods above low-low insertion limit:
- 1) ADJUST BA flow controller, 1-FC-62-139, to desired flow rate.
- 2) ADJUST BA batch counter 1-FQ-62-139 to required quantity.
- 3) PLACE mode selector 1-HS-62-140B to BOR.
- 4) PLACE VCT makeup controI1-HS-62-140A, to START.
- 5) VERIFY desired boric acid flow indicated on 1-FI-62-139.
) SRO
- 3. REFER TO EPIP-1, Emergency Plan Classification Flowchart.
SRO
- 4. NOTIFY the Load Coordinator of the required load reduction and expected ramp rate.
NOTE IF reactor power is stabilized at a lower level a drop in Tavg will occur due to Xenon build up. Dilution may be required to maintain power level.
- 5. MONITOR Tavg and Tref:
RO Tavg trending to Tref. Mismatch less than 5°F. SRO
- 6. CHECK rate of power reduction is rapid enough for existing plant conditions.
BOP
- 7. NOTIFY Cnds Demin AUO of impending pmp shutdowns.
SRO
- 8. WHEN rated thermal power change exceeds 15% in one hour, NOTIFY Chemistry to initiate 1-SI-68-28.
Ensures power level stabilized at approximately 80%. Directs the SRO RO to determine if additional horation is required to return AFD (ill) to within limits. Crew Brief - conduct for this event as time allows prior to the next SRO event. SRO Notifications should be addressed as applicable if not specifically addressed by the procedure or in the crew brief. Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 I Appendix D Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 3 Event # 3 Page _6 _ of ....;2;;;..4~-I1 Event
Description:
1 C #3 Heater drain pp. is tripped due to bearing failure, requiring a load reduction. Time Position Applicant's Actions or Behavior
- 2. INITIATE a manual boration:
- a. DETERMINE recommended boration flowrate and volume from table below.
TURBINE LOAD BORATION BORIC ACID VOLUME REDUCTION RATE FLOWRATE TO REDUCE POWER (%/min) (gal/min) FROM 100% TO 20% 2% 20 GPM 3% 30 GPM - 800 GALs >4% 40 GPM TOTAL RO
- b. INITIATE boration to maintain control rods above low-low insertion limit:
- 1) ADJUST BA flow controller, 1-FC-62-139, to desired flow rate.
- 2) ADJUST BA batch counter 1-FQ-62-139 to required quantity.
- 3) PLACE mode selector 1-HS-62-140B to BOR.
- 4) PLACE VCT makeup controI1-HS-62-140A, to START.
- 5) VERIFY desired boric acid flow indicated on 1-FI-62-139.
SRO
- 3. REFER TO EPIP-1, Emergency Plan Classification Flowchart.
SRO
- 4. NOTIFY the Load Coordinator of the required load reduction and expected ramp rate.
NOTE IF reactor power is stabilized at a lower level a drop in Tavg will occur due to Xenon build up. Dilution may be required to maintain power level.
- 5. MONITOR Tavg and Tref:
RO Tavg trending to Tref. Mismatch less than 5°F. SRO
- 6. CHECK rate of power reduction is rapid enough for existing plant conditions.
BOP
- 7. NOTIFY Cnds Demin AUO of impending pmp shutdowns.
SRO
- 8. WHEN rated thermal power change exceeds 15% in one hour, NOTIFY Chemistry to initiate 1-SI-68-28.
Ensures power level stabilized at approximately 80%. Directs the SRO RO to determine if additionalboration is required to return AFD (i1I) to within limits. Crew Brief - conduct for this event as time allows prior to the next SRO event. SRO Notifications should be addressed as applicable if not specifically addressed by the procedure or in the crew brief. Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
I Appendix 0 Required Operator Actions Form ES-O-2 I Op Test No.: NRC Scenario # 3 Event # 4 Page 8 of 24 Event
Description:
Tavg Auctioneering circuit fails LOW. RO takes manual control of rods. Time Position Applicant's Actions or Behavior 94-A TAVG-TREF DEVIATION 94-B TAVG TAUCT DEVIATION RO Determines rod insertion is due to a failure. May place rod control in MANUAL. RO Diagnoses and announces that RCS Auctioneered Tavg has failed. RO Enters and directs actions of AOI-2, "Malfunction of Reactor Control I System." EXAMINER: The following actions are frorn AOI-2, "Malfunction of Reactor Control I System," Sub Section 3.2, "Continuous Rod Withdrawal/Insertion." RO
- 1. PLACE control rods in MAN.
J SROIRO
- 2. CHECK control rod movement STOPPED.
- 3. MAINTAIN T -avg on PROGRAM. (Reference Attachment 1) i ROIBOP USE control rods.
OR ADJUST turbine load. I EXAMINER: Attachment 1 in step above is "Reactor Power VS TavgiTrefTemperature and PZR Level," and is included at the back of this Scenario Guide. RO
- 4. CHECK loop T -avg channels NORMAL.
I I RO
- 5. CHECK Auct Tavg NORMAL on 1-TR-68-2B.
RO
- 5. RESPONSE NOT OBTAINED: CONTROL pzr level in MAN with I
1-FCV-62-93. (Reference Attachment 1) SROIRO
- 6. CHECK NIS power range channels NORMAL.
I
- 7. CHECK the following:
ROIBOP Turbine impulse pressure channeI1-PI~1-73, NORMAL. Tref and Auct Tavg NORMAL on 1-TR-68-2B (Reference )
- 7. RESPONSE NOT OBTAINED: PLACE steam dumps in pressure mode as follows:
- a. PLACE steamdumps to OFF.
