ML12073A196
| ML12073A196 | |
| Person / Time | |
|---|---|
| Site: | Watts Bar  |
| Issue date: | 04/29/2012 |
| From: | Operator Licensing and Human Performance Branch |
| To: | Tennessee Valley Authority |
| References | |
| 50-390/11-302 | |
| Download: ML12073A196 (256) | |
Text
STEP DESCRIPTION TABLE FOR FR-P.l Step 6 INSTRUMENTATION:
o RCS pressure indication o Core exit TCs temperature indication o RVLIS indication o RCP status indication o RCP support conditions status indications CONTROL/EQUIPMENT:
o RCP switches o RCP support equipment controls KNOWLEDGE:
o Understanding of RVLIS function, configuration, and interpretation o Due to the less restrictive SI termination and reinitiation criteria provided in this guideline the operator should be especially alert for any decrease in RCS subcooling or vessel level that warrants SI reinitiation FRP.l Background 29 HP-Rev. 2, 4/30/2005 HFRP1BG. doc
STEP DESCRIPTION TABLE FOR FR-P.1 Step 6 PLANT-SPECIFIC INFORMATION:
o (R.12) The sum of temperature and pressure measurement system errors, including allowances for normal channel accuracies, translated into temperature using saturation tables, plus 50°F.
o (R.13) The sum of temperature and pressure measurement system errors, including allowances for normal channel accuracies and post accident transmitter errors, translated into temperature using saturation tables, plus 50°F.
o (R.01) The sum of temperature and pressure measurement system errors, including allowances for normal channel accuracies, translated into temperature using saturation tables.
o (R.02) The suni of temperature and pressure measurement system errors, including allowances for normal channel accuracies and post accident transmitter errors, translated into temperature using saturation tables.
o (K.02) RVLIS full range value which is top of core, including allowances for instrument uncertainties.
o (L.08) RVLIS dynamic range value corresponding to an average system void fraction of 25 percent with 1 RCP running, including allowances for instrument uncertainties.
o (L.07) RVLIS dynamic range value corresponding to an average system void fraction of 25 percent with 2 RCPs running, including allowances for instrument uncertainties.
o (L.06) RVLIS dynamic range value corresponding to an average system void fraction of 25 percent with 3 RCPs running, including allowances for instrument uncertainties.
o (L.05) RVLIS dynamic range value corresponding to an average system void fraction of 25 percent with 4 RCPs running, including allowances for instrument uncertainties.
o Support conditions and means for starting an RCP o If RVLIS is not available, RCS subcooling based on core exit TCs is sufficient for terminating SI since a 50°F margin has been added to instrument uncertainties. This 50°F margin allows sufficient time for operator action to reinitiate SI before core uncovery.
o As long as the RVLIS dynamic range uncertainty for the Westinghouse RVLIS design is less than +/-6%, the uncertainty does not need to be included in the calculation of the plant-specific EOP setpoints.
FR-P.1 Background 30 HP-Rev. 2, 4/30/2005 HFRP1BG. doc
3-OT-FRP000 I Rev 12 Page 5 of 120 pages I. PROGRAM:
Watts Bar Operator Training II. COURSE:
A. License Training B. License Requalification III. TITLE:
Function Restoration Guidelines FR-P.1 & 2, Pressurized Thermal Shock IV. LENGTH OF LESSON:
A. License training 2 Hours License REQUAL time will be determined after objectives are identified.
V. TRAINING OBJECTIVES:
0 0 D
C,)
X X 1. Given a set of plant conditions, use the FR-P, Pressurized Thermal Shock Status Tree to identify and implement the appropriate Function Restoration Procedure (FR-P.1 or P.2).
X 2. Identify the major actions of FR-RI, Pressurized Thermal Shock, and explain the basis for performing each major action.
X 3. Explain why minimum detectable flow is maintained to each SIG of all the S/Gs are faulted.
X X 4. Justify the basis for using a less restrictive SI termination criteria when performing FR-RI.
X 5. Explain why an RCP should be restarted if SI cannot be terminated while performing FR-P.l, Pressurized Thermal Shock.
X X 6. Given a set of plant conditions, use the procedure FR-RI or P.2 to identify any applicable cooldown and/or pressure limitations.
3-OT-FRP0001 Rev 12 Page 6 of 120 pages V. TRAINING OBJECTIVES: (continued) 0 0 D Cl)
Cl)
X X X 7. Explain the basis for a soak period as required by FR-P.1, Pressurized Thermal Shock.
x 8. Discuss the basis for using RCS T-cold when analyzing the FR-P status tree to determine if PTS or cold overpressure concerns exist.
X X 9. Explain the basis for returning to the instruction in effect after identifying that RCS pressure < 150 psig and RHR is delivering flow when performing step 1 of FR-P.1.
X X X 10. Given a set of plant conditions, use FR-P.1, FR-P.2 and the Critical Safety Function Status Trees to correctly diagnose and implement: Action Steps, RNOs, Foldout Pages, Notes and Cautions.
x X 11. Identify the major actions of FR-P.2, Cold Overpressure Condition, and explain the basis for performing each major action.
x 12, Explain the purpose for and basis of each step in FR-P.1 and FR-P.2.
3-OT-FRP000I Rev 12
- Page 47 of 120 pages Steps 7-11: Terminate SI if Conditions Satisfied
- 7. Check ECCS in service
- Any high-head SI pump running or-
- Flow thru BIT RNO:
If SI has already been reset, go to step 16.
(Steps 8-15 terminate SI)
FR-P 1 Steps, Notes, Cautions Objective 4, 5, 10, 12 Discuss actions and bases for the steps, notes, cautions, and RNO5 in FR-PA. A copy of FR-P.1 should be used for discussion of steps, notes, cautions, and RNO actions. 3-OT-STG-FRP should be used to review/discuss FR-P.1 step bases information.
- Step 7 checks if any high-head SI pump running or CCPs injecting through the BIT to determine if SI termination steps need to be performed.
3-OT-FRP0001 Revl2
. *. Page 48 of 120 pages Steps 7-11: Terminate SI if Conditions Satisfied
- 7. Check ECCS in service
- 8. Check SI termination criteria
- RVLIS> 60% with NO RCP running, -
Or RVLIS> 63% with ANY RCP running.
- RCS subcooling > 115°F L135 °FADVI..
FR-P.1 Steps, Notes, Cautions Objective 4, 5, 10, 12 Discuss actions and bases for the steps, notes, cautions, and RNOs in FR-P.1 A copy of FR-P.1 should be used for discussion of steps, notes, cautions, and RNO actions. 3-OT-STG-FRP should be used to review/discuss FR-P.1 step bases information.
- Step 8 Note Either Loop 1 or 2 pzr spray valve is effective for Loop 2 RCP in service or Loops 1, 3, & 4 RCPs in service.
- Step 8 determines if full flow SI is required based on plant conditions.
- The combination of minimum subcooling and sufficient RVLIS level, to cover the core, represent less restrictive SI termination criteria than the SI termination criteria in other EOPs since, for an imminent PTS condition, SI flow may have contributed to the RCS cooldown or may prevent a subsequent reduction if RCS pressure.
- The RNO for this step directs restart of one RCP if RCS subcooling >65°F [85°F ADVJ and RVLIS requirements not met. An RCP restart is attempted in order to mix the cold incoming SI water and the warm reactor coolant water and thereby decrease the likelihood of a PTS condition.
RNO:
Perform the following:
- 1) IF RCS subcooling greater than 65°F [85E.DF ADV] AND NO RCP running, THEN REFER TO Table 1, RCP Emergency Restart Criteria.
- 3) When start conditions established, THEN:
a) Start one RCP, loop 2 preferred.
b) IF Loop 2 RCP can NOT be started, THEN START ALL other RCPs.
c) Stop RCP(s) oil lift pump one minute after RCP start.
d) Continue ECCS Flow.
e) Go to Note prior to Step 28.
3-CT-F RP000 I Rev 12
!_____ Page 49 of 120 pages Steps 7-11: Terminate SI if Conditions Satisfied Caution:
If offsite power is lost after SI reset, then manual action will be required to restart the SI pumps and RHR pumps.
- 9. Reset SI
- 10. Reset Phase A and B, restore power to CLA isolation valves (App A)
- 11. Ensure containment air in service FR-RI Steps, Notes, Cautions Objective 4, 5, 10, 12 Discuss actions and bases for the steps, notes, cautions, and RNOs in FR-P.1. A copy of FR-Ri should be used for discussion of steps, notes, cautions, and RNO actions. 3-OT-STG-FRP should be used to review/discuss FR-Ri step bases information.
- Step 9 directs reset of the SI signal to allow the operator to realign or stop safeguards equipment.
- Step 10 directs reset of Phase A and B to allow realignment of containment isolation valves and safeguards equipment during subsequent steps. Phase B allows restoration of control air to containment which will allow charging/letdown restoration.
Power is restored to CLA isolation valves in preparation to isolate the accumulators in subsequent steps.
- Step 11 restores control air to containment allowing control of air-operated equipment inside containment.
3-OT-FRP000 I Rev 12 Page 50 of 120 pages Steps 12-18: Terminate SI if Conditions Satisfied
- 12. Stop ECCS pumps and place in A-Auto
- 13. Align Charging
- 14. Close BIT outlet valves
- 15. Control charging flow FR-P 1 Steps, Notes, Cautions Objective 5, 10, 12 Discuss actions and bases for the steps, notes, cautions, and RNO5 in FR-P.1. A copy of FR-P.1 should be used for discussion of steps, notes, cautions, and RNO actions. 3-OT-STG-FRP should be used to review/discuss FR-Ri step bases information.
- Step 12 stops all ECCS pumps, except one CCP, and places them in A-Auto, reducing RCS injection that could contribute to RCS overpressure.
- Step 13 aligns the charging flow path to allow normal control of RCS makeup.
- Step 14 stops injection flow to the RCS through the BIT, enabling the normal charging path to control RCS makeup flow.
- Step 15 controls charging flow to maintain proper PZR level and RCP seal injection flow.
3-OT-FRP000 I
.na IJdI Rev 12 In eena Page 51 of 120 pages Steps 12-18: Terminate SI if Conditions Satisfied
- 16. Check SI termination criteria
- a. RVLIS> 60% with NO RCP running, -
Or RVLIS > 63% with ANY RCP running.
- b. RCS subcooling > 65 °F [85 °F ADV].
FR-RI Steps, Notes, Cautions Objective 5, 10, 12 Discuss actions and bases for the steps, notes, cautions, and RNOs in FR-RI. A copy of FR-P.I should be used for discussion of steps, notes, cautions, and RNO actions. 3-OT-STG-FRP should be used to review/discuss FR-RI step bases information.
Step 16 checks SI termination criteria, RVLIS and RCS subcooling, to determine if ECCS flow needs to be reinitiated. The RNO directs manually starting ECCS pumps as necessary. With inadequate RVLIS level and subcooling >65°F the RNO attempts to restart an RCP to mix the cold incoming SI water and the warm reactor coolant water.
RNO:
- a. PERFORM the following:
- 1) IF RCS subcooling greater than 65 °F [85 °F ADV] AND NO RCP running, THEN START one RCP, loop 2 preferred.
REFER TO Table 1, RCP Emergency Restart Criteria.
- 2) Manually START ECCS pumps as necessary.
- 3) GO TO Note prior to Step 28.
- b. Manually START ECCS pumps as necessary. GO TO Note prior to Step 28.
WBN 10-2011 NRC RO Exam As Submitted 8/1512011
- 27. W/E15 EG2.4.6 027 Given the following conditions:
- A large break LOCA has occurred on Unit 1.
- The crew is performing E-1, Loss of Reactor or Secondary Coolant, with the ECCS aligned for cold leg recirculation.
- The operating crew determines the criteria for entering FR-Z.2, Containment Flooding, is met.
Which ONE of the following identifies...
(1) how FR-Z.2 entry conditions being met affects the use of the Emergency Procedure network and (2) the mitigation strategy associated with sampling the sump when FR-Z.2 is implemented?
A. (1) Implementation of FR-Z.2 is required.
(2) To ensure shutdown margin is being maintained, since non-borated water has entered the containment sump.
B. (1) Implementation of FR-Z.2 is at the discretion of the crew.
(2) To ensure shutdown margin is being maintained, since non-borated water has entered the containment sump.
C (1) Implementation of FR-Z.2 is required.
(2) To determine the level of activity, to allow the TSC to determine if excess sump water can be transferred to tanks outside of containment.
D. (1) Implementation of FR-Z.2 is at the discretion of the crew.
(2) To determine the level of activity, to allow the TSC to determine if excess sump water can be transferred to tanks outside of containment.
Page 73
WBN 10-2011 NRC RO Exam As Submitted 8/1512011 DISTRA CTOR ANAL YSIS:
A. Incorrect, Plausible because the FR-Z.2 entry is due to an Orange Path condition which requires immediate entry into the procedure and if water level is high enough to meet entry conditions, then the source is from an unborated supply and SDM would be affected and a potential concern.
B. Incorrect, Plausible because there is an FR-Z entry due to a Yellow Path condition which does allow crew discretion for entry into the procedure and if water level is high enough to meet entry conditions, then the source is from an unborated supply and SDM would be affected and a potential concern.
C. Correct, FR-Z.2 is entered due to an Orange Path condition which requires immediate entry into the procedure and the sump is sampled to determine activity in order that the TSC can evaluate where to transfer the water for storage.
D. Incorrect, Plausible because there is an FR-Z entry due to a Yellow Path condition which does allow crew discretion for entry into the procedure and sampling the sump to determine activity in order that the TSC can evaluate where to transfer the water for storage is correct.
Page 74
WBN 10-2011 NRC RO Exam As Submitted 811512011 Question Number: 27 Tier: 1 Group 2 KIA: W/E15 EG2.4.6 Containment Flooding Emergency Procedures / Plan Knowledge of EOP mitigation strategies.
Importance Rating: 3.7 / 4.7 10 CFR Part 55: 41.10 /43.5 /45.13 IOCFR55A3.b: Not applicable K/A Match: K/A is matched because the question requires knowledge of the mitigation strategy for implementing FR-Z.2, Containment Flooding, and the strategy used in the procedure to allow determination of how to dispose/store the water when ready for transfer from containment.
Technical
Reference:
FR-C, Status Trees, Revision 0014 FR-Z.2, Containment Flooding, Revision 0007 WOG Emergency Procedure FR-Z.2 Background Document, Revision 2 Proposed references None to be provided:
Learning Objective: 3-OT-FRZ0001
- 12. List the three major action categories of FR-Z.2, Containment Flooding.
Cognitive Level:
Higher Lower X Question Source:
New Modified Bank X Bank Question History: WBN Bank question W/E15 EK1.2 027 modified.
Comments: W/E1 5 EK1 .2 027 used on the WBN 5/2009 Exam Page 75
WBN Status Trees FR-0 I Rev. 0014 Attachment I (Page7of8)
Monitoring Critical Safety Functions CONTAINMENT FR-Z COLOR PROC CON] AINMENT RED NO GOTO PRE SSURE FR-Z.1 LES STHAN YES 13 5 PSIG
- j GOTO 4 AT LEAST ONE NO FR-Z.1 CONTAINMENT CONTAINMENT SPRAY YELLOV PRESSURE I NO I
PUMP IN SERVICE YES GOTO LESSTHAN I L PHASES YES 1
ORENSE CONTAINMENT GO TO NO LEVEL LESS THAN j:
YES o;;:c 83%
YELLOI1 CONTAINMENT NO GO TO RADIATION (
LESSTHAN 20 R/HR YES Page 10 of 11
I !/i Watts Bar Nuclear Plant Unit I Emergency Operating Instruction FR-Z.2 Containment Flooding Revision 0007 Quality Related Level of Use: Continuous Use Effective Date: 12-20-2010 Responsible Organization: OPS, Operations Prepared By: Nicholas Armour Approved By: Brian Mcllnay Current Revision Description Minor/editorial revision: Converted to Word 2007 (PCR 4892).
L WBN Unit 1 Containment Flooding FR-Z.2 Rev. 0007 1.0 PURPOSE This Instruction provides actions to respond to containment flooding.
2.0 SYMPTOMS AND ENTRY CONDITIONS 2.1 Indications Cntmt Sump level greater than 83% (14.4 ft).
2.2 Transitions FR-O, Status Trees, FR-Z in ORANGE condition.
Page 2 of 4
WBN Containment Flooding FR-Z.2 Unit I Rev. 0007 Step Action/Expected Response Response Not Obtained 3.0 OPERATOR ACTIONS
- 1. IDENTIFY and ISOLATE unexpected source of water:
- a. ERCW.
- b. CCS.
C. High pressure fire protection.
- d. Primary water.
- e. Dl water.
- f. SFP cooling water.
- 2. CHECK cntmt sump activity and chemistry:
- 1) NOTIFY Chemistry to sample from RHR system.
- 2) GO TO Step 3.
- b. NOTIFY Chemistry to sample cntmt sump.
Page 3 of 4
WBN Containment Flooding FR-Z.2 Unit I Rev. 0007 Step Action/Expected Response Response Not Obtained
- 3. NOTIFY TSC to evaluate the following:
- Stopping leakage into cntmt.
- Operational problems with equipment located below water level.
- Water transfer to RWST, PWST, etc.
- 4. RETURN TO Instruction in effect.
End of Section Page 4 of 4
STEP DESCRIPTION TABLE FOR FR-Z.2 Step 1 STEP: Try To Identify Unexpected Source Of Water To Sump PURPOSE:To identify unexpected source of water in sump BASIS:
This step instructs the operator to try to identify the unexpected source of the water in the containment sump. Containment flooding is a concern since critical plant components necessary for plant recovery may be damaged and rendered inoperable. A water level greater than the design basis flood level provides an indication that water volumes other than those represented by the emergency stored water sources (e.g.,
RWST, accumulators, etc.) have been introduced into the containment sump. Typical sources which penetrate containment are service water, component cooling water, primary makeup water and demineralized water.
All possible plant specific sources which penetrate containment should be included in this step. These systems provide large water flow rates to components inside the containment and a major leak or break in one of these lines could introduce large quantities of water into the sump.
Identification and isolation of any broken or leaking water line inside containment is essential to maintaining the water level below the design basis flood level.
ACTIONS:
Try to identify unexpected sources of water to the sump INSTRUMENTATION:
Plant specific instrumentation to identify unexpected sources of water to the surnp CONTROL/EQUIPMENT:
N/A KNOWLEDGE:
N/A PLANT-SPECIFIC INFORMATION:
Sources of water which supply components inside containment FR-Z.2 Background 7 HP-Rev. 2, 4/30/2@B5 HFRZ2BG.doc
STEP DESCRIPTION TABLE FOR FR-Z.2 Step 2 STEP: Check Containment Sump Activity Level PURPOSE:To determine the radioactivity level of the sump fluid BASIS:
The step instructs the operator to determine the activity level in the containment sump water in order to provide information concerning the possible transfer of containment sump water to plant storage tanks outside the containment. The transfer of containment sump water from the containment to other plant storage tanks may be desirable in order to minimize the potential for flooding of critical plant components inside the containment. However, the ultimate disposition of this water outside the containment will depend, in large part, on the level of radioactivity in the water. The method of sampling the containment sump water is plant dependent. Appropriate precautions should be observed due to the potential for high radioactivity.
ACTIONS:
Check containment sump activity level INSTRUMENTATION:
Plant specific sampling instrumentation CONTROL/EQUIPMENT:
Plant specific sampling controls/equipment KNOWLEDGE:
N/A PLANT-SPECIFIC INFORMATION:
Method of obtaining a sump fluid sample FR-Z.2 Background 8 HP-Rev. 2, 4/30/2005 HFRZ2BG .doc
STEP DESCRIPTION TABLE FOR FR-Z.2 Step 3 STEP: Notify Plant Engineering Staff Of Sump Level And Activity Level To Obtain Recommended Action PURPOSE:To notify plant engineering staff of sump level and activity level BASIS:
The step instructs the operator to provide the plant engineering staff with information concerning the containment sump level and information on the radioactive content of the water. The plant specific design and layout will affect the options available to the plant engineering staff regarding the potential transfer of containment sump water outside containment. The design considerations include:
- 1) location of critical plant components in relation to containment sump water level,
- 2) location, size and shielding of outside containment storage
- tanks, and
- 3) pump and line routing from the containment sump to various storage tanks.
The plant engineering staff should evaluate the event and provide specific recommendations to the operators concerning the high containment sump water levels.
ACTIONS:
Notify the plant engineering staff of sump level and activity level to obtain recommended action INSTRUMENTATION:
N/A CONTROL/EQUIPMENT:
N/A FR-Z.2 Background 9 HP-Rev. 2, 4/3e/2ee5 HFRZ2BG .doc
STEP DESCRIPTION TABLE FOR FR-Z.2 (Cont) Step 3 KNOWLEDGE:
N/A PLANT-SPECIFIC INFORMATION:
Plant personnel comprising plant engineering staff FR-Z.2 Background ie HP-Rev. 2, 4/38/2005 HFRZ2BG .doc
Wj3N i3iV)( UJ1/47)
W/E15 EK1.2 027 Given the following plant conditions:
- A large break LOCA has occurred.
- Accumulators have discharged and are isolated.
- ES-i .3, Transfer to Containment Sump has been completed.
- Containment sump level is now at 84% and slowly rising.
- The SM directs performance of FR-Z.2, Containment Flooding.
- FR-Z.2 requires that the containment sump be sampled.
Which ONE of the following describes (1) where the sample is taken from and (2) the reason for sampling the sump?
(1) (2)
A. RHR System To determine the level of activity, to allow the TSC to determine if excess sump water can be transferred to tanks outside of containment.
B. Containment Sump To determine the level of activity, to allow the TSC to determine if excess sump water can be transferred to tanks outside of containment.
C. RHR System To ensure shutdown margin is being maintained, since non-borated water has entered the containment sump.
D. Containment Sump To ensure shutdown margin is being maintained, since non-borated water has entered the containment sump.
3-OT-FRZ0001 Rev 8 Page 4 of 43 pages I. PROGRAM:
Watts Bar Operator Training II. COURSE:
A. License Prep B. Certification C. License Operator Requalification III. TITLE:
Function Restoration Guidelines FR-Z.1, .2, & .3 IV. LENGTH OF LESSON:
A. LicensePrep 2Hour B. Certification 2 Hour Licenser operator REQUAL time will be determined after objectives are identified.
V. TRAINING OBJECTIVES:
0 0 C)
X X X 1. Given a set of plant conditions, use the FR-Z status tree to determine which, if any, Containment Function Restoration Procedure should be implemented.
X X X 2. Discuss the reasons that ECA-1 .1, Loss of RHR Sump Recirculation, is given priority over FR-Z.1, High Containment Pressure for directing Containment Spray Operation.
X X X 3. Analyze a given set of plant conditions and determine if RHR containment spray should be placed in service.
X X X 4. Explain why all RCPs are stopped during the performance of FR-Z.1, High Containment Pressure.
X X 5. Discuss why any Faulted S/G is isolated during the performance of FR-Z.1.
3-OT-FRZ000I Rev 8 Page 5 of 43 pages V. TRAINING OBJECTIVES: (continued) 0 0 D
Cr)
- 6. Deleted X 7. Identify all sources of water to the containment which might cause containment flooding.
X 8. Given a set of plant conditions, use FR-Z.1, FR-Z.2, FR Z.3 and the Critical Safety Function Status Trees to correctly diagnose and implement: Action Steps, RNOs, Foldout Pages, Notes and Cautions.
X 9. Explain the purpose for and basis of each step in FR-Z.1, FR-Z.2, and FR-Z.3.
X 10. List the two major action categories of FR-Z.1, High Containment Pressure X X 1 1. List the two major action categories of FR-Z.2, Containment Flooding.
X 12. List the three major action categories of FR-Z.3, High Containment Radiation.
WBN 10-2011 NRC RO Exam As Submitted 8115/2011
- 28. 003 G2.1.20 028 Given the following:
- Unit I is in Mode 5 preparing for an RCS heatup.
- RCP #2 is in service.
- RCP #4 has experienced the following start and run times as part of a maintenance PMT:
- 1615- started but stopped before it reached rated speed.
- 1655- started and then stopped after a 10 minute run.
- 1740 started and then stopped after a 10 minute run.
- The time is now 1800 and RCP #4 is ready to be placed in service.
Which ONE of the following identifies the earliest time the pump can be started and the breaker handswitch that will be used to start the RCP motor?
Time Handswitch A. 1820 1-HS-68-73AA, RCP 4 NORMAL BKR & LIFT PMP B. 1820 1-HS-68-73BA, RCP 4 ALTERNATE BKR & XFER SELECTOR C. 1850 1-HS-68-73AA, RCP 4 NORMAL BKR & LIFT PMP D 1850 1-HS-68-73BA, RCP 4 ALTERNATE BKR & XFER SELECTOR Page 76
WBN 10-2011 NRC RO Exam As Submitted 8/15/2011 DISTRA CTOR ANAL YSIS:
A. Incorrect, Plausible because 1820 would be the correct time if there had not been 3 starts within the past 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> as the minimum time the pump would have been required to be idle would be 30 minutes and while 1-HS-68-73AA, RCP 4 NORMAL BKR & LIFT PMP, is used with the stated conditions to start the lift pump, it is not used not to start the RCP motor. The normal breaker is the breaker that is closed while the unit is running during normal power operations.
B. Incorrect, Plausible because 1820 would be the correct time if there had not been 3 starts within the past 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> as the minimum time the pump would have been required to be idle would be 30 minutes and because the pump being started from the Alternate Breaker handswitch is correct.
C. Incorrect, Plausible because 1850 is the earliest time the RCP will be restarted because the RCP is to remain idle for at least 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> before a fourth start or attempted start is made and while 1-HS-68-73AA, RCP 4 NORMAL BKR & LIFT PMP, is used with the stated conditions to start the lift pump, it is not used to start the RCP motor. The normal breaker is the breaker that is closed while the unit is running during normal power operations.
D. Correct, As identified in the precaution below, the pump should remain idle for at least 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> (which will be completed at 1850). While both of the handswitches are required to be used to place the RCP in seivice with the stated conditions, when the RCP motor is to be started the alternate breaker handswitch will be used because below 15% power, the station service supply from the unit has not been restored.
SOl-68.02 PRECAUTIONS AND LIMITATIONS E. RCP Maximum Starting Duty limits:
- 1. For Restart after any period running or attempted start where motor failed to achieve full speed before it is stopped: Motor must be idle at least 30 mm before restart.
- 2. Consecutive Starts: In any 2 hr period: Maximum of 3 starts with minimum 30 mm idle period before each restart. When 3 starts (or attempted starts) are made in 2 hrs, then a fourth start should NOT be made until motor is idle at least 1 hr.
Page 77
WBN 10-2011 NRC RO Exam As Submitted 811512011 Question Number: 28 Tier: 2 Group: 1 K/A: 003 G2.1.20 Reactor Coolant Pump System (RCPS)
Conduct of Operations Ability to interpret and execute procedure steps.
Importance Rating: 4.6 I 4.6 10 CFR Part 55: 41.10 /43.5/45.12 IOCFR55A3.b: Not applicable KIA Match: K/A is matched because the question requires the ability to interpret the procedure requirements when starting a RCP to return it to service after it has encountered previous starts.
Technical
Reference:
SOI-68.02, Reactor Coolant Pumps, Revision 0034 Proposed references None to be provided:
Learning Objective: 3-OT-SYSO68B
- 12. Identify the RCPs Normal and Alternate Power Supplies
- 15. Identify the RCP Motor Start Limits.
Cognitive Level:
Higher X Lower Question Source:
New Modified Bank X Bank Question History: WBN bank question SYSO68B.15 004 modified Comments:
Page 78
WBN Reactor Coolant Pumps SOl-68.02 Uniti Rev.0034
. Page7of37 3O PRECAUTIONS AND LIMITATIONS A. Continuous RCP operation is prohibited until RCS is filled and vented per GO-b.
B. Start one RCP at a time allowing approx 5 minutes between starts.
C. RCP Vibration Limits Lc.4j:
- 1. SHAFT (as recorded on 0-Pnl-52-R139, Aux Inst Rm):
Trip: greater than 15 mils AND rate of rise greater than I mil!hr, OR greater than 20 mils
- 2. FRAME (taken by Mech Engineer Tech Group at Vibration Monitor Test Cabinet 1-JB-292-3241) [NW of TBBP el 737 Aux BIdg]:
Normal: less than 3 mils Trip: 5 mils D. In Mode 4 or 5 with loops filled, no RCP shall be started unless secondary water temperature of each SG is 50°F or less above each RCS cold leg.
E. RCP Maximum Starting Duty limits:
- 1. For Restart after any period running or attempted start where motor failed to achieve full speed before it is stopped: Motor must be idle at least 30 mm before restart.
- 2. Consecutive Starts: In any 2 hr period: Maximum of 3 starts with minimum 30 mm idle period before each restart. When 3 starts (or attempted starts) are made in 2 hrs, then a fourth start should NOT be made until motor is idle at least 1 hr.
F. Do not restart RCPs in modes I and 2.
G. When RCS is greater than 150°F, backup power shall be available to continue CCS flow to the Thermal Barriers.
H. If CCS is lost to the motor bearing oil coolers, RCP operation may continue for 10 minutes.
I. CCS to an Idle RCP is to remain in service at least 30 mm, or until RCS is less than 150°F.
J. If all RCPs trip during a dilution operation, one RCS loop could fill with unborated water. Resumption of flow in that loop could flush unborated water to the core and cause a rapid change in shutdown margin. [c.13,5,6]
WBN Reactor Coolant Pumps SOI-6&02 Unit I Rev. 0034 Page 16 of 37 Date________ INITIALS 5.0 STARTUP (continued)
[18] IF starting RCP 1, THEN ENSURE Pzr spray, 1-PCV-68-340D, is CLOSED.
[19] IF starting RCP 2, THEN ENSURE Pzr spray, 1-PCV-68-340B, is CLOSED.
[20] ANNOUNCE RCP start on PA system.
NOTE Below 15% power with station service NOT transferred, the Alternate handswitch is used to start RCP.
[21] START selected RCP (NIA HSs NOT used):
NOMENCLATURE LOCATION POSITION UNID INmAL RCP 1 NORMAL BKR & LIFT PUMP 1-M-5 PUSH IN, THEN 1-HS-68-8AA START RCP 1 ALTERNATE BKR & XFER 1-M-5 PUSH IN, THEN 1-HS-68-8BA SELECTOR START RCP 2 NORMAL BKR & LIFT PUMP 1-M-5 PUSH IN, THEN 1-HS-68-3IAA START RCP 2 ALTERNATE BKR & XFER 1-M-5 PUSH IN, THEN 1-HS-68-31BA SELECTOR START RCP 3 NORMAL BKR & LIFT PUMP 1-M-5 PUSH IN, THEN 1-HS-68-5OAA START RCP 3 ALTERNATE BKR & XFER 1-M-5 PUSH IN, THEN 1-HS-68-5OBA SELECTOR START RCP 4 NORMAL BKR & LIFT PUMP 1-M-5 PUSH IN, THEN 1-HS-68-73AA START RCP 4 ALTERNATE BKR & XFER 1-M-5 PUSH IN, 1-HS-68-73BA SELECTOR THEN START
iv)(
SYSO68B.15004 During an RCS sweep in Mode 5, the #2 RCP had the following start and run times:
- 1300- started and ran 5 minutes.
- 1335- started and ran 10 minutes.
- 1415- started and ran 10 minutes.
Which of the following is the time at which the pump can be started again per procedure.
- a. 1445
- b. 1455
- c. 1515 dY 1525
3-OT-SYSO68 B Revision 15 Page 5of50 I. PROGRAM Watts Bar Operator Training II. COURSES A. License Training B. Non-License Training III. TITLE Reactor Coolant Pumps IV. LENGTH OF LESSON A. License Training 2 Hours B. Non-License Training 4 Hours V. TRAINING OBJECTIVES 0 0 D I Cl) U)
X X X 01. State the Reactor Coolant Pump (RCP) Design basis per FSAR 5.5.1.
X X X 02. Locate MCR Controls and Indications for the RCPs, including:
- a. Normal & Alternate control handswitches.
- b. Cooling water and thermal barrier supplies.
B c. Bearing temp; Seal water supply, leakoff, water temp, and tIP.
X X 03. Given the RCS condition/status and number of RCPs/RHR pumps in service, use Tech Specs to determine if operability requirements are met and if actions are required.
X X X 04. Describe the Purpose and Flowpath of the RCP Thermal Barrier.
X X X X 05. Describe the RCPs Seal Injection System, including:
- a. Flowpath/Components
- b. Flowrate
X X X X 07. Give the Purpose of the #1 Seal Bypass Valve, and list conditions that must be met before the valve is opened X X X X 08. Identify the Conditions requiring closure of the #1 Seal Leak-off Valve, and the Effects of closing the leak-off valve
3-OT-SYS068 B Revision 15 Page6of5o 0 0<
DO O: I
< U) U)
X X X 09. Describe the Purpose and Interlocks of the RCP Oil Lift System X X X X 10. Explain the Purpose of the RCP Flywheel X X X X 1 1. Describe how Reverse Rotation of an idle RCP is prevented X X X X 12. Identify the RCPs Normal and Alternate Power Supplies X X X 13. List and Explain the limitation for RCP operation without Component Cooling Water (CCS) aligned X X X 14. Describe the Conditions which must be met to continue RCP operation Without Seal Injection Flow X X X 15. Identify the RCP Motor Start Limits.
X X X X 16. Correctly Locate the following:
- b. RCP Seal and Seal Piping arrangement.
- c. Oil Lift Pump.
V d. Motor Cooling Water Supply and Return Valves.
- e. Thermal Barrier Booster Pumps (TBBPs) and Piping.
- f. RCP Oil level Sight Glasses.
- g. RCP Motor Heater.
- h. RCP Motor Cooler.
WBN 10-2011 NRC RO Exam As Submitted 811512011
- 29. 003 K6.02 029 Given the following:
- Unit I is in Mode 3 with the RCS at normal operating temperature and pressure.
- Annunciator 100-D, RCP SEAL LEAK OFF FLOW HI, alarms.
- The #4 RCP seal leak off temperature has begun to slowly rise.
Which ONE of the following identifies...
(1) the operation of the #4 RCP #2 seal and (2) if RCP Immediate Trip Criteria is currently met?
A (1) The # 2 seal will transition to a film riding mode of operation as the #1 seal fails.
(2) Is met.
B. (1) The # 2 seal will transition to a rubbing face mode of operation as the #1 seal fails.
(2) Is met.
C. (I) The # 2 seal will transition to a film riding mode of operation as the #1 seal fails.
(2) Is NOT met.
D. (1) The # 2 seal will transition to a rubbing face mode of operation as the #1 seal fails.
(2) Is NOT met.
Page 79
WBN 10-2011 NRC RO Exam As Submitted 8/15/2011 DISTRACTOR ANAL YSIS:
A. Correc1, The #2 seal does transition to a film riding mode of operation following the failure of the #1 seal and with The seal flow high and the seal leak off temperature starting to rise, the RCP Immediate Trip criteria is met.
B. Incorrect, Plausible because the #2 seal does transition but the stated transition is the opposite of what actually occurs and the RCP Immediate Trip criteria currently being met is correct.
C. Incorrect, Plausible because the #2 seal transitioning to a film riding seal is correct and because if the seal leak off temperature had not been rising the Immediate Trip criteria would not currently be met.
D. Incorrect, Plausible because the #2 seal does transition but the stated transition is the opposite of what actually occurs and because if the seal leak off temperature had not been rising the Immediate Trip criteria would not currently be met.
Question Number: 29 Tier: 2 Group: 1 KIA: 003 K6.02 Reactor Coolant Pump System (RCPS)
Knowledge of the effect of a loss or malfunction on the following will have on the RCPS:
RCP seals and seal water supply Importance Rating: 2.7 I 3.1 IOCFRPart55: 41.7/45/5 IOCFR55.43.b: Not applicable K/A Match: K/A is matched because the question requires knowledge of the effect an RCP #1 seal failure has on the #2 seal on the pump and also the evaluation of pump seal conditions to determine if a pump shutdown is required.
Technical
Reference:
ARI-95-101, Reactor Coolant Pumps, Revision 0033 AOl-24, RCP Malfunctions During Pump Operation, Revision 0029 N3-68-4001, Reactor Coolant System, Revision 0030 Proposed references None Page 80
WBN 10-2011 NRC RO Exam As Submitted 8/1512011 to be provided:
Learning Objective: 3-OT-A012400
- 10. Given a set of plant conditions, use AOl-24 to correctly:
- a. Recognize Entry Conditions.
- b. Identify Required Actions.
- c. Respond to Contingencies (RNO).
- d. Observe and Interpret Cautions and Notes.
- 11. Given a set of conditions, determine if RCP shutdown is required using AOl-24, Attachment 2.
Cognitive Level:
Higher X Lower Question Source:
New Modified Bank Bank X Question History: WBN bank question SYSO68B.05 013 with choices relocated and conditions/wording changed in the stem and all choices.
Comments:
Page 81
WBN Reactor Coolant Pumps ARI-95-101 Unit I Rev. 0033 Page 39 of 50 I00-D Source Setpoint RCP 1: 1-FS-62-11 4.8 gpm RCP 2: 1-FS-62-24 FLOW RCP 3: 1-FS-62-37 HI RCP 4: 1-FS-62-50 A
(Page 1 of 1)
Probable A. No. 1 seal damage Cause: B. No. 1 seal NOT fully seated C. Loss of seal injection water followed by high seal temperature Corrective [1] VERIFY high leakoff flow condition of affected RCP(s) with the following Action: instruments:
RCP RECORDER PEN1TRACE ICS POINT I 1-FR-62-24 Red F1018A 2 1-FR-62-24 Blue F1020A 3 1-FR-62-50 Red F1022A 4 1-FR-62-50 Blue F1024A
[2] IF high leakoff is confirmed, THEN GO TO AOl-24, RCP MALFUNCTIONS DURING PUMP OPERATION.
References:
I -47W6 10-62-1 AOl-24
2O0 300 10
,1 1116242 1TI6243 1Fl--6240A 1PDI6247A
WBN RCP MALFUNCTIONS DURING PUMP AOI-24
- Unit I OPERATION Rev. 0029 Attachment 2 (Page 1 ofl)
RCP IMMEDIATE SHUTDOWN CRITERIA NOTE Exceeding any of the following setpoints will require an immediate pump shutdown. Operating limits can be found in SOl 68.02. This list is immediate shutdown criteria only.
A. Shaft vibration greater than 20 mils or 15 mils with a rate of rise equal to 1 mil/hr (alarm at 15 mils). [Indicators located on O-PNL-52-R139, Aux Inst Rm.]
B. Frame vibration greater than 5 mils or 3 mils with a rate of rise of 0.2 mil/hr.
[Readings taken by Maint. at Aux Bldg L-Panels, el.737.]
C. Motor windings temp greater than 302°F.
D. Motor bearing temp greater than 195°F.
E. Pump bearing temp greater than 225°F.
F. Loss of CCS to oil coolers for greater than 10 minutes.
G. No. I seal outlet temp greater than 225°F.
H. No. 1 seal flow HIGH with rising pump bearing or #1 seal leakoff temperatures.
I. No. 1 seal \P less than or equal to 200 psid.
Page 26 of 27
- NPG System REACTOR COOLANT SYSTEM N3-68-4001 Description Rev. 0030 Document Page 64 of 225 3.2.3 Reactor Coolant Pumps (continued)
- 6. Radial Bearing Assembly The radial bearing consists of a two-piece horizontally split housing, a bearing cartridge, and a journal. It is lubricated and cooled by injection water. The spherical inside diameter of the housing mates with a surface on the bearing cartridge that is overlaid with a cobalt-based alloy. Carbon-graphite rings are shrunk in the bearing cartridge and form the bearing surface. The bearing operates against a journal shrunk on the shaft. This journal is made of stainless steel overlaid with a cobalt-based alloy.
B. Seal System The pump seal system consists of three different controlled-leakage seals within a seal housing, and features the assembly of the Number 2 and Number 3 seals in a single cartridge so that they may be installed or removed together.
- 1. Number 1 Seal The Number 1 seal is the main controlled-leakage seal of the pump. It is a hydrostatically balanced, film-riding face seal, consisting of a seal runner which rotates with the shaft and a nonrotating seal ring enclosed by the seal housings. Both the runner and ring have an aluminum-oxide or silicon-nitride faceplate clamped to a stainless steel holder.
Seal Injection water flows through the separation between the two faceplates, the amount of separation being controlled by the face contours and system pressure.
Separation will be maintained and no surface contact will occur as long as minimum operating pressures are maintained. Part of the leakage up through the Number 1 seal (normally injection water) supplies the Number 2 seal, while the excess flow is piped to the VCT through the Number 1 seal leak-off pipe.
- 2. Number 2 Seal The Number 2 seal is a rubbing-face seal, consisting of a carbon-graphite insert assembled with a shrink fit into a retaining ring. This assembly is attached to a seal ring base with spring-loaded pins. Both the retaining ring and the seal ring are made from stainless steel forgings. The assembly is pinned to prevent rotation but allows motion in the axial direction. The insert rubs on a chrome-carbide-coated stainless steel forged runner, which rotates with the shaft.
The leakage through the Number 2 seal is piped to RCDT through the Number 2 seal leak-off pipe.
When subjected to high pressure (which would occur should the Number 1 seal fail), the Number 2 seal is designed to convert from a rubbing-face to a film-riding seal. This conversion happens because the runner deflects as operating pressure increases.
SYSO68B.05013 wG/1 Given the following plant conditions;
- The Unit is at 42% power, and increasing.
- The #1 RCP seal leak off flow indication is rising.
- The #1 RCP lower radial bearing temperature has begun to slowly rise.
Which of the following describes the RCP seals, and the condition of the RCP?
- a. The # 2 seal will transition to a film riding mode of operation as the #1 seal fails, and the RCP may continue to run indefinitely.
- b. The # 2 seal will transition to a rubbing face mode of operation as the #1 seal fails, and the RCP may continue to run indefinitely.
- c. The # 2 seal will transition to a rubbing face mode of operation as the #1 seal fails, and the RCP must be removed from service.
- d. The # 2 seal will transition to a film riding mode of operation as the #1 seal fails, and the RCP must be removed from service.
3-OT-A012400 Rev 8 Page 4 OF 114 I. PROGRAM Watts Bar Operator Training II. COURSE A. License Training B. Non-license Training III. TITLE AOI-24, RCP Seal Malfunctions during Pump Operation IV. LENGTH OF LESSON License Training 1 Hour Non-License Training 1 Hour V. TRAINING OBJECTIVES AR S S U OR T 0 0 A X X X X 01. Demonstrate knowledge of the Purpose/Goal of AOI-24.
X X X X 02. Indicate how much leakage could result from total seal failure at full RCS pressure, describe action to mitigate the consequences of this leakage.
) X X 03. Identify Alarms associated with RCP seal malfunctions.
J X X 04.
05 List 4 Indications of RCP seal malfunctions per AOI-24.
Deleted Objective X X X 06 Assuming injection water to an RCP is lost and pump lower bearing temperature is above alarm setpoint, state what precautionary measure must be observed when restoring seal injection.
X X X X 07. Given an RCP seal Standpipe Hi level alarm, describe how to calculate #2 seal leak-off rate from the Radwaste Panel.