- b. PLACE mode selector HS to STEAM PRESS.
BOP
- c. ADJUST steam dump demand to zero.
- d. PLACE steam dumps to ON.
- e. ENSURE controller set at 84% (1092 psig).
- f. WHEN conditions allow, THEN REFER TO SOI-1.02 and PLACE steam dumps in TAVG Mode.
Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 I Appendix 0 Required Operator Actions Form ES-D-2 I Op Test No.: NRC Scenario # 3 Event # _4~ ____ Page _8 _ of _2_4_-11 Event
Description:
Tavg Auctioneering circuit fails LOW. RO takes manual control of rods. Time Position Applicant's Actions or Behavior 94-A TAVG-TREF DEVIATION 94-B TAVG TAUCT DEVIATION RO Determines rod insertion is due to a failure. May place rod control in MANUAL. RO Diagnoses and announces that RCS Auctioneered Tavg has failed. RO Enters and directs actions of AOI-2, "Malfunction of Reactor Control System." EXAMINER: The following actions are from AOI-2, "Malfunction of Reactor Control System," Sub Section 3.2, "Continuous Rod Withdrawal/Insertion." RO
- 1. PLACE control rods in MAN.
SROIRO
- 2. CHECK control rod movement STOPPED.
- 3. MAINTAIN T-avg on PROGRAM. (Reference Attachment 1)
ROIBOP USE control rods. OR ADJUST turbine load. EXAMINER: Attachment 1 in step above is "Reactor Power VS TavglTref Temperature and PZR Level," and is included at the back of this Scenario Guide. RO
- 4. CHECK loop T -avg channels NORMAL.
RO
- 5. CHECK Auct Tavg NORMAL on 1-TR-68-2B.
RO
- 5. RESPONSE NOT OBTAINED: CONTROL pzr level in MAN with 1-FCV-62-93. (Reference Attachment 1)
SROIRO
- 6. CHECK NIS power range channels NORMAL.
- 7. CHECK the following:
ROIBOP Turbine impulse pressure channeI1-PI-1-73, NORMAL. Tref and Auct Tavg NORMAL on 1-TR-68-2B (Reference )
- 7. RESPONSE NOT OBTAINED: PLACE steam dumps in pressure mode as follows:
- a. PLACE steam dumps to OFF.
- b. PLACE mode selector HS to STEAM PRESS.
BOP
- c. ADJUST steam dump demand to zero.
- d. PLACE steam dumps to ON.
- e. ENSURE controller set at 84% (1092 psig).
- f. WHEN conditions allow, THEN REFER TO SOI-1.02 and PLACE steam dumps in T AVG Mode.
Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9
[ Appendix D Required Operator Actions Form ES-D-2 1 Op Test No.: NRC Scenario # 3 Event # 4 Page 9 of 24 Event
Description:
Tavg Auctioneering circuit fails LOW. RO takes manual control of rods. Time Position Applicant's Actions or Behavior
- 8. MONITOR core power distribution parameters:
Power range channels. L'l Flux Indicators. RO/BOP T-avg. Loop L'lT. Incore TCs. Feed flow/Steam flow. SRO
- 9. INITIATE repairs to failed equipment.
- 10. REFER TO Tech Specs:
SRO SRO determines that there are no Tech Specs associated with the failure of the Tavg Auctioneering Unit. CAUTION Allowing at least 5 minutes between any rod control input (i.e., T-avg, T-ref, or NIS) change and placing rods in AUTO, will help prevent undesired control rod movement. SRO
- 11. NOTIFY Chemistry of any reactor power changes greater than 15% in one hour.
SRO Crew Brief - conduct for this event as time allows prior to the next event. SRO Notifications should be addressed as applicable if not specifically addressed by the procedure or in the crew brief. . Operations Management - Shift Manager. SRO Maintenance Personnel - Maintenance Shift Supervisor (MSS). (Note: Maintenance notification may be delegated to the Shift Manager). Simulator Operator enters Event 5. Appendix D Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9 I Appendix 0 Required Operator Actions Form ES-O-2 I Op Test No.: NRC Scenario # 3 Event # 4 Page _9 __ of _2_4_-11 Event
Description:
Tavg Auctioneering circuit fails LOW. RO takes manual control of rods. Time II Position II Applicant's Actions or Behavior
- 8. MONITOR core power distribution parameters:
Power range channels. L'l Flux Indicators. RO/BOP T-avg. Loop L'lT. Incore TCs. Feed flow/Steam flow. SRO
- 9. INITIATE repairs to failed equipment.
- 10. REFER TO Tech Specs:
SRO SRO determines that there are no Tech Specs associated with the failure of the Tavg Auctioneering Unit. CAUTION Allowing at least 5 minutes between any rod control input (i.e., T-avg, T-ref, or NIS) change and placing rods in AUTO, will help prevent undesired control rod movement. SRO
- 11. NOTIFY Chemistry of any reactor power changes greater than 15% in one hour.
SRO Crew Brief - conduct for this event as time allows prior to the next event. SRO Notifications should be addressed as applicable if not specifically addressed by the procedure or in the crew brief. Operations Management - Shift Manager. SRO Maintenance Personnel - Maintenance Shift Supervisor (MSS). (Note: Maintenance notification may be delegated to the Shift Manager). Simulator Operator enters Event 5. Appendix 0 Watts Bar NRC Exam November 2009 NUREG 1021 Revision 9}}