X X X 08. Explain why RCP Seal Stand pipe Level Hi/Lo alarm comes in on #3 Seal leak-off Hi flow.
3-OT-AO 12400 Rev 8 Page 5 OF 114 V. TRAINING OBJECTIVES (continued)
AR S S U OR T 0 0 A X X X 09. Identify the parameters listed in AOI-24 that require the RCP to be shutdown x x 10. Given a set of plant conditions, use AOI-24 to correctly:
x
- a. Recognize Entry Conditions.
- b. Identify Required Actions.
- c. Respond to Contingencies (RNO).
- d. Observe and Interpret Cautions and Notes.
X X 1 1. Given a set of conditions, determine if RCP shutdown is required using AOI-24, Attachment 2.
X X 12. Describe basic Operator Actions to shut down an RCP.
VI. TRAINING AIDS A. Marker Board & Markers B. Multimedia/Overhead projector(s)
VII. MATERIALS Attachment(s):
Attachment 1 RCP Seal Flows Attachment 2 AOI-24, RCP Seal Malfunctions during Pump Operation (Latest Rev)
Attachment 3 SOER 82-5, Reactor Coolant Pump Seal Failure VIII. REFERENCES ENGINEERING SYSTEM DESCRIPTION(S)
Number Title Rev.
N3-62-4001 Chemical and Volume Control System 29 N3-68-4001 Reactor Coolant System 28 A4 ;1I Section Title Amend.
9.3.4 Chemical and Volume Control System NA Chapters3, 5, 6, 7, Reactor Coolant System NA 9, 15 I] I[c Plant Drawings Title Rev.
None
3-OT-A0l2400 Rev 8 Page 19 OF 114 Three general classes of conditions are addressed by AOl-24:
Conditions requiring immediate pump shutdown or pump trip.
This condition, which includes high #1 seal leakoff flow that results in rising RCP lower bearing or #1 seal outlet temperature, requires an immediate reactor trip if in Mode I or 2.
In formation to Instructor
3-OT-AO 12400 Rev 8 Page 53 OF 114 AOI-24. Section 3.3, #1 Seal Leakoff Flow High
- 1) MONITOR #1 seal leakoff equal to or greater than 6.0 gpm. (Annunciator alarms at 4.8 gpm) 2)MONITOR RCPs lower bearing and #1 seal outlet temp STABLE or DROPPING Information to Instructor NOTE: The numbering of steps corresponds to the numbering of AOl steps. A copy of AOl-24 should be used for detailed substeps and RNO actions.
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.
1 Additional Info: Seal leak-off high range indicator scale is 0-6 gpm. Since 6 gpm is the maximum indicated leak-off flow, the only way to determine the impact of flow> 6 gpm is to monitor the effect on RCP lower bearing and #1 seal outlet temperature, and the effect on #2 seal leak-off flow.
Contact should be made with Engineering to install temporary flow indication if leakage exceeds 6 gpm.
Westinghouse technical bulletin states, If the total #1 seal flow exceeds 8.0 gpm or temperatures begin to rise, proceed with immediate shutdown Since we cant read 8 gpm, we rely on temperature.
2 Additional Info: In the condition where the lower bearing or #1 seal outlet temperatures are rising, leak-off flow is greater than seal injection flow (nominally 8 gpm). Rising temperatures indicate RCS flow up through the thermal barrier at a rate greater than the cooling capacity of the thermal barrier (3 gpm). (Implying leak-off is 11 gpm or. higher).
If either of these conditions exist, then the reactor is tripped, the RCP stopped, and the #1 seal return valve is closed. This action should stop the leakage by forming the #2 seal to its film-riding mode, thus reversing the heatup of the seal package and pump bearing due to high flow and resultant high temperatures. The pump is stopped prior to isolating the seal leak-off in order to avoid the possibility of forcing debris from the failed seal or the RCS up through the #2 seal while the pump is rotating.
3-OT-SYS068B Revision 14 OBJECTIVE 8 11. Discuss the impact of a #1 seal failure on RCP operation.
In Tke tkormol karrier is designed to 0001 FtCS liquid when
- The thermal barrier is designed to cool RCS liquid 31 seal look-off flow is in the nonoal range (opprox. 3 gpor). when #1 seal leak-off flow is in the normal range to At higher leak-off flows the pomp lower keoring and seals are sokjnoted to high temp until fit leak-off is (approx. 3 gpm).
isolated.
to When the look-off is isolated tho #2 seol will beoome the primary seal aod be eoposed to foil RCS prossoro.
- At higher leak-off flows the pump lower bearing to Feilore of a #1 seal wlrioh results in fit seal leakoff flow o f.O gpto roqairns removal of affeoted RCP AND and seals are subjected to high temp until #1 leak-slosieg offeoted poerp soul return FCV within 3 to off is isolated.
C) to Removal of tho RCP from senaiso praoents #2 seal w
foilore doe to debris from failed/doterioratiog ft seol.
I When leak-off is isolated the #2 seal will become the primary seal and be exposed to full RCS
-J pressure.
C)
I Failure of a #1 seal which results in #1 seal leakoff flow> 6.0 gpm requires removal of affected RCP AND closing affected pump seal return FCV within 3 to 5 minutes.
- Removal of the RCP from service prevents #2 seal failure due to debris from failed/deteriorating #1 seal
- Hyperlink to the Human Performance Tools and Traps home page and select Procedure Use and Adherence. Emphasize the importance of use of AOls to address these conditions.
to Prossorn kalonooct ond spring-loaded robhisg fase seal.
RCP #2 Seal to Concerts too film-riding seal opon loss of the No.
0 to Approo. 3 GPH leakoff drdos tea staedpipr- oOiolt
- 1. Discuss the function, operation and design w drabs to tlte RCDT Pomps. characteristics of the RCP #2 Seal.
-J I Pressure balanced and spring-loaded rubbing face U) seal.
- Converts to a film-riding seal upon loss of the No.
1 seal.
- Approx. 3 GPH leakoff drains to a standpipe which drains to the RCDT Pumps.
- 2. Discuss the function and operation of the RCP No. 2 to Moiotaies kaskpresnore on No.2 neal and a nonstant - .1 0
00 0-0 Seal Standpipe.
head to the No. 3 seal.
to Orifloe over tIre top of the oov-. 0 0 I Maintains backpressure on No. 2 seal and a Iii tdl0I lthk I I constant head to the No. 3 seal.
to High mtd low leoel alarinnie I Orifice near the top of the standpipe limits the rate
-J of drainage from the standpipe to the design Cl) leakage rate for the No. 2 seal.
- High and low level alarms in the MCR.Window XA 55-SB, Window 95-C.
RCP X STANDPIPE LEVEL HI/LO.
HI 12 in. above outlet.
LO 12 in. below outlet.
3-OT-SYSO68B Revision 15 Page 5of50 I. PROGRAM Watts Bar Operator Training II. COURSES A. License Training B. Non-License Training III. TITLE Reactor Coolant Pumps IV. LENGTH OF LESSON A. License Training 2 Hours B. Non-License Training 4 Hours V. TRAINING OBJECTIVES 0 0 D
(I) (I)
X X X 01. State the Reactor Coolant Pump (RCP) Design basis per FSAR 5.5.1.
X X X 02. Locate MCR Controls and Indications for the RCPs, including:
- a. Normal & Alternate control handswitches.
- b. Cooling water and thermal barrier supplies.
- c. Bearing temp; Seal water supply, leakoff, water temp, and AP.
X X 03. Given the RCS condition/status and number of RCPs/RHR pumps in service, use Tech Specs to determine if operability requirements are met and if actions are required.
X X X 04. Describe the Purpose and Flowpath of the RCP Thermal Barrier.
X X X X 05. Describe the RCPs Seal Injection System, including:
- a. Flowpath/Components
- b. Flowrate
X X X X 07. Give the Purpose of the #1 Seal Bypass Valve, and list conditions that must be met before the valve is opened X X X X 08. Identify the Conditions requiring closure of the #1 Seal Leak-off Valve, and the Effects of closing the leak-off valve
3-OT-SYSO68B Revision 15 Page6of50 0 0 D I Cl) Cl)
X X X 09. Describe the Purpose and Interlocks of the RCP Oil Lift System X X X X 10. Explain the Purpose of the RCP Flywheel X X X X 1 1. Describe how Reverse Rotation of an idle RCP is prevented X X - X X 12. Identify the RCPs Normal and Alternate Power Supplies X X 13. List and Explain the limitation for RCP operation without Component Cooling Water (CCS) aligned X X 14. Describe the Conditions which must be met to continue RCP operation Without Seal Injection Flow X X 15. Identify the RCP Motor Start Limits.
X X X X 16. Correctly Locate the following:
- b. RCP Seal and Seal Piping arrangement.
- c. Oil Lift Pump.
- d. Motor Cooling Water Supply and Return Valves.
- e. Thermal Barrier Booster Pumps (TBBP5) and Piping.
- f. RCP Oil level Sight Glasses.
- g. RCP Motor Heater.
- h. RCP Motor Cooler.
WBN 10-2011 NRC RO Exam As Submitted 8115/2011
- 30. 004 A2.06 030 Given the following:
- Unit I is operating at 100% power after restart following a refueling outage.
- Rod Control in MANUAL.
- VCT level is currently at 32%.
- An AUO places an un-borated mixed bed demineralizer in service.
Which ONE of the following identifies...
(I) expected change in VCT level if no operator action is taken and the condition is allowed to persist and (2) the corrective action the RO will take that will stop the event in progress?
A. (1) Remain constant.
(2) Place 1-HS-62-79A, LTDN HI TEMP DIVERT, to V.C. TK.
B. (1) Remain constant.
(2) Initiate normal boration per AOI-34, Immediate Boration.
C (1) Rise over time.
(2) Place 1-HS-62-79A, LTDN HI TEMP DIVERT, to V.C. TK.
D. (1) Rise overtime.
(2) Initiate normal boration per AOI-34, Immediate Boration.
Page 82
WBN 10-2011 NRC RO Exam As Submitted 8/15/2011 DISTRA CTOR ANAL YSIS:
A. Incorrect, Plausible because, unlike an inadvertent dilution due to makeup, no inventory is directly added to the VCT due to the unborated mixed bed and placing 1-HS-62-79A to the VCT position will divert letdown around the demin that is the source of the problem.
B. lncorreci, Plausible because, unlike an inadvertent dilution due to makeup, no inventory is directly added to the VCT due to the unborated mixed bed and A 01-3, Malfunction of Reactor Makeup Contro4 does refer operators to A 01-34 to borate the RCS, however it will not stop the event in progress.
C. CorrecI, the dilution event in progress does not add any inventory but it will increase Tavg which will cause pressurizer level to increase above setpoint, which will lower charging and place more coolant into the VCT. Also, placing 1-HS-62-79A to the VCT position will divert letdown around the demin that is the source of the problem.
D. lncorrect Plausible because the dilution event in progress does not add any inventory but it will increase Tavg which will cause pressurizer level to increase above setpoint, which will lower charging and place more coolant into the VCT.
Also plausible because A 01-3, Malfunction of Reactor Makeup Control, does refer operators to A 01-34 to borate the RCS, however it will not stop the event in progress.
Question Number: 30 Tier: 2 Group: 1 KIA: 004 A2.06 Chemical and Volume Control System Ability to (a) predict the impacts of the following malfunctions or operations on the CVCS; and (b) based on those predictions, use procedures to correct, control, or mitigate the consequences of those malfunctions or operations:
Inadvertent boration/dilution.
Importance Rating: 4.2 / 4.3 10 CFR Part 55: 41.5/43.5/45.3 / 45.5 IOCFR55.43.b: Not applicable K/A Match: K/A is matched because the question requires knowledge of the operation of CVCS, i.e. how charging will respond as Tavg and pressurizer level change and that effect on VCT level and knowledge of how to stop an unborated mixed bed from diluting the RCS through Page 83
WBN 10-2011 NRC RO Exam As Submitted 8/1512011 KIA Match: K/A is matched because the question requires knowledge of the operation of CVCS, i.e. how charging will respond as Tavg and pressurizer level change and that effect on VCT level and knowledge of how to stop an unborated mixed bed from diluting the RCS through the CVCS.
Technical
Reference:
AOl-3, Malfunction of Reactor Makeup Control, Rev.
0029 Proposed references None to be provided:
Learning Objective: 3-OT-A010300
- 04. List 3 ways Inadvertent Dilution could occur.
- 06. Explain the effect placing an unborated Mixed Bed Demin in service can have on RCS Boron Concentration.
Cognitive Level:
Higher X Lower Question Source:
New X Modified Bank Bank Question History: New question for the WBN 10/2011 NRC exam.
Comments:
Page 84
WBN Malfunction of Reactor Makeup Control AOI-3 Unit I Rev. 0029 Step Action/Expected Response Response Not Obtained 3.2 Inadvertent Dilution (continued)
CAUTION Charging flow path should be isolated when Letdown is taken out of service.
- 3. PLACE 1-HS-62-79A, Ltdn Hi Temp CLOSE 1-FCV-62-69 and DiverttoVCTK. 1-FCV-62-70, LETDOWN FLOW ISOLATION.
IF leakage from Mixed Bed is suspected, THEN:
CLOSE 1-ISV-62-901 and 1-ISV-62-902 to isolate A Mixed Bed
[A3T/71 3].
OR CLOSE 1-ISV-62-908 and 1-ISV-62-909 to isolate B Mixed Bed
[A3T/71 3].
NOTE A letdown temperature drop can reduce RCS boron concentration by changing the demin bed boron equilibrium.
- 4. CHECK letdown temp stable: STABILIZE letdown and CCS temp.
- 1-Tl-70-191, LTDN HX RET TEMP.
- 1-TI-62-78, Letdown HX Outlet Tern p.
- 1-Tl-62-131, VCT Outlet Temp.
Page 7 of 19
3-OT-AO 10300 Rev 13 Page 4 of 68 I. PROGRAM Watts Bar Operator Training II. COURSE A. License Training B. Licensed Requalifcation C. NAUO Requalifcation III. TITLE AOI-3, Malfunction of Reactor Makeup Control IV. LENGTH OF LESSON License Training 1.0 Hour License Requalification and NAUO Requalification times will be determined after objectives are identified.
V. TRAINING OBJECTIVES Describe the Purpose/Goal of AOI-3.
Describe the main concern(s) for Inadvertent Dilution at power.
List 3 Symptoms of Inadvertent Dilution during Shutdown.
List 3 ways Inadvertent Dilution could occur.
Explain required Local Action if Primary Water flow to blender can not be terminated from MCR.
Explain the effect placing an unborated Mixed Bed Demin in service can have on RCS CB With Refueling in progress, determine correct response of personnel in Cntmt to a PA announcement for Cntmt evacuation.
WBN 10-2011 NRC RO Exam As Submitted 811512011
- 31. 004A2.21 031 Given the following:
- Unit 1 is operating at 100% power.
- Letdown flow is 120 gpm.
- Chemistry request the cation bed be placed in service at a 50 gpm flow rate.
Which ONE of the following identifies...
(I) the affect on the Cation Bed if full letdown flow was aligned through the bed and (2) the valve that will be used to set the requested flow rate at 50 gpm through the cation bed in accordance with SOl-62.04, CVCS Purification System?
A. (1) Design flow would NOT be exceeded.
(2) 1-ISV-62-916, CVCS CATION DEMIN BED OUTLET B. (1) Design flow would be exceeded.
(2) 1-ISV-62-916, CVCS CATION DEMIN BED OUTLET C. (1) Design flow would NOT be exceeded.
(2) 1-ISV-62-922, CVCS MIXED BED DEMIN OUTLET D (1) Design flow would be exceeded.
(2) 1-ISV-62-922, CVCS MIXED BED DEMIN OUTLET Page 85
WBN 10-2011 NRC RO Exam As Submitted 811512011 DISTRACTOR ANAL YSIS:
A. Incorrect, Plausible because the design flow rate of each of the CVCS Mix Beds is 120 gpm and if this rating had been applied to the Cation Bed the flow rate of the full letdown flow would not have been exceeded. Second part also plausible because throttling the outlet valve on a component is a typical way of establishing a flow rate through a component and the flow rate would be changed through the cation bed if 1-IS V-62-916, CVCS CATION DEMIN OUTLET were throttled.
B. Incorrect, Plausible because design flow of the cation bed being exceeded is correct and because throttling the outlet valve on a component is a typical way of establishing a flow rate through a component and the flow rate would be changed through the cation bed if 1-IS V-62-916, CVCS CATION DEMIN OUTLET were throttled.
C. Incorrect, Plausible because the design flow rate of each of the CVCS Mix Beds is 120 gpm and if this rating had been applied to the Cation Bed the flow rate of the full letdown flow would not have been exceeded. Also plausible because throttling 1-IS V-62-916, CVCS MIXED BED DEMIN OUTLE7 is correct.
D. Correct, The design flow rate of the cation bed is 75 gpm. The full 120 gpm letdown flow through the cation bed would exceed the design flow of the bed. In accordance with SOI-62. 04, 1-IS V-62-922, CVCS MIXED BED DEMIN OUTLET, is used after the cation bed inlet and outlet valves are opened to establish the required flow rate. The valve is parallel to the cation bed in the system flow path. Throttling this valve in the close direction forces flow through the cation bed.
Page 86
WBN 10-2011 NRC RO Exam As Submitted 8/1512011 Question Number: 31 Tier: 2 Group: 1 KIA: 004 A2.21 Chemical and Volume Control System Ability to (a) predict the impacts of the following malfunctions or operations on the CVCS; and (b) based on those predictions, use procedures to correct, control, or mitigate the consequences of those malfunctions or operations:
Excessive letdown flow, pressure, and temperatures on ion exchange resins (also causes).
Importance Rating: 2.7 / 2.7 10 CFR Part 55: 41.5/43.5/45.3 / 45.5 IOCFR55.43.b: Not applicable K/A Match: K/A is matched because the question requires knowledge of the impact of placing an established letdown flow through a CVCS ion exchanger (cation bed) and how flow will be throttled to protect the demin bed from failure.
Technical
Reference:
SOI-62.04, CVCS Purification System, Rev. 0057 Proposed references None to be provided:
Learning Objective: 3-OT-SY5062
- 20. Discuss the function of the CVCS mixed bed and cation bed demineralizers.
Cognitive Level:
Higher Lower X Question Source:
New X Modified Bank Bank Question History: New question for the WBN 10-2011 NRC exam Comments:
Page 87
WBN CVCS Purification System SOI-62.04 Unit I Rev. 0057 Page6OofIO3 Date
&2 Place Cation Bed in Service
[1] ENSURE CB FILLED and VENTED per Section 8.1.
[2] PERFORM the following:
NOMENCLATURE LOCATION POSITION UNID PERF VERIFIER INITIAL INITIAL CVCS CATION DEMIN BED A3T1713 CLOSED 1-ISV-62-915 INLET CV CVCS CATION DEMIN BED A3T/713 CLOSED 1-ISV-62-916 OUTLET CV CVCS CATION DEMIN BED A3T/713 CLOSED 1-VTV-62-917 VENT CV CVCS CATION DEMIN BED A5U1737 CLOSED 1-ISV-62-918 RESIN FILL CV CVCS CATION DEMIN BED A7U/713 CLOSED 1-ISV-62-919 RESIN DISCH CV CVCS CATION DEMIN BED A3T1713 CLOSED 1-DRV-62-920 DRAIN CV CVCS CATION BED FLUSH A3T1713 CLOSED 1-FLV-62-921 CV
[3] ENSURE 1-ISV-62-922, CVCS MIXED BED DEMIN OUTLET
[A3T/713], is OPEN.
[4] REVIEW Attachment 1, Resin Status Sheet to ensure CB is FILLED and BORATED.
CV
[5] NOTIFY SRO of intent to place CB in service, and its current boron concentration as recorded on Attachment 1, Resin Status Sheet.
CAUTION Cation Bed may need to be flushed to minimize reactivity effects if cation bed boron concentration varies more than 20 ppm from that of the RCS boron concentration or if a new cation bed is being placed in service.
[6] OPEN 1-ISV-62-915, CVCS CATION DEMIN BED INLET.
CV
WBN CVCS Purification System SOI-62.04 Unit I Rev. 0057 Page 61 of 103 Date 8.2 Place Cation Bed in Service (continued)
[7] IF flush is desired for cation bed, THEN GO TO Section 8.7, Flushing Cation Bed to Adjust Boron Prior to Use.
CAUTION Maximum Cation Bed flow is 75 gpm. May be read locally at 1-FI-62-113 (Panel 1-L-57 at A3T/71 3).
[8] (p) SLOWLY OPEN 1-ISV-62-916, CVCS CATION DEMIN BED OUTLET.
CV
[9] SLOWLY THROTTLE CLOSE 1-ISV-62-922, CVCS MIXED BED DEMIN OUTLET, until desired cation bed flow rate achieved.
CV
[10] RECORD Time, Date, and Flowrate when CB was placed in service on Attachment 1, Resin Status Sheet.
[11] NOTIFY Chemistry of Time, Date, and Flowrate when CB was placed in service.
End of Section
WBN CVCS Purification System SOI-62.04 Unit I Rev. 0057 Page 6 of 103 3.0 PRECAUTIONS AND LIMITATIONS A. Resin damage may occur if demin inlet temp exceeds 140°F.
B. Mixed Bed Demins must be borated before placing in service, or borated slowly while placing in service to avoid rapid reduction of Reactor Coolant System (RCS) boron concentration (CB).
2 Where use of new resin is a part of a planned RCS boron concentration control evolution, work shall be controlled to ensure that adequate reactivity control systems are maintained operable at all times.
C. When resin addition is in progress, transfer line plugging can occur if a sufficient flow of water is not maintained.
D. Spent resin sluice line can be a source of considerable radiation exposure during resin transfer due to pipe routing and lack of shielding around pipe.[c.1]
E. When Reactor Coolant Filter is bypassed, flow though the demins should be Secured or Diverted to HUT to prevent potential Resin intrusion into RCS.
F. Demineralizer flow limits: j /
- 1. MB Demins normal design flow is 20 to 120 gpm.
- 2. Cation Demin design flow is 75 gpm. jç-
G. When performing operations on demins, care should be exercised to maintain a letdown flow path at all times.
H. Work in Radiological Control Area (RCA) requires the use of existing RWPs and may require additional ALARA Preplans. Failure to follow posted Rad control requirements can cause unnecessary radiation exposure. Radiological Protection should be notified of work with potential to change radiological conditions.
I. Instrument Maintenance department should be notified to ensure required instruments will be in service, as necessary, to support system operation.
J. Demineralizers containing macroporous resin have the potential for particulate loading and subsequent release when flow is reestablished.
K. Steps that directly affect reactivity will be preceded with the Greek symbol (p).
L. Steps within this instruction may require venting, draining, or breaching radioactive components or systems to the atmosphere. Appropriate protection controls must be established to prevent the spread of contamination and avoid the generation of airborne radioactivity.
3-OT-SYSO62A Revision 14 Page6of83 I.PROGRAM Watts Bar Operator Training II. COURSES A. License Training B.. Non-License Training III. TITLE Chemical and Volume Control System IV. LENGTH OF LESSON A. License Training 6 Hours B. Non-License 6 Hours V. TRAINING OBJECTIVES A RS S U ORT 0 CA X X X X 1. Explain the major functions of the CVCS system as described in FSAR section 9.3.4 X X X X 2. Explain the functions of the following subsystems of CVCS:
- Charging, letdown and seal injection water.
- Chemical control, purification, and makeup.
- Chemical shim (boron concentration) and reactor coolant makeup.
X X X X 3. Explain the purpose and capacity of the excess letdown system.
X X X X 4. Using a block diagram of CVCS, explain system flow balance.
X X X X 5. Describe all interlocks (opening and closing) for:
B Letdown isolation valves (FCV 62-69, 70, 77)
- Letdown orifice isolation valves (FCV 62-72, 73, 74, 76)
3-OT-SYS062A Revision 14 Page 7of83 A RS S U ORT 0 CA X X X X 6. Describe the function/purpose of the following CVCS equipment:
- Regenerative Hx.
- Letdown Hx.
- Letdown Orifices
- Rx Coolant Filter
- Holdup Tanks U Volume Control Tank U Centrifugal Charging Pump
- Seal Water Injection Filters U RCP Seal Standpipe
- Number 1 Seal Bypass U Seal Water Filter U Seal Water Hx.
- Excess Letdown Hx.
X X X X 7. Explain the function and operation of the letdown pressure control valve PCV-62-81.
X X X X 8. Explain the function and operation of the three way temperature divert valve TCV-62J9.
X X X X 9. Explain the function and operation of the three way divert valve LCV-62-1 18.
X X X X 10. Explain the VCT level program.
X X X X 1 1. Explain the reason for maintaining> 17 psig H2 pressure in the VCT relative to RCP operation.
X X X X 12. Explain the automatic actuation logic and interlocks associated with the VCT outlet valves, FCV-62-1 32 and 133 and the CCP suction valves from the RWST, FCV-62-135 and 136.
X X X X 13. Describe the CCPs. Include capacity and power supplies.
X X X X 14. Explain how to locally control charging flow using the following equipment:
U COP discharge valve FCV-62-93 U Charging header FCV-62-89 U FCV-62-93 bypass X X X X 15. Explain the conditions that must exist to allow opening of the ROP No. 1 seal bypass (FCV-62-53) after receiving a high temp alarm on the RCP lower bearing or leakoff, in accordance with S01-68.02.
3-OT-SYSO62A Revision 14 Page 8of83 A R S S U 0 R T 0 0 A X X X X 16. List the CVCS relief valves, with setpoints and relief paths for each.
X X X X 17. Describe the indications of a leaking or stuck open letdown relief valve, RV-62-662.
X X X X 18. Explain the reason for adding hydrazine and lithium hydroxide to the RCS and when it should be added.
X X X X 19. Discuss the process for placing a hydrogen or nitrogen blanket on the VCT and adjusting VCT pressure, in accordance with SQl-62.01.
X X X X 20. Discuss the function of the CVCS mixed bed and cation bed demineralizers.
X X X X 21. Describe three conditions that require bypassing the CVCS demineralizers.
X X X X 22. Discuss resin breakthrough and relate the consequences to the RCS.
X X X X 23. Explain the precautions regarding placing an unborated mixed bed demineralizer in service, in accordance with SOl-62.01.
X X X X 24. Explain the necessity for checking the CCP breaker after each operation, in accordance with SOl-62.01.
X X X X 25. Explain why a change in RCS boron concentration is required during plant operation.
- 26. Objective deleted.
X X X X 27. Describe the boric acid blender.
X X X X 28. Describe the modes of operation of the CVCS Boron Concentration and Reactor Makeup Control System.
X X X X 29. Discuss how to perform manual immediate boration, include when this is necessary.
X X X X 30. Discuss how chemicals are injected into the RCS.
X X X X 31. Given a set of plant parameters or indications diagnose conditions and/or problems relative to the CVCS.
X X X 32. Regarding Technical Specifications and Technical Requirements for this system:
I Identify the conditions and required actions with completion time of one hour or less.
- Explain the Limiting Conditions for Operation, Applicability, and Bases.
I Given a status/set of plant conditions, apply the appropriate Technical Specifications and Technical Requirements.
3-OT-SYSO62A Revision 14 Page 9of83 ARS S U ORT 0 0A X X X 33. [Discuss recent plant events involving gas intrusion into systems providing safety injection or boron injection functions.]
X X X 34. [Discuss the effects of gas intrusion on accident response.]
X X X 35. [Discuss the primary causes of gas intrusion to include design deficiencies, operating deficiencies, and maintenance deficiencies.]
- 36. Deleted.
X X X 37. Explain why seal water supply temperature is monitored at the RCP via RCP lower bearing temperatures.
WBN 10-2011 NRC RO Exam As Submitted 811512011
- 32. 005 A1.01 032 Given the following plant conditions:
- Unit 1 is in Mode 5, midloop operation.
- RHR Train A in service at a flow rate of 2100 gpm.
- The RCS temperature is stable at 126°F.
- The operator throttles open 1-FCV-74-32, RHR HXS BYPASS.
Which ONE of the following identifies how the RCS temperature and the RHR flow rate indicated on 1 -M-6?
RCS Temperature RHR Flow A. Decreases Increases B. Decreases Decreases C Increases Increases D. Increases Decreases Page 88
WBN 10-2011 NRC RO Exam As Submitted 8/15/2011 DISTRA CTOR ANAL YSIS:
A. Incorrect, Plausible because the typical thought process is when bypassing a heat exchanger less heat will be picked up allowing the temperature to drop and because of where the flow is measured the indicated flow rate increasing is correct.
B. Incorrect, Plausible because the typical thought process is when bypassing a heat exchanger less heat will be picked up allowing the temperature to drop and because there is a flow element on the flow through the heat exchanger that would sense a lower flow but it is not the flow element that provides the indication on the control board.
C. Correct, with the valve being opened further (until it is stopped by a restricting device placed on the valve during midloop operations), more flow to bypass the RHR HX. Less flow through the heat exchanger results in less cooling allowing RCS temperature to increase. Since total flow is measured downstream of where the HX Bypass connects to the HX discharge line (less overall system resistance),
the flow indication will rise.
D. Plausible because the RCS temperature increasing is correct and because there is a flow element on the flow through the heat exchanger that would sense a lower flow but it is not the flow element that provides the indication on the control board.
Question Number: 32 Tier: 2 Group 1 KIA: 005 A1.01 Residual Heat Removal System Ability to predict and/or monitor changes in parameters (to prevent exceeding design limits) associated with operating the RHRS controls including:
Heatup/cooldown rates Importance Rating: 3.5 I 3.6 10 CFR Part 55: 41.5 /45.5 IOCFR55.43.b: Not applicable K/A Match: K/A is matched because the question requires the ability to predict and/or monitor changes in the RCS cooldown rate and RHR system flow rates associated with operating the RHRS controls, Technical
Reference:
1-47W810-1 R19 1-47W811-1 R55 Page 89
WBN 10-2011 NRC RO Exam As Submitted 811512011 Proposed references None to be provided:
Learning Objective: 3-OT-SYSO74A
- 22. Explain the Normal RHR Cooldown mode by way of a simplified drawing.
Cognitive Level:
Higher Lower X Question Source:
New Modified Bank Bank X Question History: SQN bank question 005 Al .01 001 used on the SQN 4/2007 exam with changes in stem conditions and the question statement and 2nd part of distractors B and D changed. Not sufficient change to call bank modified.
Comments:
Page 90
005A1.O1001 Given the following plant conditions:
5Q 3j\4J)(%
- Plant cooldown in progress using two trains of RHR.
- The flow is 2500 gpm per train.
- The RCS cooldown rate is 25°F per hour.
- RCS temperature is 250° F.
- The demand signal is RAISED on 1-FCV-74-32, RHR Heat Exchanger Bypass Valve.
Which ONE (1) of the following describes the effect on RCS cooldown rate and on total indicated RHR system flow?
RCS Cooldown Rate Indicated RHR Flow A. INCREASES INCREASES B. INCREASES REMAINS CONSTANT C? DECREASES INCREASES D. DECREASES REMAINS CONSTANT
3-OT-SYS074A Revision 11 Page 5 of 50 PROGRAM Watts Bar Operator Training II. COURSES A. NOTP License Training B. License Certification C. AUORequal D. License Operator Requal III. TITLE Residual Heat Removal System IV. LENGTH OF LESSON A. NOTP 8 Hours B. License Certification 4 Hours V. TRAINING OBJECTIVES 0 0<
DO I
< O Cl) C!)
X X X X 01. State the purpose/function of the RHR System in accordance with FSAR section 5.5.7.
X X X X 02. Sketch the RHR System, including both trains from suction to hot and cold leg injection X X X X 03 State the plant conditions including reactivity effects that must be met prior to placing the RHR System in service in accordance with SOI 74.01.
X X X X 04. State the safety-related or emergency functions of the RHR System in accordance with the RHR System Description.
X X X X 05. Describe each of the modes of the RHR System.
X X X X 06. Identify the systems with which the RHR System interfaces.
X X X X 07. Describe the RHR pumps, including power supply, logic, and capacity.
X X X X 08. State the conditions that will result in an auto start of the RHR Pump Room Cooling System in accordance with the RHR System Description.
X X X X 09. State the conditions that will result in an auto start of the RHR pumps in accordance with the RHR System Description.
X X X 10. The plant has just entered Mode 3 with crosstie valves FCV-33 & 35 closed. Determine if Tech Spec operability requirements are met and what actions, if any, are required.
X X X X 11. Describe the auto operation of the RHR pump mini-flow valves.
X X X X 12. Describe the affect of a Safety Injection Signal on the RHR Hx outlet valves.
3-OT-SYSO74A Revision 11 Page6of50 0 0 D
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X X X X 13. Explain how the RCS temperature is controlled using the RHR System.
X X X 14. An RCS cooldown is in progress at a rate of 30°F/Hr with both trains of RHR in service. Describe how you would increase the cooldown rate to 50°F/ Hr while maintaining the same RHR flow rate in accordance with S0l-74.01. Also include control room indications of pump conditions.
X X X 15. State the interlocks associated with the RHR Pump inlet valves (FCV 74-3 & -21) in accordance with the RHR System Description.
X X X 16. State the interlocks associated with the RCS loop 4 HL suction valves to RHR (FCV-74-1 & -2) in accordance with the RHR System Description.
X X X 17. State the interlocks associated with the RCS loop 4 HL suction bypass valves (FCV-74-8 & -9) in accordance with the RHR System Description.
X X X X 18. State the design basis and setpoint of the RHR suction piping relief valve, in accordance with FSAR Section 5.5.7.3.3.
X X X X 19. State the design basis of the RHR System in accordance with FSAR Section 5.5.7.1.
X X X X 20. Explain why, at low RCS pressures, it is necessary to use RHR for letdown capability.
X X X X 21. Explain the RHR alignment as it pertains to standby emergency core cooling by drawing a simplified drawing.
X X X X 22. Explain the Normal RHR Cooldown mode by way of a simplified drawing.
X X X 23. The RCS is being cooled down at 50°F/Hr using RHR cooling.
Identify parameters and limitations in accordance with the Press and Temp Limits Report (PTLR) that must be observed.
X X X 24. State the three sources of heat load when conducting an RCS cooldown with the RHR system.
X X X 25. Deleted X X X X 26. State two plant conditions which require that only one train of RHR cooling be in service.
X X X X 27. With the RCS in a solid water condition and letdown from the RHR
. system, explain the operator actions required to increase the RCS pressure.
X X )( X 28. With the RCS in a solid water condition and letdown from the RHR system, describe the response of FCV 62-81, Letdown Pressure Control valve, when the operating RHR pump is stopped, include the net effect on the RCS pressure.
X X X X 29. While on RHR Mid-loop operation, FCV-63-1 can be used to makeup to the RCS from the RWST. Determine what cautions must be observed when adding RCS makeup in this manner.
3-OT-SYS074A Revision 11 Page 7of50 0 0<
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X X X X 30. Explain, by use of a simplified drawing, the RHR Injection Mode after an SI signal.
X X X X 31. Plant conditions are such that an AUTO swapover to the RHR containment sump is required. Describe the automatic sequence of events including the initiating setpoints.
X X X X 32. Delete X X X X 33. By use of a simplified drawing, describe the RHR Recirculation Mode after 3 hours3.472222e-5 days <br />8.333333e-4 hours <br />4.960317e-6 weeks <br />1.1415e-6 months <br /> of cold leg injection.
X X X 34. Explain from where the RHR System takes suction during a severe loss of RCS coolant accident (LOCA).
X X X 35. Identify the procedure used to control the operation of the RHR System during mid-loop at WBN.
X X X 36. Describe the methods available at WBN for monitoring RCS level during mid-loop operation on RHR.
X X X X 37. [Identify what possible discrepancies could occur in indicated level during a loss of RHR capability. (SOER 88-003, Rec. 3a).]
X X X X 38. [Briefly describe the response to a loss-of-core cooling flow with no indication of core coolant temp, include method to determine heatup rate. (SOER 88-003, Rec. 3a, 3b & 3d).]
X X X X 39. [Briefly describe indications of RHR pump cavitation and actions needed to restore core cooling flow. (SOER 88-003, Rec. 3c and IN 89-067).]
X X X X 40. Regarding Technical Specifications and Technical Requirements for this system:
- a. Identify the conditions and required actions with completion time of one hour or less.
- b. Explain the Limiting Conditions for Operation, Applicability, and Bases.
- c. Given a status/set of plant conditions, apply the appropriate Technical Specifications and Technical Requirements.
X X X 41. Deleted.
3-OT-SYSO74A Revision 11 Page8of5O 0 0<
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X X X X 42. Describe the in-plant location of:
- a. RHR Pumps and Pump Rooms
- b. RHR Heat Exchangers
- d. Control Room Switches, Alarms, and Indications
- g. FCV-74-3 & -21 (RHR Pump Inlet Valves)
- h. FCV-74-12 & -24 (RHR Pump Miniflow Valves)
- i. FCV-74-16 & -28 (RHR Htx Outlet Valves)
- j. FCV-74-32 (RHR Htx Bypass Valve)
- k. FCV-74-36 & -37 (Manual Isolation Valves to FCV-74-32)
I. FCV-63-1 (RWST to RHR Valve)
- n. FCV-72-40 & -41 (RHR Containment Spray)
- o. FCV-74-33 & -35 (RHR Heat Exchanger Outlet Crosstie)
X X X X 43. Identify the power supplies to the pressure boundary isolation valves of the RHR System.
WBN 10-2011 NRC RO Exam As Submitted 8/1512011
- 33. 006 K5.07 033 Given the following:
- Unit I was operating at 100% power when a reactor trip and SI with loss of offsite power occurred 20 minutes ago.
- Pressurizer pressure dropped to 1750 psig, then recovered five minutes later to 2235 psig.
Current conditions:
- Offsite power has been restored.
- Pressurizer level is currently at 68% and stable.
- RCS cold leg temperatures are 561°F and stable.
- RCS hot leg temperature is 590°F and slowly decreasing.
- RVLIS indicates 96%.
- All SGs are at 1125 psig and controlled by the SG PORVs.
- ES 1 1, SI Termination, is being performed and is at the step for determining RCP status.
Which ONE of the following identifies the impact of the above conditions on RCP restart?
A. RCP restart is NOT allowed; The cold ECCS water injected t6the RCS cold legs could result in reactor restart.
B. RCP restart is NOT allowed; The cold ECCS water injected to the RCS cold legs could result in a pressure surge in the RCS.
C. RCP restart is allowed only after an engineering analysis of the boration from ECCS injection during natural circulation operation.
Dv RCP restart is allowed; Natural circulation flow has been established and has removed the cold ECCS water from the cold legs.
Page 91
WBN 10-2011 NRC RO Exam As Submitted 8115/2011 DIS TRACTOR ANAL YSIS:
A. Incorrect, Plausible because the cold ECCS water would be stagnant in the Cold Legs resulting in a large mass of cold water being sent into the core when the RCP was started which results in a pressure increase. There is a Caution in SOl-68. 02 that addresses an expected pressure transient inadvertently lifting a Pzr PORV following dilution during the restart of an RCP, but it is not for the conditions in the question. Also a precaution in GO6 stating If all RCPs are stopped for greater than 5 minutes AND RCS temperature is greater than the charging and seal injection temperature, do NOT restart a pump UNTIL a Pzr steam bubble exists.
This will minimize a pressure transient due to the previously injected cold water when the first RCP is started. Again different than conditions in the question.
B. Incorrect, Plausible because if natural circulation was not established the cold ECCS water would be stagnant in the Cold Legs resulting in a large mass of cold water being rapidly heated when the RCP was started which results in a positive reactivity addition. There is a Caution in SOl-68. 02 that addresses the Resumption of flow in that loop could flush unborated water to the core and cause a rapid change in shutdown margin, but it is not for the conditions in the question.
C. lncorrect, Plausible because of a Precaution in SOl-68. 02 stating Starting a RCP following a natural circulation cooldown during which boration of the RCS took place, can result in a rapid boron dilution of the reactor core. Reactor engineering staff should be consulted for analysis prior to RCP start. But from the conditions in the stem a cooldown has not been performed.
D. Correct the conditions indicate natural circulation is occurring which would have resulted in the cold ECCS flow being mixed with the warmer RCS water and moved from the cold legs through the reactor coolant system.
Question Number: 33 Tier: 2 Group: 1 K/A: 006 K5.07 Emergency Core Cooling System Knowledge of the operational implications of the following concepts as they apply to ECCS:
Expected temperature levels in various locations of the RCS due to various plant conditions Importance Rating: 2.7 / 3.0 10 CFR Part 55: 41.5/45.7 IOCFR55.43.b: Not applicable Page 92
WBN 10-2011 NRC RO Exam As Submitted 8/15/2011 K/A Match: K/A is matched because the question requires knowledge of the operational implications of restarting an RCP following the injection of cold ECCS into the RCS while the RCS is at normal operating conditions during a loss of forced RCS flow.
Technical
Reference:
ES-ti, SI Termination, Revision 0017 SOI-68.02, Reactor Coolant Pumps, Revision 0034 GO-6, Unit Shutdown From Hot Standby To Cold Shutdown, Revision 0047 Proposed references None to be provided:
Learning Objective: 3-OT-EOPO100
- 8. Given a set of plant conditions, use E-1, ES-i .1, ES-i .2, ES-i .3, and ES-i .4 to correctly diagnose and implement: Action Steps, RNOs, Foldout Pages, Notes, and Cautions.
3-OT-G00600
- 4. State the precautions and operating requirements for the Reactor Coolant Pumps (RCP5) when performing a cooldown to Cold Shutdown per GO-6.
Cognitive Level:
Higher X Lower Question Source:
New Modified Bank X Bank Question History: Prairie Island 1 bank question 006 K507 in INPO bank Comments:
Page 93
- Unit I Rev. 0017 Step Action/Expected Response Response Not Obtained CAUTION If seal injection and thermal barrier cooling had previously been lost to any RCP, that pump should not be started prior to TSC evaluation.
NOTE Either Loop 1 or 2 pzr spray valve is effective for Loop 2 RCP in service or for Loops 1, 3, & 4 RCPs in service.
- 25. DETERMINE RCP status:
- a. CHECK RCP(s) RUNNING to a. ESTABLISH normal pzr spray, provide normal pzr spray. Loop 2 preferred:
N
- 1) IF RVLIS less than 95%,
THEN:
- RAISE pzr level greater than 90%, OR UNTIL level stops rising.
- RAISE RCS subcooling to greater than 95°F
[115°F ADV].
- CONTROL pzr heaters as necessary.
- REFER TO Table 1, RCP Emergency Restart Criteria.
Step continued on next page.
Page 15 of 35
- Uniti Rev.0017 Step Action/Expected Response Response Not Obtained
IFLoop2RCPcanNOTbe started, THEN START ALL other RCPs.
- 6) IF no RCP(s) can be started, THEN MONITOR natural circulation:
- RCS subcooling greater than 65°F [85°F ADV].
- S/G press controlled or dropping.
- T-hot stable or dropping.
- Incore TICs stable or dropping.
- T-cold at saturation temp for S/G press.
IF natural circulation NOT established, THEN DUMP steam at a greater rate.
Page 16 of 35
WBN Reactor Coolant Pumps SOl-68.02 Unit I Rev. 0034
. Page9of37 3.0 PRECAUTIONS AND LIMITATIONS (continued)
- 2. If all RCPs are stopped and the RCS is being cooled by RHR, a non-uniform RCS temp distribution may occur.
- 3. Ensure SG-to-RCS AT is less than 50°F before starting an RCP.[c.2]
U. When RCS temp is above 160°F, at least one RCP shall be operating.
V. Ear Protection must be worn in the area where the RCPs are running.
W. Notify System Engineer when RCP Heater Breaker is opened during Mode 5 or 6. Heaters protect motor windings from moisture intrusion. This information reproduced on a placard posted on Rx Vent Bds IA-A (C7B/8B) and lB-B (C7BI8B).
X. During plant cooldown, only two RCPs may be operated below RCS temp of 160°F.
Y. For plant heatup, only one RCP may be operated below 80°F and only two RCPs may be operated between 80 and 105°F. Exception: Four RCPs may be operated below 105°F for approximately 5 minutes for sweeping and venting.
Z. Starting a RCP following a natural circulation cooldown during which boration of the RCS took place, can result in a rapid boron dilution of the reactor core.
Reactor engineering staff should be consulted for analysis prior to RCP start.
[C.6]
AA. Evaluate circumstances which would require starting an RCP when COMs is armed, no other RCP5 are running, and the RCS pressure is near the COMs setpoint. This may result in the expected pressure transient inadvertently lifting a Pzr PORV.
WBN Unit Shutdown From Hot Standby To GO-6 Unit I Cold Shutdown Rev. 0047 Page 9 of 90 3.1 PRECAUTIONS (continued)
- 6. Plant evolutions that may cause pressurizer level or RCS pressure or temperature to become unstable should be prohibited during approach to solid water operations.
- 7. If pressurizer level, RCS pressure or temperature, or charging flow become unstable during approach to solid water operations, pressurizer level should be reduced to less than 80% and investigate cause.
- 8. Configuration changes to either CVCS or RHR should be prohibited during approach to solid water operations.
- 9. 1-PCV-62-81, LETDOWN PRESSURE CONTROL, should be maintained near the middle of its control range during approach to solid water operations.
- 10. RHR inlet is NOT to be isolated from the RCS UNLESS there is a Pzr bUbble or charging pumps are stopped. This ensures a relief path when the RCS pressure is low.
- 11. When water solid with RHR letdown in service, 1-FCV-62-83, RHR LETDOWN FLOW CONTROL should be FULLY OPEN, and RCS pressure controlled by 1-PCV-62-81, LETDOWN PRESSURE CONTROL. During this Mode, the normal letdown system must remain in service, with all orifices open.
- 12. If all RCPs are stopped for greater than 5 minutes AND RCS temperature is greater than the charging and seal injection temperature, do NOT restart a pump UNTIL a Pzr steam bubble exists. This will minimize a pressure transient due to the previously injected cold water when the first RCP is started.
- 13. If all RCPs are stopped and the RCS is being cooled down by the RHR HXs, a non-uniform RCS temperature distribution may occur. Do NOT start an RCP UNLESS a Pzr steam bubble exists.
- 14. When RCS pressure is being maintained by Letdown through PCV-62-81, changes to the flow through the RHR loop by throttling valves or starting/stopping RHR pumps will cause RCS pressure changes, e.g.,
stopping an RHR pump will raise RCS pressure by 100 to 150 PSIG.
E. Operational components of the RHR system should NOT be taken out of service for elective maintenance following a reactor shutdown Until the decay heat rate is sufficiently low to be readily handled by other systems or methods.[c71
WBN Unit Shutdown From Hot Standby To GO-6 Unit I Cold Shutdown Rev. 0047
. PageIIof9O 3I PRECAUTIONS (continued)
- 0. Cooldown
- 1. Operators are encouraged to cooldown the plant on a continuous cooldown rate instead of stepwise rate (e.g., rapid RCS cooldown followed by nearly constant temperature for the balance of the hour). Stepwise cooldowns may promote Reactor Vessel embrittlement.[c.2j
- 2. Cooldown rate affects Pzr level. Net charging must be maintained as high as practical to offset the effects of cooldown and letdown flow.
- 3. During RCS cooldown and depressurization above 350°F, maintaining RCS Subcooling between 75 and 125°F ensures adequate Subcooling.
- 4. During unit cooldown, all SGs should be connected to the steam header to assure uniform RCS cooldown.[c3]
- 5. CVCS letdown flow should be maximized with the demineralizer in service before cooldown, and continued throughout shutdown Letdown may be reduced to 45 gpm If necessary to support cooldown and maintain PZR level but should be restored to maximum when level can be maintained.
I
- 6. When performing activities with RCS support systems during and after the cooldown, be alert to potential circumstances or conditions that may introduce lower boron concentration solutions to the core.[c.6, c.15] 0 P. Steps within this instruction may require venting, draining, or breaching radioactive components or systems to the atmosphere. Appropriate radiation protection controls must be established to prevent the spread of contamination and avoid the generation of airborne radioactivity.
1006 K5.07 I 9/30/2004 I? Exit Iprairie Island 1 Exam Level JR Question Record Search Given the following conditions:
Question -A reactor trip and SI with loss of offsite power occurred.
-All equipment operates as designed.
-Pressurizer pressure drops to 1750 psig, then recovers one minute later to 2250 psig
-Pressurizer level has increased to 48%
-RCS cold leg temperatures are 545 F and stable
-RCS hot leg temperature is 582 F and slowly decreasing
-Both SGs are at 1005 psig controlled by the SG PORVs
-Offsite power is now available and non safeguard buses have been energized.
-Twenty minutes has elapsed since the reactor trip.
-SI has been terminated per ES 0.2, SI Termination.
-Step 23 of ES 0.2 directs the start of one RCP.
What is the impact of the above conditions on RCP restart?
a.The RCP can be started, natural circulation flow has been established and has removed the cold ECCS water from the cold legs.
Answer:
b.The RCP can be started, natural circulation flow has NOT been established but ECCS flow did not occur to the RCS.
1 Distracter 1 Distracter 2 c.RCP restart is not allowed, the reactivity addition from cold ECCS water in the RCS cold legs could result in reactor restart.
1 Dastracter Id.RCP restart is not allowed, the RCS will overpressurize upon RCP restart when cold ECCS water is heated.
Distracter Analysis:
Answer:
Distracter 1:
Distracter 2:
Distracter 3:
3-OT-EOPO1 00 Rev 14 Page 4 of 138 pages I. PROGRAM:
Watts Bar Operator Training II. COURSE:
A. License Training B. License Operator Requal III. TITLE:
E-1, Loss of Reactor or Secondary Coolant IV. LENGTH OF LESSON:
A. License training 3 Hours B. License Operator Requal License operator REQUAL time will be determined after objectives are identified.
V. TRAINING OBJECTIVES:
0 0 0 D
ci) U)
X X X 1. Describe the purpose of procedure E-1 as listed in Section 1.Ooftheprocedure.
- 2. Explain the basis for tripping the RCPs in an accident situation given the following conditions:
- a. RCS press less than 1500 psig
- b. Phase B isolation signal initiated.
- 3. List the condition that must be checked and satisfied before removing a RCP from service in accident conditions due to low RCS pressure (< 1500 psig).
X X X 4. Explain the basis for the continuous action step to monitor containment pressure and stop the CS pumps when containment pressure is verified less than 2.0 psig.
X X X 5. For a given H2 concentration in containment determine if the H2 igniter should be energized and explain why or why not.
3-OT-EOPO1 00 Rev 14 Page 5 of 138 pages V. TRAINING OBJECTIVES: (continued) 0 0 D F C) (I)
X X X 6. Explain the basis for isolating the CLAs when RCS press decreases to less than 250 psig.
X X 7 Explain the reason for transfer to Hot Leg recirc following a LOCA including the location of the worst case break for this concern X X X 8 Given a set of plant conditions use E-i ES-i 1 ES-i 2 ES-i 3 and ES-i 4 to correctly diagnose and V implement: Action Steps, RNOs, Foldout Pages, Notes, and Cautions.
X X X 9. List the four parameters (not setpoints) that must be verified prior to SI termination.
X X X 10. Determine the correct procedure transition if during the SI termination steps of ES-i .1 it is determined that PZR level cannot be maintained using the normal charging flowpath.
X X 11 Explain the basis for waiting for a faulted SIG to complete depressurization before checking RCS press stable or increasing following the establishment of normal charging and prior to stopping any running SI pumps.
-L- X X X 12. Discuss the purpose of ES-i.2 Post LOCA V Cooldown and Depressurization.
X X X 13. Justify the procedure step to shutdown the RHR pumps if RCS pressure is greater than 150 psig.
X X X 14. Identify the procedural transition required if any SIG level continues to increase with feedflow isolated.
3-OT-EOPOI 00 Rev 14 Page 6 of 138 pages V. TRAINING OBJECTIVES: (continued) 0 0 D
C))
X 15. Explain the basis for limiting the RCS cooldown rate to 100°F in one hour.
X 16. Discuss the requirement to check RCS subcooling greater than 65°F prior to RCS depressurization.
X 17. Describe how depressurization of the RCS might result in the capability to maintain PZR level when PZR level could not be maintained prior to depressurization.
X 18. Analyze and explain the process that leads to a new RCS equilibrium pressure following the shutdown of an ECCS pump during the ES-I .2 reduction sequence.
X 19. Explain why subcooling is minimized following the alignment of normal charging in procedure ES-I .2.
X 20. Discuss and justify the priority of usage given to proedure ES-l .3, Transfer to RHR Containment Sump.
X 21. Justify the ES-l .3 procedural requirement to shutdown the SI pumps if RCS press increase to greater than 1350 psig while aligned for sump recirc.
X 22. Identify and explain the basis of the interlock on the RHR pump discharge to the SI and CCP suction (FCV-63-8 and I I).
X 23. State from memory the action required if offsite power is lost following transfer to RHR containment sump cold leg recirc. Explain the basis for the required action.
3-OT-EOPO1 00 Rev 14 Page 7 of 138 pages V. TRAINING OBJECTIVES: (continued) 0 0 D
C,)
X X X 24. Discuss the basis for ensuring the COP suction from the RWST (LCV-62-135 and 136) handswitches are left in the A-Auto position following transfer to cold leg recirc in procedure ES-i .3.
X 25. Explain why procedure ES-i 3 directs the operator to leave the containment spray pumps aligned to the RWST until RWST level is less than 8%.
X 26. Identify the action required if RWST level decreases to 8% during swapover to CL sump recirc.
X 27. Explain the basis for limiting temperature above current conditions after transition to SI termination. (SOER 94-001, Rec. 4b)
X X 28. Describe the actions in ES-i .1, SI Termination, required in the event that SI does not reset.
I 1!41 GO-6, PLANT SHUTDOWN FROM HOT STANDBY TO COLD SHUTDOWN 3-OT-GOO600 Revision 4 Page 4 of 83 I. PROGRAM Watts Bar Operator Training II. COURSE License Training Non-License Training III. TITLE GO-6, Unit Shutdown From Hot Standby to Cold Shutdown IV. LENGTH OF LESSON License Training 3 Hours Non-License Training 3 Hours V. TRAINING OBJECTIVES AR S S U OR T 0 0 A X X X 1. Explain the reason for each Precaution and Limitation listed in GO-6.
X X X 2. Briefly state the reason for borating the Reactor Coolant System (RCS) prior to cooldown. State the limits for the Reactor Coolant System /Pressurizer (PZR) zCB and explain the preferred method for equalizing the RCS/PZR CB.
X X X 3. Discuss the major steps for taking the unit from Hot Standby to Cold Shutdown per GO-6.
X X X 4. State the precautions and operating requirements for the Reactor Coolant Pumps (RCPs) when performing a cooldown to Cold Shutdown per GO-6.
X X X 5. Describe the manual block and automatic reset of the Low PZR Pressure SI at <1970 (P-i 1).
I 1!41 GO-6, PL\NT SHUTDOWN FROM HOT STANDBY TO COLD SHUTDOWN 3-OT-GOO600 Revision 4 Page 5 of 83 V. TRAINING OBJECTIVES (Continued)
AR S S U OR T 0 0 A X X X 6. Identify the cooldownlheatup limits for the RCS and PZR, and given plant conditions, use the cooldown, heatup, and pressure limitations curves to determine that the plant is operating within limits.
X X X 7. State the limit and basis on AT between the Pressurizer Spray Nozzle and fluid.
X X X 8. State what conditions must exist in order to place Residual Heat Removal (RHR) in service during cooldown per GO-6.
X X X 9. Describe the precautions and basis on solid water Residual Heat Removal operations.
X X X 10. Discuss the operation of 1 -PCV-62-8 1 to maintain RCS pressure and Letdown flow when in a solid water condition.
VI. TRAINING AIDS A. Marker Board and Markers B MultimedialOverhead projector(s)
VII. MATERIALS A. Attachments Attachment 1 - GO-6, Unit Shutdown From Hot Standby To Cold Shutdown Attachment 2 - [INPO SOER 94-2, Boron Dilution Events in PWRs.]
Attachment 3 SI-68-44, RCS Pressure/Temperature Limits Attachment 4 - WBN PERs 77176, 77699, 79910
WBN 10-2011 NRC RO Exam As Submitted 811512011
- 34. 007 K5.02 034 The pressurizer (PZR) cold cal level is at 40% with a nitrogen blanket present.
Which ONE of the following choices completes the statement below?
When establishing a steam bubble, in accordance with GO-I, Unit Startup From Cold Shutdown To Hot Standby, the pressurizer administrative maximum heat-up rate limit is (1) and the PORVs are closed and placed in P-AUTO when (2) w A. 75°F in one hour Letdown flow exceeds charging flow B. 75°F in one hour PZR Liquid Temperature reaches 235°F C. 100°F in one hour Letdown flow exceeds charging flow D. 100°F in one hour PZR Liquid Temperature reaches 235°F DIS TRACTOR ANAL YSIS:
A. lncorrect Plausible because GO-I identifies the administrative heatup rate is 75°F and there is a note prior to Step [10.18] in Section 5.2.1 stating When letdown flow is ABOVE charging flow, and RCS pressure is either stable or slowly rising, a PZR steam bubble is forming. This would apply during bubble formation from solid water conditions which is different than the conditions in the question stem.
B. Correct, GO-I (Rev 0070) Section 5.2.1 has a Caution prior to step [4] stating Administrative PZR maximum heatup-rate is 75°F in 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />. 100°F in I hour shall NOTbe exceeded. (TR 3.4.2) and Step [8] states When 1-TI-68-319, PZR LIQUID TEMP, reaches 230-240°F then close PORVs, and place in P-AUTO.
C. Incorrect, Plausible because 100°F is identified in the same Caution statement but it is the Tech Requirement limit not the administrative limit. Also there is a note prior to Step [10.18] in Section 5.2.1 stating When letdown flow is ABOVE charging flow, and RCS pressure is either stable or slowly rising, a PZR steam bubble is formThg. This would apply during bubble formation from solid water conditions which is different than the conditions in the question stem.
D. Incorrect, Plausible because 100°F is identified in the same Caution statement but it is the Tech Requirement limit not the administrative limit. Also plausible because closing the PORVs if the temperature is 235°F is correct in accordance Step [8]
which states When 1-Tl-68-319, PZR LIQUID TEMP, reaches 230-240°F, then close PORVs, and place in P-AUTO.
Page 94
WBN 10-2011 NRC RO Exam As Submitted 8/1512011 Question Number: 34 Tier: 2 Group 1 K/A: 007 K5.02 Pressurizer Relief Tank/Quench Tank System (PRTS)
Knowledge of the operational implications of the following concepts as they apply to PRTS:
Method of forming a steam bubble in the PZR Importance Rating: 3.1 I 3.4 10 CFR Part 55: 41.5 / 45.7 IOCFR55.43.b: Not applicable KIA Match: K/A is matched because the question requires knowledge of the changes in conditions (operational implications) due to forming a steam bubble in the pressurizer when starting with a nitrogen blanket in the pressurizer.
Technical
Reference:
GO-i, Unit Startup From Cold Shutdown to Hot Standby, Revision 0070 Proposed references None to be provided:
Learning Objective: 3-OT-GO0100
- 5. Describe the basic steps necessary to establish a steam bubble in the Pressurizer (Pzr) with or without a Nitrogen blanket.
Cognitive Level:
Higher Lower X Question Source:
New Modified Bank X Bank Question History: Question 007 K5.02 034 used on WBN 05/2009 exam modified by changing the first part of the question. The correct answer position relocated from C to B.
Comments:
Page 95
WBN Unit Startup From Cold Shutdown To GO-I Unit I Hot Standby Rev. 0070 Page 37 of 126 Date Initials 5.2.2 Establish Pressurizer Bubble with Nitrogen Blanket
[1] ENSURE PZR level is between 20% and 60%
[1-Ll-68-321, PZR-COLD CAL LEVEL].
[2] ENSURE PORV AND BLOCK valves OPEN.
[3] INITIATE applicable sections of 1-SI-68-44, RCS Temperature/Pressure Limits and Pressurizer Temperature Limits.
itC CAUT9V Administrative PZR maximum heatup rate is 7F in 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />. 100°F in 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> shall NOT be exceeded. (TR 3.4.2)
NOTES
- 1) PZR heater backup control group IC should be on when RCS pressure is below its automatic setpoint.
- 2) PZR heater(s) may be energized or deenergized at Unit Operator discretion to maintain optimal heatup rate within allowable limits.
[4] ENERGIZE all available PZR heaters.
NOTES
- 1) Pressurizer Relief Tank (PRT) pressure and temperature should be monitored during venting. Normal pressure range is 6.5 to 8 psig and temperature is less than 1 12°F.
- 2) Pressurizer PORV flow should be verified by ACOUSTIC MONITORS, 1-XI-96-340A and 1-XI-68-334 [0-M-25].
[5] CHECK a rise in the PZR relief line temperature indicators when PZR steaming begins.
[6] MAINTAIN PRT temperature below high temperature alarm setpoint using spray and drain operation.
[7] IF PRT pressure approaches 8 psig, THEN VENT via 1-PCV-68-301, PRT VENT TO WDS VENT HDR.
WBN Unit Startup From Cold Shutdown To GO-I Unit I HotStandby Rev. 0070 Page 38 of 126 Date Initials 5.2.2 Establish Pressurizer Bubble with Nitrogen Blanket (continued)
[8] WHEN 1-TI-68-319, PZR LIQUID TEMP, REACHES 230 to 240°F, THEN CLOSE PORVs, AND PLACE in P-AUTO.
[9] ENERGIZE PZR heaters as needed to MAINTAIN RCS pressure.
[10] ADJUST Charging and Letdown to maintain between 25 and 30% cold cal PZR level.
[11] GO TO Section 5.3.
End of Section
WBN Unit Startup From Cold Shutdown To GO-I Unit I Hot Standby Rev. 0070 Page 35 of 126 Date Initials 5.2.1 Transition to Solid Water Operation (continued)
[10.17] INITIATE PZR heatup by performing the following:
[10.17.1] PLACE 1-PIC-68-340A, PZR PRESS MASTER CONTROL, in MANUAL and drive output to zero.
[10.17.2] ENERGIZE all available PZR heaters.
[10.17.3] CONTROL PZR heatup rate using PZR heaters and spray.
ç7D \
NOTES
- 1) When letdown flow is above charging flow and RCS pressure is either stable OR slowly rising, a PZR steam bubble is forming
- 3) It is desirable to maintain all heaters energized to ensure a constant oufflow through PZR surge line.
[10.18] BEFORE exceeding 250°F, OBTAIN Chemistry concurrence that PZR chemistry is acceptable for operation above 250°F.
[10.19] WHEN PZR is between 425 and 430°F, THEN ADJUST Charging and Letdown to slowly lower PZR level to between 25 and 30% while maintaining RCS pressure with heaters and spray.
007 K5.02 034 u9N ;c The pressurizer (PZR) cold cal level is at 40% with a nitrogen blanket present.
v Which ONE of the following choices completes the statement below?
When establishing a steam bubble, in accordance with GO-I, Unit Startup From Cold Shutdown To Hot Standby, the first indication of steaming from the PZR to the Pressurizer Relief Tank is verified by observing a rise in (1) and a steam bubble is first confirmed when (2)
(1) (2)
A. relief line temperature. Letdown flow exceeds charging flow.
B. Pressurizer Relief Tank level. Letdown flow exceeds charging flow.
C. relief line temperature. PZR Liquid Temperature reaches 235F.
D. Pressurizer Relief Tank level. PZR Liquid Temperature reaches 235F.
3-OT-GOOi 00 Revision 7 Page 3 of 34 I. PROGRAM Watts Bar Operator Training II. COURSE A. License Training III. LESSON TITLE GO- 1, Unit Startup From Cold shutdown To Hot Standby IV. LENGTH OF LESSON License Training 3 Hours V. TRAINING OBJECTIVES AR S S U OR T 0 0 A X X X 1. Define the six reactor operating modes.
X X X 2. Identify the maximum allowable Reactor Coolant System (RCS)
Heatup rate per GO-i.
X X X 3. Describe the major steps necessary to heat the unit, from Cold Shutdown to Hot Standby, as discussed in class.
X X X 4. Identify the temperature and pressure limits for having Residual Heat Removal (RHR) System Suction aligned to RCS per GO-i.
X X X 5. Describe the basic steps necessary to establish a steam bubble in the Pressurizer (Pzr) with or without a Nitrogen blanket.
X X X 6. Explain how RCS temperature, pressure, and inventory are controlled per this instruction.
X X X 7. Explain, as described in GO-i, the operating precautions for the Reactor Coolant Pumps (RCPs).
X X X 8. Describe the conditions requiring Cold Overpressure Protection System (COPS) to be armed and operable per GO-i.
WBN 10-2011 NRC RO Exam As Submitted 811512011
- 35. 008 A3.02 035 Given the following plant conditions:
- Unit 1 is at 100% power with Thermal Barrier Booster Pump (TBBP) lB running.
- TBBP handswitches on 0-M-27 are aligned with:
1-HS-70-131A, THRM BAR BSTR PMP 1A (TBBP) is PULL A-P AUTO.
1-HS-70-130A, THRM BAR BSTR PMP lB (TBBP) is IN A AUTO.
- Loss of Offsite Power occurs.
Which ONE of the following identifies how the TBBP5 will respond during the blackout relay sequencing to restore equipment?
A Only the IA TBBP will restart.
B. Only the 1 B TBBP will restart.
C. Both of the TBBPs will restart.
D. Neither of the TBBPs will restart.
DISTRACTOR ANAL YSIS:
A. Correct The normal alignment of the TBBPs is with the handswitches in A-P AUTO which allows the pumps to restart following a Blackout. With the TBBP lB not in the A-P AUTO position, the pump cannot restart following the blackout. Only the TBBP IA will restart.
B. Incorrect, Plausible if the conclusion is that the pump that was running will be the pump that restarts. Similar to the ERCW pump logic where running pump is selected to restart following a blackout.
C. lncorrect, Plausible because both pump handswitches are in an Auto position and the A-AUTO function can be mistakenly determined to be for the automatic restart.
D. Incorrect, Plausible because both pump handswitches are in a position for the accident signal (A-Auto signal), but the accident signal is not to restart on a blackout; it is to trip the pumps on a Phase B containment isolation signal.
Page 96
WBN 10-2011 NRC RO Exam As Submitted 8/15/2011 Question Number: 35 Tier: 2 Group 1 K/A: 008 A3.02 Component Cooling Water System (CCWS)
Ability to monitor automatic operation of the CCWS, including:
Operation of the CCW pumps, including interlocks and the CCW booster pump Importance Rating: 3.2 / 3.2 IOCFRPart55: 41.7/45.5 10CFR55.43b: Not applicable K/A Match: K/A is matched because the question requires the ability to predict the TBBP(s) (which are the CCW booster pumps) that will be running following a change in plant conditions with a defined control switch alignment.
Technical
Reference:
S0l-70.0 1, Component Cooling Water (CCS) System, Revision 0068 1-47W611 3 R4 Proposed references None to be provided:
Learning Objective: 3-OT-SYSO7OA
- 4. Explain the logic associated with each valve/pump control in the CCS.
- 8. Describe the thermal barrier system; include purpose, pump capacity, and logic.
Cognitive Level:
Higher X Lower Question Source:
New Modified Bank X Bank Question History: WBN question SYSO7OA.19 004 modified.
Comments:
Page 97
WBN Component Cooling Water (CCS) SOl-70.01 Unit I System Rev. 0068 Page8of 145 3.0 PRECAUTIONS AND LIMITATIONS A. CCS desgn press is 150 psig. Design Temp is 200°F.
B. Normal CCS Supply Header (Hx outlet) temp is 60°F to 95°F for A Hx.
and 40°F to 95°F for B and C Heat exchangers. When ERCW inlet temperature is below 60°F, supply temperature may be lower than 40°F for the B and C heat exchangers and lower than 60°F for A heat exchanger but should be maintained as close to normal as possible by throttling ERCW flow.
Additional limitations are discussed in Section 6.0.
C. CCS Pump flow: Minimum is 900 gpm; Maximum is 6800 gpm per pump.
D. C-S Pump Local Throwover Switch must NOT be operated if either Red light on the panel is on, indicating one of the 480V SD Bd ACBs is CLOSED.
Switch Transfer may require Tech Spec LCO 3.7.7 entry.
E. Chemicals added to CCS for corrosion control are TOXIC. The Material Safety Data Sheets for the chemicals added to CCS (i.e. sodium molybdate, sodium hydroxide and Cobratec TT5O), have precautions necessary for handling treated CCS water.
F. When heat load is on CCS, ERCW must be in service to CCS Hx(s).
G. CCS misaligned to SFP Hx(s) causes water interchange between Unit I and Unit2.
H. To avoid CCS Hx tube vibration and excessive load, do NOT exceed shell design flow of 12000 gpm.
I. All CCS Pumps start on a Blackout if handswitch is in A-P AUTO; however while U2 is in deferred status and Pump 2B-B is aligned with Pump C-S, Header 2A low press auto-start signal is disconnected from Pump 2B-B, and the SI Signal is disconnected from both U2 Pumps.
J. Before operating Train B equipment, flow must be established in lB Header.
K. If a CCS loop is SHUT DOWN, associated Rad monitor will alarm on low flow.
L. Discharge of various relief valves is routed to station drainage.
M. Thermal Barrier Booster Pumps trip on Cntmt ØB Isol signal, and Cntmt Isol Valves for Thermal Barriers, and RCP upper and lower oil coolers CLOSE. If power is lost to either TBBP (Rx MOV Bd) the ØB seal-in is lost and the pump can restart with no flow path.
N. When isolating CCS-supplied Hx, the primary side must be isolated and allowed to cool below 200°F BEFORE isolating CCS flow.
- WBN Component Cooling Water (CCS) SOl-70.01 Unit I System Rev. 0068 Page22ofI45 Date________ INITIALS 5.4 Placing Thermal Barrier Booster Pumps in Service
[1] ENSURE Section 5.1 and 5.3 COMPLETE.
[2] ENSURE the following valve OPEN:
NOMENCLATURE LOC POSITION UNID PERF INITIAL THERMAL BAR SUP CIV ØB- O-M-27B OPEN 1-HS-70-133A THERMAL BAR SUP CIV ØB- O-M-27B OPEN 1-HS-70-134A THERMAL BAR RET CIV ØB- O-M-27B OPEN 1-HS-70-87A THERMAL BAR RET CIV ØB- O-M-27B OPEN 1-HS-70-90A
[3] START either of the following (NIA pump NOT started):
NOMENCLATURE LOCATION POSITION UNID PERF INITIAL THRM BAR BSTR PMP 1A O-M-27B START 1-HS-70-131A (TBBP)
THRM BAR BSTR PMP lB O-M-27B START l-HS-70-130A (TBBP)
[4] MONITOR rise in flow to approximately 160 gpm on 1-FI-70-81, TH BAR RET HDR FLOW [0-M-27B].
WBN Component Cooling Water (CCS) SOl-70.01 Unit I System Rev. 0068 Page 23 of 145 Date________ INITIALS 5.4 Placing Thermal Barrier Booster Pumps in Service (continued)
[5] IF TBBP 1A is available or running, THEN ENSURE 1-HS-70-130A, THRM BAR BSTR PMP lB (TBBP) in A-P AUTO if available. [Cl]
IV
[6] IF TBBP lB is available or running, THEN ENSURE 1-HS-70-131A, THRM BAR BSTR PMP IA (TBBP) in A-P AUTO if available. [c.1]
IV
[7] INDEPENDENTLY VERIFY the following:
NOMENCLATURE LOC POSITION UNID VERIF INITIAL THERMAL BAR SUP CIV ØB
- O-M-27B OPEN 1-HS-70-133A IV THERMAL BAR SUP CIV ØB
- O-M-27B OPEN 1-HS-70-134A IV THERMAL BAR RET CIV ØB
- O-M-27B OPEN 1-HS-70-87A IV THERMAL BAR RET CIV ØB
- O-M-27B OPEN 1-HS-70-90A IV End of Section
SYS07OA.19 004 Given the following plant conditions:
4AJ &1
- Unit in service w[th TBBP lA-A running.
- Loss of Offsite Power occurs.
- Shutdown boards are re-energized by diesel generators.
Which of the following alignments of the Thermal Barrier Booster Pump would result in both pumps sequencing on?
a9 IA-A TBBP control switch in A-P-AUTO 1 B-B TBBP control switch in A-P-AUTO
3-OT-SYSO7OA Revision 13 Page5of56 I. PROGRAM Watts Bar Operator Training II. COURSES A. License Training B. NOTP C. License Operator Requal D AUO Requal III. TITLE Component Cooling System IV. LENGTH OF LESSON A. Licensed Training 1 .5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> B. NOPT 3.0 hours0 days <br />0 hours <br />0 weeks <br />0 months <br /> License Requalification and NAUO Requalification times will be determined after objectives are identified V. TRAINING OBJECTIVES 0 0<
DO I Cl) Cl)
X X X X 1 State the design basis of the Component Cooling Water System (CCS)_in_accordance_with_FSAR_section_9_2_2 X X X X 2 Sketch a basic drawing of the CCS include all pumps major heat exchangers_and_blocks_showing_major_uses_of_CCS X X X X 3. Describe the CCS pumps, include power supply, pump type, capacity, lubrication, and logic.
X X X X 4. Explain the logic associated with each valve/pump control in the
. OCS.
X X X X 5. Explain the operation, purpose, and location of the C-S CCS Pump power supply transfer switch.
X X X X 6. Describe the CCS heat exchangers, include cooling medium.
3-OT-SYSO70A Revision 13 Page 6 of 56 0 0 D 0 Cl) Cl)
X X X X 7. Given a tube rupture in a CCS heat exchanger, describe the resulting flow path.
X X X X 8. Describe the thermal barrier system; include purpose, pump capacity, and logic.
X X X X 9. Describe the CCS Surge Tanks; include purpose, capacity, and method of makeup to them.
X X X X 10. Explain how the CCS pumps are sealed and how the seal leakage return unitoperates.
X X X X 1 1. Identify ten (10) uses of CCS during normal and post accident conditions.
X X X X 12. Identify the automatic actions that occur upon detection of CCS high radiation.
X X X 13. Describe the actions which must be taken if CCS is lost to the RCP motors.
X X X X 14. [Identify two indications of biofouling in a heat exchanger. (SOER 84-1, Rec. 4)]
X X X 15. Describe the effect of a loss of CCS to the major equipment supply headers:
- a. Miscellaneous equip. & Reactor Bldg. Headers
- d. Spent Fuel Pit Supply Header X X X 16. Regarding Technical Specifications and Technical Requirements foi this system:
- a. Identify the conditions and required actions with completion tim of one hour or less.
- b. Explain the Limiting Conditions for Operation, Applicability, and Bases.
- c. Given a status/set of plant conditions, apply the appropriate Technical Specifications and Technical Requirements.
3-OT-SYS070A Revision 13 Page 7 of 56 0 0<
DO Q I Q Cl) Cl)
X X X X 17. Identify the in-plant location of each of the following:
- a. Component Cooling Water Pumps.
- b. Component Cooling Water Heat Exchangers.
- c. Thermal Barrier Booster Pumps.
- d. Component Cooling System Surge Tanks.
- e. Seal Leakage Return Tank and Pumps.
- f. C-S CCS Pump Power Supply Throw-over Switch.
- g. CCS Flood Mode Spool Pieces.
- h. RHR Heat Exchangers.
X X X 18. Correctly locate all control room controls and indications associated with the Component Cooling System.
X X X 19. Given a set of plant conditions, determine the correct response of the CCS system.
X X X 20. Given a CCS instrument and failure mode, identify how the instrument will respond and what interlock(s) or control function(s) will be affected, including effects on system/component operation.
X X X 21. Given a loss of instrument air/control power, determine the effect on the following valves:
- a. Surge tank make up valve.
- b. Surge tank vent valve.
- c. Letdown HEAT EXCHANGER. temp. control valve.
X X X 22. Explain how the failure of CCS or its support systems could lead to core damage.
X X X 23. [Identify the action(s) to be taken by the Operator if significant heat exchanger degradation due to fouling is detected. (SOER 84-1, Rec. 4)]
3-OT-SYSO7OA Revision 13 Page 34 of 56 a The Thermal Barrier Booster Pumps are Horizontal,
- r. Th Tnrr- r o r ru -
single stage, centrifugal pumps with:
rio p ow t 00 trou 0 m woh a Design Flow:
-De go. o:
Ui 16O gpm. a 160 gpm.
De 13O feet head a Design Pressure:
-J U) a l30feethead.
- Power Supplies:
a TBBP lA-A Rx MOV Board 1A1-A.
BOARD BREAKER
L T8BP1A-A RxMOVBoard1Al-A 2C TBBP lB-B Rx MOV Board IBI-B 2C Ui
-J Hyperlink to the Industrial Safety homepage and U) select Arc Flash Hazard Calculation and Required Protection
- 2. Discuss the MCR controls associated with Thermal Barrier Booster Pumps.
a Stop function.
- Start function.
U, a A-Auto starts on:
Ui
- Low flow.
-I a HighP.
U) a SI.
a PulIA-P Auto:
a Same as above, plus.
a Station Blackout.
3-OT-SYSO7OA Revision 13
- AUTO STARTS Low flow, if in A-P Auto (Normal handswitch
.auItl.t,7.l blhI.n 1050.1t LOerloer. 1 A-PAub (Bunt huodnIut, poelbon) arth no Ito spot position) with no Blackout, SI, or Phase B BlOckout SI. or Phase B 5000 STARTS After blackout (80) usth AS erA PAuloarrdStcetdoe,.cfluaA 35 seconds (SI eInck ocacrnno after blackout
- After blackout (BC) with HS in A-P Auto and enttagore.toasdOslal010AthoJt blon5eeq000c.
SI erenal present)
LatlonenSflooohgfl In SPIt Shutdown Board voltage restored (with or reps Pba.oOteolaBon 2_Br without SI signal present)
Blackout I.-.
- TRIPS w
- Differential flow high.
-J
- Phase B Isolation.
Cl)
- Blackout.
COMMITMENT: Hyperlink to the OE homepage and select SQN-II-S-92-100, Dual Unit Reactor Trip
- 3. Discuss the function and operation of the TBBP Bo TBP Appendix Ft Appendix R Control Panel.
Control Panel
- Breaker F reaker jee Oiilnc2_0ll B- OFF F,nntirt
- On function.
LU
- OFF function.
-J U)
- Pump Control TBBP Appendix R Control Panel
- Stop function.
Pump Coot ol B topuc n
- Start function.
flOTiO)fl nc.]J-rr F (In II F. B-roth ulolt
- P-AUTO, with the transfer switch in AUX, LU TI IttAUXt Itt P0IIA same as MCR Pull A-P Auto.
Ott I
-J U)
WBN 10-2011 NRC RO Exam As Submitted 8/15/2011
- 36. 010 A1.09 036 Given the following:
- Unit 1 is operating at 100% power.
- Abnormal RCS leakage has been detected.
- One of the pressurizer PORV5 is suspected to have seat leakage.
Without any additional operator action, which ONE of the following identifies...
(I) the MCR indication that would be used to identify the leaking PORV and (2) how long the crew has to close the PORV Block valve if the PORV is determined to be declared inoperable?
A. TAILPIPE TEMPS on 1-M-4 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> B. TAILPIPE TEMPS on 1-M-4 30 minutes 0 PZR VALVES ACOUSTIC MONITOR on 0-M-25 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> D. PZR VALVES ACOUSTIC MONITOR on 0-M-25 30 minutes Page 98
WBN 10-2011 NRC RO Exam As Submitted 8115/2011 DISTRA CTOR ANAL YSIS:
A. lncorrect Plausible because there is a PORV tailpipe indication on 1-M-4 along with indications for each of the 3 safety valve tailpipe temperatures, but the PORV indicator is on the common tailpipe from both PORVs Tech Spec and allowing one hour to close the block valve is correct.
B. Incorrect, Plausible because there is a PORV tailpipe indication on 1-M-4 along with indications for each of the 3 safety valve tailpipe temperatures, but the PORV indicator is on the common tailpipe from both PORVs and there are Tech Spec 3.4 actions required to be completed within 30 minutes (e.g. restore minimum temperature for criticality).
C. Correct, there are flow indicating LEDs on the PZR Valves Acoustic Monitor for each PORV that will indicate which valve is leakage through and Tech Specs require the PORV Block valve to be closed within 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br />.
D. lncorrec1, Plausible because the PZR Valves Acoustic Monitor which has LED indicating flow each of the PORVs is correct and there are Tech Spec 3.4 actions required to be completed within 30 minutes (e.g. restore minimum temperature for criticality).
Question Number: 36 Tier: 2 Group 1 KIA: O1OA1.09 Pressurizer Pressure Control System (PZR PCS)
Ability to predict and/or monitor changes in parameters (to prevent exceeding design limits) associated with operating the PZR PCS controls including:
Tail pipe temperature and acoustic monitors Importance Rating: 3.4! 3.7 10 CFR Part 55: 41.5 / 45.5 IOCFR55.43.b: Not applicable KIA Match: K/A is matched because the question requires the ability to monitor changes in parameters associated with PORV tailpipes and interpret the information to accurately determine which PORV is leaking.
Technical
Reference:
MCR photos ARI-88-94, Reactor Coolant System, Revision 0022 Tech Spec LCO 3.4.11, Pressurizer Power Operated Page 99
WBN 10-2011 NRC RO Exam As Submitted 8/15/2011 Technical
Reference:
MCR photos ARI-88-94, Reactor Coolant System, Revision 0022 Tech Spec LCO 3.4.11, Pressurizer Power Operated Relief Valves (PORVs)
Proposed references None to be provided:
Learning Objective: 3-OT- SYSO68K
- 3. Correctly locate control room controls and indications associated with the Acoustic Monitoring System, including:
- a. alarm
- b. panel
- c. LEDs
- d. power switch
- e. individual valve indications
- f. tail pipe temperature indications Cognitive Level:
Higher Lower X Question Source:
New Modified Bank X Bank Question History: WBN bank question SYSO68K.03 001 modified Comments:
Page 100
WBN Reactor Coolant System ARI-88-94 Unit I Rev. 0022 Page II of5O 89-A Source Setpoint 1-TS-68-331 235°F PZR PORV LINE TEMP HI (Page 1 of 1)
Probable A. One or both PZR PORVs open or leaking through Cause:
NOTE This alarm may come in due to other valves connected to the PRT, such as PZR Safeties, open or leaking through.
Corrective [1] CHECK 1-Tl-68-331, PZR PORV LINE TEMP [1-M-4], to confirm alarm.
Action: [2] ENSURE PZR pressure below PZR PORV lift setpoint AND CHECK PZR PORVs CLOSED.
[3] IF PZR PORVs indicate CLOSED, THEN:
[3.1] CHECK Acoustic monitors [O-M-25] for indication of leaking PZR PORV.
[3.2] OBTAIN SRO permission to determine affected PZR PORV by manipulating the respective block valves.
[3.3] MONITOR the following for indication of leakage:
- 1-LI-68-300, PRT LEVEL
- 1-Pl-68-301, PRT PRESS
- 1-Tl-68-309, PRT TEMP
[3.4] IF PORV(s) partially open, THEN REFER TO AOl-I 8, Malfunction of Pressurizer Pressure Control System.
[4] REFER TO AOl-6, Small Reactor Coolant System Leak.
[5] REFER TO Tech Specs.
References:
I -47W61 0-68-5 AOI-6 AOl-18 Tech Specs
WBN Reactor Coolant System ARI-88-94 Unit I Rev. 0022 Page 23 of 50 91-A Source Setpoint PORV 25% flow through PORV/ PZR I -XE-68-340A Safety Valve PORVISAFETY 1-XE-68-334 (0.25 indication on OPEN Safety Acoustic Monitor)
I -XE-68-363 1 -XE-68-364 (Page 1 of 1) 1 -XE-68-365 Probable A. PZR PORV or Safety leaking through or open Cause:
Corrective [1] CHECK PZR pressure to determine if PZR PORV/Safety should be open.
Action: [2] CHECK other indications to determine if PZR PORV or Safety is open:
- Windows 89-A and 89-B
- 1-Tl-68-328 [1-M-4] Safety
- 1-Tl-68-329 [1-M-4] Safety
- 1-Tl-68-330 [1-M-4] Safety
- 1-Tl-68-331 [1-M-4] PORV
[3] ENSURE PZR PORV and Safeties CLOSED when PZR pressure is below lift setpoi nt.
[4] IF PZR PORV is NOT closed when PZR pressure is below lift setpoint, THEN:
[4.1] CLOSE associated PZR PORV block valve.
[4.2] NOTIFY SRO.
[4.3] REFER TO AOl-i 8, Malfunction of Pressurizer Pressure Control System.
[4.4] REFER TO Tech Specs.
References:
1 -47W61 0-68-5 AOl-18
if 300 300 U H0,i U
S 1t Dicj12
I 9IXL New Page 1 Page 1 of 1 OM26 METEOROLOGICAL &
flflHRTIC MON)TOR I fl!I!
file://C:\Documents and Settings\NRC4Test\Desktop\MCR pictures\WBN Sim Photos\OM... 4/15/2011
Pressurizer PORV5 3.4.11 3.4 REACTOR COOLANT SYSTEM (RCS) 3.4.11 Pressurizer Power Operated Relief Valves (PORV5)
LCO 3.4.11 Each PORV and associated block valve shall be OPERABLE.
APPLICABILITY: MODES 1,2, and 3.
ACTIONS NOTE Separate Condition entry is allowed for each PORV.
CONDITION REQUIRED ACTION COMPLETION TIME A. One or more PORVs A.1 Close and maintain power to 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> inoperable and capable of associated block valve.
being manually cycled.
B. One PORV inoperable B.1 Close associated block valve. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> and not capable of being manually cycled.
B.2 Remove power from associated 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> block valve.
AND B.3 Restore PORV to OPERABLE 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> status.
(continued)
Watts Bar-Unit 1 3.4-22 Amendment 55
Pressurizer PORVs 3.4.11 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME C. One block valve C.1 Place associated PORV in 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> inoperable, manual control.
AND C.2 Restore block valve to 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> OPERABLE status.
D. Required Action and D.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of Condition A, B, AND or C not met.
D.2 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> E. Two PORVs inoperable E.1 Close associated block valves. 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> and not capable of being manually cycled.
E.2 Remove power from associated 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> block valves.
AND E.3 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> AND E.4 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> F. Two block valves F.1 Place associated PORVs in 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> inoperable, manual control.
AND (continued)
Waifs Bar-Unit 1 3.4-23
Pressurizer PORVs 3.4.11 ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME F. (continued) F.2 Restore one block valve to 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> OPERABLE status.
G. Required Action and G.1 Be in MODE 3. 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> associated Completion Time of Condition F not AND met.
G.2 Be in MODE 4. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.11.1 NOTE Not required to be met with block valve closed in accordance with the Required Action of Condition B or E.
Perform a complete cycle of each block valve. 92 days SR 3.4.11.2 Perform a complete cycle of each PORV. 18 months Watts Bar-Unit 1 3.4-24
SYSO68K.03 001 (A c-rrs c(L Given the following conditions:
- RCS leakage has been detected
- The OATC reports that he suspects a leaking Pzr PORV Which of the following could be used by the crew to identify the leaking PORV?
- a. Acoustic monitor indications on 1-M-4
- b. PORV/Safety valve tailpipe temperature indications on ICS Acoustic monitor LED indications on O-M-25
- d. PORV/Safety valve tailpipe temperature alarms on 1-M-5 The correct answer is C.
- a. Incorrect there are no acoustic monitor indications on M-4, only a common alarm on M-5.
- b. Incorrect PORV tailpipe temperature will rise from a leaking PORV a single tailpipe indication for both PORVs exist on ICS.
- c. Correct LED indications for varying leakage values are located on the common acoustic monitor panel on O-M-25.
- d. Incorrect there is a common tailpipe temperature alarm on 1-M-5 for all PORVs and Safeties.
REFERENCES:
3-OT-STG-068K AOI-6 K/A 010 Al .09 [3.4/3.7]
002 K4.05 [3.8/4.2]
SYSO68C.11006 i(
Given the following conditions:
- Abnormal RCS leakage has been detected.
- The OAC reports he suspects a leaking Pzr PORV.
Which of the following would be used to identify which PORV is leaking?
- a. PORV OPEN and CLOSED indicating lights LIT at the same time
- b. PORV tailpipe temperature indication rising
- c. PRT temperature and pressure rising dY PORV tailpipe acoustic monitor lights LIT The correct answer is D K/A: 002000K405 [3.8 / 4.2]
Reference:
3-OT-SYSO68C History: SQN NRC Exam 09/19/97 Level: Memory
3-OT-SYSO68K Revision 6 Design Basis The Acoustic Monitoring system does not provide any emergency design criteria.
- 1. The Acoustic Monitoring system does not provide any Safety Funcdon emergency design criteria.
The Acoustic Monitoring systnnr dons not provide any spooifio sofoty functions for plont nperotiorrs. Safety Function LU
- 1. The Acoustic Monitoring system does not provide any
-J specific safety functions for plant operations.
U)
General Description
- 2. Overview the basic theory of operation of the Acoustic P. Flow through a valve generates vibrations that which can be detected on the downstream Monitoring system.
Is, piping of the valves.
Ui ft. Valve position is determined by using the
- Flow through a valve generates vibrations that can relationship between eibration and flow rate past the valve. be detected on the downstream piping of the
-J valves.
U)
- Valve position is determined by using the relationship between vibration and flow rate past the valve.
- 3. Preview the major components of the Acoustic M br Components Monitoring system.
- Accelerometer Mount.
- Accelerometer.
Charge Converter (Preamp).
° CD I ::: MCR Display.
LU
- Optional: Question class on how an
-J L accelerometer works.
U)
Answer: The accelerometer sensor is a piezoelectric device. It utilizes the phenomena that certain crystals emit a charge or voltage when stressed. This charge is proportional to the acceleration level caused by the turbulent fluid flow in the piping downstream of the associated valve.
3-OT-SYSO68K Revision 6 Page 10 of 20 OBJECTIVE 2 4. Discuss the General Arrangement of the Acoustic Monitoring system field equipment.
B One Accelerometer for each Pressurizer Safety, F and PORV.
uJ B Each accelerometer feeds a separate Flow
-J Monitoring Module on the MCR display panel.
Cl)
OBJECTIVE 3 5. Discuss the General Arrangement of the Acoustic Monitoring system MCR display panel.
tw ttCR DopIoy ponti B Located on MCR control panel 0-M-25.
contorn0000porato mPot
- nrrpt,o-- -flrItott 03 mofront:
0-All fhroo PZR Sofolton p 5fP B The MCR Display panel contains a separate input 0-The two PZR PORnO.
2 I r Ir Ir: r channel from each Pressurizer Safety, and PORV.
- I °:I°: :I° B Panel also houses the power supply module and
.9. I : I: :I:1: the Alarm Test module.
t I IZ; 1 ;L
- J B Optional: Question the class if one valve is open/leaking thru will it affect the indications for Lii the other valves.
Answer: Since all PZR Safety Valves and PORVs
-J Cl) have a common downstream pipe connection prior to entering the Pressurizer Relief Tank (PRT),
when a single accelerometer senses that one valve is not fully closed the other valve accelerometers will be exposed to some associated dynamic stress in the common piping.
The LED display for the valve that is not fully closed will have a larger signal being generated, and thus, more LED5 will be lit.
3-OT-SYSO68K Revision 6 133 Alarm and Test Module o Receives input from each of the 514 Valve Flow Monitoring doles when a flew of 25% is
- 1. Discuss the function, operation and indications fr Alarre LED is lit wherrever soy Valve Flew of 25% is present. LED will ectinguish if level associated with the 914 Valve Flow Monitoring drops below 25%. 0 Module.
o Outputs to MOE aneunoiator and lOS computer LC) point. (Alarm does not seal in) b Test switch is used to
- Receives input from each of the 914 Valve Flow w test the MOE annunoiu and lOS oanrpater point.
PZR Monitoring Modules when a flow of 25% is sensed.
P0EV 1 SAFETY OPEN
-J
- Alarm LED is lit whenever any Valve Flow of 25%.
U)
I Outputs to MCR annunciator and ICS computer point.
- Test switch is used to test the MCR annunciator and ICS computer point.
- Optional: Use ARI 1-XA-55-5A window 91A to discuss response to alarm.
Alternate Indications Alternate NCR indications can be used to determine if a pressarienr safaty or P0EV is leahing. 1. Discuss the alternate MCR indications that can be Prossurizar Safety arrd P0EV Tailpipe Tempvraturvs
- Pressurizer level indicativns cv panel V.4.
used to determine if a pressurizer safety or PORV is
- PET cvvditiuv indications an pond V.4.
- Frossanzor prussuru indications cv panvl MS.
leaking.
- Prvscorc PORV indicatirrg livhtc cv puval V.5
- Pressurizer Safety and PORV Tailpipe cc Temperatures.
w I Pressurizer level indications on panel M-4.
-J I PRT condition indications on panel M-4.
C!)
I Pressurizer pressure indications on panel M-5.
- Pressure PORV indicating lights on panel M-5.
OE Link to OE Homepage and discuss PER-31350 as it relates to using multiple indications to validate annunciators. This also reinforces SER-3-05 for using MflTP Irh nf fhta ir1r1IrfIr,nQ AIiII h dicri iQQcr1 in Pressurizer Safety and PORV Tailpipe Temperatures
- 1. Discuss the MCR indications for Pressurizer Safety and PORV Tailpipe Temperature available on panel
- I I Pressurizer tailpipe temperature for each of the J three pressurizer safeties.
U (Tl-68-328, Tl-68-329 and Tl-6833O,)
- Common tailpipe temperature for thePORVS (Tl-68-331)
3-OT-SYSO68K Revision 6
- 2. Discuss how elevated tailpipe temperatures can be Elevated tailpipe temperatures are odmative of safety valves not fatly closed.
used to indicate a safety valve or PORV is not fully S
- or ewe.
lo ye lro K0 r
ferry w Ps.
ft OCr closed.
w
- CC CO OK op rife C r pOrcK. NO ow
- Normal tailpipe temperature is ambient lower rtre OP Caftan a cr0 iKe rot Cr e.
containment temperature.
-J Cl)
- At normal operating temperature (NOT) any leakage would cause an increase in downstream tailpipe temperature above containment ambient temperature.
Pressurizer Level Indications
- 3. Discuss the MCR indications for Pressurizer Level available on panel M4.
LU
- Three channels of hot calibrated pressurizer level.
-j (LI-68-320, LI-68-335A and LI-68-339A)
Cl) B Pressurizer cold calibrated level indicator (TI-68-321).
ill 4. Discuss how pressurizer level can be used to indicate fo Any leakage past the PORVs or Safety Valves would result in a mass loss to the RCS a safety valve or PORV is not fully closed.
e Significant leakage would result ma small B Any leakage past the PORVs or Safety Valves initial increase in pressurizer level due to an in 0
surge, followed immediately by a decrease in would result in a mass loss to the RCS pressurizer level due to loss of inventory.
ci fe Lower leakage rates could be identified by: B Significant leakage would result in a small initial LU 5° Charging and etdoon floK mantatch.
5° Ueexpectcd cecrease in VCT level.
increase due to an in-surge, followed immediately
-J 5° Urexpocted autornafic makeap to tie VCT. by a decrease in pressurizer level due to loss of C,) inventory.
B Lower leakage rates could be identified by:*
B Charging and letdown flow mismatch.
- Unexpected decrease in VCT level.
- Unexpected automatic makeup to the VCT.
PRT Condition Indications I 5. Discuss the MCR indications for the PRT available on C., panel M4.
LU B PRT Level.
-J (LI-68-300) ci) B PRT Pressure (P1-68-301)
B PRT Temperature (TI-68-309).
3-OT-SYSO68K Revision 6 Page 4 of 4 PROGRAM Watts Bar Operator Training II. COURSES License Training Non-Licensed Training III. TITLE Acoustic Monitoring System IV. LENGTH OF LESSON A. License Training 2 Hours B. NOTP 2 Hours V. TRAINING OBJECTIVES
- 1. State the function of the Acoustic Monitoring System as described in this lesson plan.
- 2. List valves monitored by the Acoustic Monitoring System
- 3. Correctly locate control room controls and indications associated with the Acoustic Monitoring System, including:
- a. alarm
- b. panel
- c. LEDs
- d. power switch
- e. individual valve indications
- f. tail pipe temperature indications
WBN 10-2011 NRC RO Exam As Submitted 8/1512011
- 37. 010 K6.04 037 Unit I is operating at 100% power when the following sequence of events occurs:
- Pressurizer Power Operated Relief Valve (PORV) I -PCV-68-334 opens and fails to reseat when closed.
- Pressurizer PORV Block valve, 1-FCV-68-332, for PORV 334 cannot be closed.
- Pressurizer Relief Tank (PRT) pressure begins to slowly rise.
- The PRT pressure continues to rise until the PRT ruptures.
Which ONE of the choices below completes the following two statements?
1-PCV-68-301, PRT VENT TO WDS VENT HDR, will automatically close when the PRT pressure reaches psig.
When the PRT ruptures, the PORV tailpipe temperature will 1-PCV-68-301 closes PORV Tailpipe Temperature A. 2.Opsig beginto drop B. 2.0 psig rise at a faster rate C. 8.0 psig begin to drop D. 8.0 psig rise at a faster rate Page 101
WBN 10-2011 NRC RO Exam As Submitted 8/15/2011 DISTRA CTOR ANAL YSIS:
A. Incorrect, Plausible because 2.0 psig is the pressure that the vent header must be maintained less than when venting the PRT due to high pressure (AR! 88-C) and when the PRT rupture diaphragm blows the PORV tailpipe temperature starting to drop is correct.
B. Incorrect, Plausible because 2.0 psig is the pressure that the vent header must be maintained less than when venting the PRT due to high pressure (ARI 88-C) and because the leakage flow rate will rise when the PRT ruptures, the applicant may conclude that the temperature will start rising at a faster rate.
C. Correct, 1-PC V-68-301 will automatically close when the PRT pressure reaches 8.0 psig and as demonstrated during the TMI event, when the PRT rupture diaphragm blows the PORV tailpipe temperature will start to drop.
D. Incorrect, Plausible because 1-PCV-68-301 automatically closing when the PRT pressure reaches 8.0 psig is correct and because the leakage flow rate will rise when the PRT ruptures, the applicant may conclude that the temperature will start rising at a faster rate.
Page 102
WBN 10-2011 NRC RO Exam As Submitted 8/15/2011 Question Number: 37 Tier: 2 Group 1 K/A: 010 K6.04 Pressurizer Pressure Control System Knowledge of the effect of a loss or malfunction of the following will have on the PZR PCS:
PRT Importance Rating: 2.9 I 3.2 IOCFRPart55: 41.7/45.7 IOCFR55.43.b: Not applicable K/A Match: K/A is matched because the question requires knowledge of PRT conditions and how a loss of the PRT will affect indications in the pressurizer pressure control system.
Technical
Reference:
ARI-88-94, Reactor Coolant System, Revision 0022 1-47W813-1, R43 Steam Tables Proposed references None to be provided:
Learning Objective: 3-OT-SYSO68C
- 11. Describe the indication an operator has that a PORV is open or leaking through.
Cognitive Level:
Higher Lower X Question Source:
New Modified Bank X Bank Question History: WBN bank question 010 K6.04 036 used on 05/2009 exam modified.
Comments:
Page 103
WBN Reactor Coolant System ARI-88-94 Unit I Rev. 0022 Page6of5o 88-C Source Setpoint 1-PS-68-301 8.0 psig PRT PRESS HI (Page 1 of 2)
Probable A. Any of the following valves open or leaking through:
Cause:
- PZR PORVs or Safeties
- RHR Pumps suction or discharge reliefs
- RCP seal water supply relief
- SI Pumps discharge or recirc line reliefs
- CS Pumps suction reliefs
- Letdown relief
- Rx vessel head vent
- Charging Pump suction relief B. N 2 regulator malfunction NOTE 1-PCV-68-301 will auto-close at 8 psig to prevent over pressurizing the vent header.
Corrective [1] CHECK 1-Pl-68-301, PRT PRESS [1-M-41, to confirm alarm.
Action: [2] ENSURE 1-PCV-68-301 CLOSED.
[3] CHECK the following for indication of flow:
- PZR Safety line temperature 1-Tl-68-330, -329, and -328 [1-M-4]
- PZR PORV line temperature 1-Tl-68-331 [1-M-4}
- PZR PORV ans Safety acoustic indication [0-M-25]
[4] CHECK RV Head Vent Isol Vlaves 1-FSV-68-394, -395, -396, and -397 CLOSED.
[5] MONITOR the following for indication of leakage to PRT [1-M-4]:
- 1-Ll-68-300, PRT LEVEL
- 1-Tl-PRT TEMP Continued on Next Page
WBN Reactor Coolant System ARI-88-94 Unit I Rev. 0022 Page 7 of 50 88-C PRT PRESS HI Corrective Action: (Continued)
(Page 2 of 2)
[6] DISPATCH Operator to perform the following:
- CHECK for indication of lifting relief valves.
- CHECK N 2 pressure regulator 1-PCV-68-304 CLOSED AND ISOLATE regulator, if necessary.
[7] REDUCE PRT level and temperature to normal as necessary per SOl-68.O1.
[8] REDUCE PRT pressure to approximately 6.5 psig as follows:
[8.1] STATION Operator at panel O-L-2 to monitor vent header pressure and start Waste Gas Compressor if necessary.
[8.2] HOLD 1-HS-68-301A, PRT VENT TO WDS VENT HDR, in the OPEN position as long as the following conditions exist:
- Vent Header pressure is less than 2 psig.
- PRT pressure is greater than 6.5 psig.
[8.3] ENSURE 1-HS-68-301A in the CLOSED position.
[9] REFER TO Tech Specs.
References:
1-45W600-57-1 6 1 -47W61 0-68-6 1-47W61 1-68-1 SOI-68.01 Tech Specs
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NPG System REACTOR COOLANT SYSTEM N3-68-400l Description Rev. 0030 Document Page 158 of 225 Table 18 (Page 1 ofl)
Pressurizer Relief Tank Design Parameters Design pressure, psig Internal 100 External 15 Design temperature, °F 340 Normal operating pressure, psig 3 Volume, ft3 1800 Normal water volume, ft3 1350 Normal gas volume, ft 3 450 Number of rupture disks 2 Rupture disc relief capacity lb/hr 800,000 each Rupture disc release pressure, psig Nominal 91 Range 86-100 Cooling time required following design approx. I maximum discharge, hr.
Number of spray nozzles 5 Total Spray Flow, gpm 150
WM 32- j7iO-)
Unit 1 is operating at 100% power when the following sequence of events occurs:
- PZR Power Operated Relief Valve (PORV) 1-PCV-68-334 opens and sticks open.
- PZR PORV Block valve, 1-FCV-68-332 cannot be closed.
- Pressurizer Relief Tank (PRT) is at 43 psig and continues to rise.
Which ONE of the following completes the following statement?
The PRT rupture disc will blow when pressure reaches psig, at which point Pressurizer Power Operated Relief Valve tailpipe temperature will PRT Rupture Disc Setpoint PORV Tailpipe Temperature A. 85 psig Remain the same.
B. 85 psig Lower C. 100 psig Remain the same.
D. 100 psig Lower DISTRACTOR ANALYSIS
- a. Incorrect. Plausible, since the rupture disc blows at 85 psig. The applicant misapplies the constant enthalpy process and concludes that PORV outlet temperature rises.
- b. CORRECT. The rupture disc blows at 85 psi 9 and per the TMI lessons learned, and basic thermodynamic principles, PORV outlet temperature will lower.
- c. Incorrect. Plausible, since 100 PSIA is equivalent to 85 PSIG, and the applicant may recall inappropriate units.
The applicant misapplies the constant enthalpy process and concludes that PORV outlet temperature rises.
- d. Incorrect. Plausible, since 100 PSIA is equivalent to 85 PSIG, and the applicant may recall inappropriate units.
Per the TMI lessons learned, and basic thermodynamic principles, PORV outlet temperature will lower.
Question Number: 36 KIA: 010 K6.04 Knowledge of the effect of a loss or malfunction of the following will have on the PZR PCS: PRT Tier: 2 RO Imp: 2.9 RO Exam: 36 Cognitive Level: Low Group: I SRO Imp: n/a SRO Exam: 36 Source: New Applicable IOCFR55 Section: (CFR: 41.7/45.7)
Learning Objective: 3-OT-SYSO68C, Obj. 11: Describe the indication an operator has that a PORV is open or leaking through.
References:
INPO Bank question; ARI 88-C, PRT Press Hi.
KIA: 010 K6.04 Knowledge of the effect of a loss or malfunction of the following will have on the PZR PCS: PRT
3-OT-SYSO68C Revision 13 Page5of45 I. PROGRAM Watts Bar Operator Training II. COURSES A. License Training B.. Non-License Training III. TITLE PZR, PZR Pressure Control System! PZR Level Control System, and PRT IV. LENGTH OF LESSON A. License Training 4 Hours B. Non-License 6 Hours V.
Identify the three (3) main purposes of the Pressurizer.
Describe the major components of the Pressurizer.
Describe the purposes of the Manual Bypass Pressurizer Spray Throttle Valves.
Identify the normal setpoint required to auto open the PZR Relief Valves (PORVs).
Identify each setpoint and resulting automatic action for the Pressurizer Pressure Program.
State the basis for the low pressure reactor trip, as stated in Tech Specs Section 2.1.1.
State the basis for the high pressure reactor trip, as stated in Tech Specs Section 2.1.1.
Describe the operation of the master pressure controller.
Describe what control room indication would alert the operator that the pressurizer spray valves were open.
- 10. Describe the method of control for the power operated relief valves.
- 11. Describe the indication an operator has that a PORV is open or leaking through.
- 12. Identify the program setpoints, and describe any automatic actions relative to the pressurizer level program.
3-OT-SYSO68C Revision 13 Page 6 of 45 0 0 D
Cl) Cl)
X X X X 13. Describe the basis for the program setpoints of the pressurizer level program circuit.
X X X X 14. Explain the basis for programming the level vs. maintaining the level constant in the pressurizer.
X X X X 15. Describe the response to a deviation from pressurizer level program.
X X X 16. Explain the purpose of the PRT.
X X X 17. Identify the components which drain into the Pressurizer Relief Tank.
X 18. Deleted.
X 19. Deleted X X X X 20. Describe the in-plant location of major system components, instrumentation, controls, and piping/header arrangements.
X X X X 21. Describe the flow path of sources of supply, discharges, vents, drains, leakoff, and connections/penetrations that intertie this system to other systems.
X X X X 22. Explain the operation of major system components.
X X X X 23. Deleted X X X 24. Deleted
WBN 10-2011 NRC RO Exam As Submitted 811512011
- 38. 012 K2.01 038 Which ONE of the following identifies the plant electrical boards that supply power to the listed components on Unit 1?
SSPS Train B Reactor Reactor Trip Bypass Breaker A Trip Breaker 48v UV coil (BYA) Control Power Circuit A 12OvAC Vital Instrument 125V DC Vital Battery Board I Power Boards II and IV B. 120v AC Vital Instrument 125V DC Vital Battery Board II Power Boards II and IV C. I 20v AC Vital Instrument 1 25V DC Vital Battery Board I Power Board II ONLY D. 12OvAC Vital Instrument 125V DC Vital Battery Board II Power Board II ONLY DIS TRACTOR ANAL YSIS:
A. Correct, 120v AC Vital Instrument Power Boards II and IV supply the 48v Reactor Trip Undervoltage relay through an auctioneered circuit and the 125V DC Battery Board Ills the control power to BYA.
B. Incorrect, Plausible because the 120v AC Vital Instrument Power Boards II and IV supplying the 48v reactor Trip Undervoltage relay through an auctioneered circuit is correct and the 125V DC Battery Board II is the control circuit power supply Train B reactor trip breakers and BYA receives trip signal from Train B circuits.
C. lncorrect Plausible because the 120v AC Vital Instrument Power Boards Ills the only power supply to other components in SSPS TraIn B (e.g. Slave relays) and the 125V DC Battery Board I is the control power supply to BYA.
D. Incorrect, Plausible because the 120v AC Vital Instrument Power Boards II is the only power supply to other components in SSPS Train B (e.g. Slave relays) and the 125V DC Battery Board Ills the control circuit power supply Train B reactor trip breakers and BYA receives trip signals from Train B SSPS Reactor Trip circuits.
Page 104
WBN 10-2011 NRC RO Exam As Submitted 8/15/2011 Question Number: 38 Tier: 2 Group 1 KIA: 012 K2.01 Reactor Protection System Knowledge of bus power supplies to the following:
RPS channels, components, and interconnections.
Importance Rating: 3.3 / 3.7 IOCFRPart55: 41.7 IOCFR55.43.b: Not applicable K/A Match: K/A is matched because the question requires the knowledge of the bus power supplies to Reactor Protection System components Technical
Reference:
1-45W600-99-1 R7 N3-99-4003, Reactor Protection System, Revision 0021 Proposed references None to be provided:
Learning Objective: 3-OT-SYSO99A
- 2. Sketch a basic drawing of the Solid State Protection System.
Cognitive Level:
Higher Lower X Question Source:
New X Modified Bank Bank Question History: New question for the WBN 10/2011 NRC exam.
Comments:
Page 105
Bus 1-I Busl-N I I r
12OVAC Bus 1-Ill II Busl-IV I I I S____
Input Logic Output Cabinet Cabinet Cabinet
WAN System REACTOR PROTECTION SYSTEM N3-99-4003 Description Rev. 0021 Document Page 35 of 106 2.2.8 Separation, Fire Protection, or Intrazonal Protection Requirements (continued)
Channel independence shall be carried throughout the system extending from the sensor through to the devices actuating the protective function. Physical separation shall be used to achieve separation of redundant transmitters. Separation of wiring shall be achieved using separate wireways, cable trays, conduit runs and containment penetrations for each redundant channel set. Redundant equipment shall be separated by locating equipment in different protection rack sets. Each redundant channel set shall be energized from a separate ac power feed, which shall be fed from vital inverters and battery-backed (see Reference 7.2.6).
Separate routing shall be maintained for the four basic Reactor Protection System channel sets, sensing signals, comparator output signals, and power supplies for such systems. The separation of these four channel sets shall be maintained from sensors to instrument racks to logic system cabinets.
Separate routing of the reactor trip and ESFAS signals from the redundant logic system cabinets shall be maintained. In addition they are separated from the four process protection sets by spatial separation, by provision of barriers, or by separate cable trays or wireways.
The Reactor Protection System shall be protected from fire by physical separation and portions of the Fire Protection System (Reference 7.2.16). Additional requirements for fire protection and detection are found in WB-DC-40-62 (Reference 7.2.13) and N3-13-4002 (Reference 7.2.5). The Eagle 21 Process Protection System cabinets shall be designed in accordance with the requirements of IEEE 384-1981 (Reference 7.3.24).
2.2.9 Electrical Power Requirements Redundant 1 20-Vac Class 1 E electrical power shall be supplied to the Reactor Protection System. Each input protection channel and output train shall be energized from a separate battery backed ac power feed (see Reference 7.2.6).
The Reactor Protection System equipment shall obtain power from a static inverter and shall be designed to accept the possible voltage and frequency variations associated with the regulated static inverter output. The specified regulated output of the static inverter is 120 Vac +/-2% and 60 Hz +/-0.5 Hz. The allowed total harmonic distortion is 5%.
A. Power Distribution Train A and Train B Solid State Protection System (SSPS) shall receive power from the four 120V ac vital instrumentation busses. The channel I through IV busses shall enter their respective input cabinet compartments through fuses in the compartments. In the input compartments, the busses shall be used to operate relays driven by external contacts. Two of the four busses shall run through line noise filters at the rear of the input compartment into the dc power supplies in the logic cabinet. In Train A, busses I and III shall feed the power supplies and bus I shall feed the slave relays and in Train B, busses II and IV shall feed the power supplies and bus II shall feed the slave relays. Separate feeds shall be brought into the output cabinet for the slave relays to avoid running unfiltered lines through the logic cabinet.
- WAN System REACTOR PROTECTION SYSTEM N3-99-4003 Description Rev. 0021
. Document Page 36 of 106 2.2.9 Electrical Power Requirements (continued)
The two 48V dc and 15V dc power supplies in one train shall be auctioneered to form one 48 and one 15V dc bus. A zero volt bus or circuit common bus shall be formed by connecting the (-)48 and (-)15V lines. The zero volt bus in trains A and B shall not be connected. Computer and control board demultiplexers shall be powered by their own 48 and 1 5V dc power supplies that are isolated from the power supplies in the trains.
Specific Requirements Power and lnputlOutput Requirements of SSPS Equipment Characteristic Approximate Values Power Requirements Train A or B 120V ac, 60 Hz (Reference 7.5.7)
Control Board Demux 120V ac, 60 Hz Computer Demux 120V ac, 60 Hz Signal Inputs Instrument Comparators CV, or (11 8V ac, 60 Hz)
Field Contacts Contact closure to I 18V ac, 60 Hz Control Board Inputs Contact closure to logic ground Outputs UV Output +48V Normal, CV Trip Safeguards Outputs Relay Contacts Multiplex Signals Pulse trains: 0 and 15V levels Demultiplexed Signal ON: +48V; OFF: CV (to computer or interface relays in Control Board Demultiplexer Cabinet B. Control Rod Drive System Power Requirements The electrical requirements for the Control Rod Drive System can be found in N3-85-4003 (Reference 7.2.14).
2.2.10 Instrumentation and Control Requirements Instrumentation and controls shall be provided to monitor and maintain essential reactor facility operating variables such as neutron flux, primary coolant pressure, temperature, and control rod positions within prescribed ranges.
The non-neutronic process and containment instrumentation shall measure temperatures, pressure, flows, and levels in the Reactor Coolant System, steam systems, containment, and auxiliary systems. Process variables which are required on a continuous basis for the startup, power operation, and shutdown of the plant shall be monitored in a controlled access area. The quantity and types of process instrumentation provided shall be adequate for safe and orderly operation of all systems and processes over the full operating range of the plant.
Independent and redundant channels shall be combined through isolators in logic circuits.
Protection interlocks, initiation signals such as Safety Injection System, containment isolation, and turbine runback shall further assist in plant protection during operation.
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- 4. NORMAL OPERATION OF THE REACTOR TRIP SWITCHSEAR IS WITH THE REACTOR TRIP BREARERS RTA AND WOO IN SERVICE AND THE BYPASS BREAKERS BYA AND BYB WITHDRAWN.
THE BYPASS BREAKER FOR EACH TRAIN WILL BE CLOSED ONLY WREN THE RESPECTIVE REACTOW TRIP BREAKER IS TO BE TESTED, AND DALY ONE BYPASS BREAKER MAY BE CLOSED AT ONE TIME.
IF BOTH BVPASS BREAKERS ARE CLOSED AT ONE B TIME, EACH WILL TRIP THE OTHER, RESULTINO -B RTA IV CONTACTS IN A REACTOR TRIP. AT THE SAME TIME THE 52b 55P5 WILL TRIP ALL FOUR BREAKERS THROUGH RTA THE UNDERAOLTAOE COILS, PROAIDING A TTB31 TURBINE TRIP BUS B REDUNDANT REACTOR TRIP, o (1 4SW600 47 2) S. THE UNDERVOLTAOE COIL FOR EACH BYPASS BTUI BREAKER IS CONTROLLED FROM THE OPPOSITE lSDBDMAKE TRAIN OF TOE CONTROL CIRCUIT FOR THAT BREAKER.
A. BREAHER DISCONNECT PIN NUMBERS INSIDE A 104 CIRCLE ARE ON A SPECIAL CONNECTOR MOUNTED INSIDE THE BREAKER COMPARTMENT, RELAY 04A (8KW BYMI 7. FOR 000ERAL NOTES. INCLUDING TECHNICAL INFORMATION
[FU_SS_LliB/RTAN. AWDUT CIRCUIT DESION, SEE ORAWINO 1-WSW600-Dl,
- 8. FOR IWPUTS TO THE PLANT COMPUTER, THE COMPUTER POINT ISESUIVALENT TO THE WIRE NUMBER WITHOUT THE OR RELAY BOA (8KW BVUI 1BN OASEE CKT BELUW 1
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3-OT-SYS099A Revision 9 Page 4of47 PROGRAM Watts Bar Operator Training II. COURSES A. License Training B. Non-License Training III. TITLE Reactor Protection System (RPS)
IV. LENGTH OF LESSON A. License Training 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br />
- 1. Non-License Training 6 hours6.944444e-5 days <br />0.00167 hours <br />9.920635e-6 weeks <br />2.283e-6 months <br /> V. TRAINING OBJECTIVES 0 0<
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- 1. Explain the purpose of the Reactor Protection System.
- 2. Sketch a basic drawing of the Solid State Protection System.
- 3. Describe the actions that take place when a reactor trip is generated at X X X 100% power.
- 4. Identify the functions which rely on ESFAS for initiation.
x x x x Explain how the fire pumps would be affected by an SI signal.
6 Briefly describe the inputs to the SSPS.
Deleted.
x x x x 8 Briefly discuss the input relays, Logic Section and Output Section of the SSPS.
9 Explain how the two trains of SSPS are interconnected.
10 Describe the two ways by which the SSPS opens the Reactor Trip breakers.
11 Describe the four basic outputs of the SSPS.
12 Explain the purpose of the reactor trip bypass breakers and how their use is made fail safe.
3-OT-SYSO99A Revision 9 Page 5of47 0 0 D 0 I-0:: U) (I) 13 Describe the causes of General Warning on SSPS 14 Identify where General Warning indications can be found.
15 Identify the SSPS equipment which can be tested.
16 Describe operator actions prior to allowing testing of SSPS train.
17 Identify the Reactor trips and give setpoints and list logic required for
. the Reactor trips.
18 Given the condition/status of the Reactor Protection system/component and the appropriate sections of Tech Specs, determine if operability requirements are met and what actions, if any, are required.
x 19 Deleted x x x 20 Deleted x x x x 21 Deleted x
WBN 10-2011 NRC RO Exam As Submitted 811512011
- 39. 013 K4.19 039 Given the following:
- Unit I has been shutdown for a refueling outage.
- GO-6, Unit Shutdown from Hot Standby to Cold Shutdown, is in progress.
- The lowest RCS Tcold temperature and pressure trend is:
Time Temp Pressure 0500 349°F 395 psig 0530 337°F 380 psig 0600 324°F 345 psig 0630 302°F 340 psig 0700 280°F 340 psig 0730 257°F 340 psig 0800 235°F 340 psig 0830 214°F 340 psig 0900 199°F 330 psig 0930 185°F 330 psig Which ONE of the following is the earliest of the identified times that one of the Centrifugal Charging Pumps is required to be tagged with its breaker racked down and the reason for the requirement?
Time Reason A. 0600 to be in compliance with TR 3.1.3 Charging Pump, Shutdown.
B 0600 to be in compliance with LCO 3.4.12 Cold Overpressure Mitigation System.
C. 0900 to be in compliance with TR 3.1.3 Charging Pump, Shutdown.
D. 0900 to be in compliance with LCO 3.4.12 Cold Overpressure Mitigation System.
Page 106
WBN 10-2011 NRC RO Exam As Submitted 811512011 DIS TRACTOR ANAL YSIS:
A. lncorrect Plausible because 0600 is the correct time and because TR-3. 1.3 does address having one Centrifugal Charging Pump but it is not to limit the number to one pump. It is to ensure there is at least one pump operable.
B. Correct, One of the Centrifugal Charging Pumps is required to be made inoperable and tagged with a Hold Order prior to the lowest Tcold dropping below 325°F (which happens at 0600) and the reason is to be in compliance with the COMs Tech Spec in order to prevent over-pressurizing the RCS.
C. Incorrect, Plausible because there is a four hour allowance to make the pump inoperable after entering Mode 4 and the four hour window does expire at 0900; but the 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> is only applicable if the lowest Tcold is maintained at 325°F or higher.
Also plausible because TR-3. 1.3 does address having one Centrifugal Charging Pump but it is not to limit the number to one pump. It is to ensure there is at least one pump operable.
D. Incorrect, Plausible because there is a four hour allowance to make the pump inoperable after entering Mode 4 and the four hour window does expire at 0900; but the 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> is only applicable if the lowest Tcold is maintained at 325°F or higher.
Also plausible because the reason being to comply with the COMs Tech Spec in order to prevent over-pressurizing the RCS is correct.
Question Number: 39 Tier: 2 Group: 1 K/A: 013 K4.19 Engineered Safety Features Actuation System (ESFAS)
Knowledge of ESFAS design feature(s) and/or interlock(s) which provide for the following:
Reason for opening breaker on high-head injection pump Importance Rating: 3.0* / 3*4*
10 CFR Part 55: 41.7 IOCFR55.43.b: Not applicable K/A Match: K/A is matched because the question requires knowledge of the why one high head injection pump is required to have its breaker open and placed in a non-operating position.
Technical
Reference:
GO-6, Unit Shutdown From Hot Standby To Cold Shutdown, Revision 0047 Page 107
WBN 10-2011 NRC RO Exam As Submitted 8115/2011 Technical
Reference:
GO-6, Unit Shutdown From Hot Standby To Cold Shutdown, Revision 0047 Tech Spec LCO 3.4.12, Cold Overpressure Mitigation System, Amendment 55 Tech Requirement TR-3.1 .3, Charging Pump, Shutdown, Revision 38 Proposed references None to be provided:
Learning Objective: 3-OT-G00600
- 3. Discuss the major steps for taking the unit from Hot Standby to Cold Shutdown per GO-6.
Cognitive Level:
Higher X Lower Question Source:
New Modified Bank X Bank Question History: WBN bank question G00600.03 012 modified for the WBN 10/2011 NRC exam.
Comments:
Page 108
WBN Unit Shutdown From Hot Standby To GO-6 Unit I Cold Shutdown Rev. 0047 Page 36 of 90 Date________ INITIALS 5.4 Unit Cooldown to Between 330 and 340°F (continued)
CAUTION In Mode 4, at least two RCPs shall be in operation when the Rod Control System is capable of rod withdrawal, and at least one RCP or RHR Pump in operation when Rod Control System is NOT capable of rod withdrawal (TS 3.4.6).[c.3]
[10] WHEN RCS temperature reaches 350°F, PERFORM the following:
[10.1] LOG Mode 4 entry in the Operators Narrative Log.
[10.2] ANNOUNCE entry into Mode 4 using Plant P/A system.
CAUTION In Mode 4, 5 or 6 with the Reactor Vessel head on, the Cold Overpressure System (COPS) shall be operable with a maximum of one Charging Pump and no SI Pumps capable of injecting into the RCS, and the accumulators isolated (T.S. 3.4.12).
[10.3] WITHIN 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> after entering MODE 4 from MODE 3, AND before the temperature of one or more RCS CL be.. 4 dropping below 325°F, THEN PERFORM the following:
[10.3.1] PLACE ONE CCP handswitch in PULL-TO-LOCK (N!A pump to remain in service):
PERF NOMENCLATURE POSITION UNID INITIALS COP A-A(ECCS) P-T-L 1-HS-62-108A CCP B-B (ECCS) P-T-L 1-HS-62-104A
WBN Unit Shutdown From Hot Standby To GO-6 Unit I Cold Shutdown Rev. 0047
. Page 37 of 90 Date________ INITIALS 5.4 Unit Cooldown to Between 330 and 340°F (continued)
[10.3.2] PLACE both SI Pumps handswitches in PULL-TO-LOCK:
PERF NOMENCLATU RE POSITION UNtO INITIALS SI PMP A (ECCS) P-T-L 1-HS-63-1OA SI PMP B (ECCS) P-T-L 1-HS-63-15A
[10.3.3] ISSUE Hold Order on SI Pumps and disabled CCP.
[10.3.4] IF only one PORV is available for purposes of complying with LCO 3.4.12, THEN ENSURE RHR suction relief valve is available to serve as the second relief valve (in addition to the PORV) to meet LCO 3.4.12 (COMS).
[10.4] DISABLE alarm windows 85F and 124E for RVLIS USING SOI-55.01 in accordance with OPDP-4.
[10.5] ENSURE Instrument Maintenance (IM) PERFORMS the following within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after the unit has been 350°F or less (N/A if completed in last 31 days):
A. 1-51-68-1 92 COMPLETE.
B. 1-51-68-1 93 COMPLETE.
COMS 3.4.12 34 REACTOR COOLANT SYSTEM (RCS) 3.4.12 Cold Overpressure Mitigation System (COMS)
LCO 3.4.12 A COMS System shall be OPERABLE with a maximum of one charging pump and no safety injection pump capable of injecting into the RCS and the accumulators isolated and either a or b below.
- a. Two RCS relief valves, as follows:
- 1. Two power operated relief valves (PORV5) with lift settings within the limits specified in the PTLR, or
- 2. One PORV with a lift setting within the limits specified in the PTLR and the RHR suction relief valve with a setpoint 436.5 psig and 463.5 psig.
NOTES
- 1. Two charging pumps may be made capable of injecting for less than or equal to one hour for pump swap operations.
- 2. Accumulator may be unisolated when accumulator pressure is less than the maximum RCS Pressure for the existing RCS cold leg temperature allowed by the PIT limit curves provided in the PTLR.
APPLICABILITY: MODES 4 and 5, MODE 6 when the reactor vessel head is on.
Watts Bar-Unit 1 3.4-25 Amendment 14, 55
COMS 3.4.12 ACTIONS
- NOTE-LCO 3.O.4.b is not applicable when entering MODE 4.
CONDITION REQUIRED ACTION COMPLETION TIME A. One or more safety A.1 Initiate action to verify no Immediately injection pumps capable of safety injection pumps are injecting into the RCS. capable of injecting into the RCS.
B. Two or more charging B.1 Initiate action to verify a Immediately pumps capable of injecting maximum of one charging into the RCS. pump is capable of injecting into the RCS.
C. An accumulator not C.1 Isolate affected 1 hour1.157407e-5 days <br />2.777778e-4 hours <br />1.653439e-6 weeks <br />3.805e-7 months <br /> isolated when the accumulator.
accumulator pressure is greater than or equal to the maximum RCS pressure for existing cold leg temperature allowed in the PTLR.
(continued)
Watts Bar-Unit 1 3.4-26 Amendment 55
COMS 3.4.12 ACTIONS (continued)
CONDITION REQUIRED ACTION COMPLETION TIME D. Required Action and D.1 Increase RCS cold leg 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> associated Completion temperature to> 350°F.
Time of Condition C not met. OR D.2 Depressurize affected 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> accumulator to less than the maximum RCS pressure for existing cold leg temperature allowed_in_the_PTLR.
E. One required RCS relief E.1 Restore required RCS relief 7 days valve inoperable in valve to OPERABLE status.
MODE 4.
F. One required RCS relief F.1 Restore required RCS relief 24 hours2.777778e-4 days <br />0.00667 hours <br />3.968254e-5 weeks <br />9.132e-6 months <br /> valve inoperable in valve to OPERABLE status.
MODE5or6.
G. Two required RCS relief G.1 Depressurize RCS and 8 hours9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> valves inoperable, establish RCS vent.
OR Required Action and associated Completion Time of Condition A, B, D, E, or F not met.
OR COMS inoperable for any reason other than Condition A, B, C, D, E, or F.
Watts Bar-Unit 1 3.4-27
COMS 3.4.12 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.4.12.1 Verify no safety injection pumps are capable of Within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> after injecting into the RCS. entering MODE 4 from MODE 3 prior to the temperature of one or more RCS cold legs decreasing below 325°F.
AND 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> thereafter SR 3.4.12.2 Verify a maximum of one charging pump is capable Within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> after of injecting into the RCS. entering MODE 4 from MODE 3 prior to the temperature of one or more RCS cold legs decreasing below 325°F.
AND 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> thereafter SR 3.4.12.3 Verify each accumulator is isolated. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> (continued)
Watts Bar-Unit 1 3.4-28
COMS 3.4.12 SURVEILLANCE_REQUIREMENTS_(continued)
SURVEILLANCE FREQUENCY SR 3.4.12.4 NOTE Only required to be performed when complying with LCO 3.4.12.b.
Verify RCS vent open. 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> for unlocked open vent paths AND 31 days for locked open vent paths SR 3.4.12.5 Verify PORV block valve is open for each required 72 hours8.333333e-4 days <br />0.02 hours <br />1.190476e-4 weeks <br />2.7396e-5 months <br /> PORV.
SR 3.4.12.6 Verify both RHR suction isolation valves are 31 days locked open with operator power removed for the required RHR suction relief valve.
SR 3.4.12.7 NOTE Required to be met within 12 hours1.388889e-4 days <br />0.00333 hours <br />1.984127e-5 weeks <br />4.566e-6 months <br /> after decreasing RCS cold leg temperature to 350°F.
Perform a COT on each required PORV, excluding 31 days actuation.
SR 3.4.12.8 Perform CHANNEL CALIBRATION for each 18 months required PORV actuation channel.
Watts Bar-Unit 1 3.4-29
Charging Pump, Shutdown TR 3.1.3 TR 3.1 REACTIVITY CONTROL SYSTEMS TR 3.1.3 Charging Pump, Shutdown TR 3.1.3 One charging pump in the boron injection flow path required by TR 3.1.1 shall be OPERABLE and capable of being powered from an OPERABLE emergency power source.
APPLICABILITY: MODES 4, 5, and 6.
For Mode 4, Technical Specification LCO 3.O.4.b is not applicable to ECCS high head (centrifugal charging) subsystem.
ACTIONS CONDITION REQUIRED ACTION COMPLETION TIME A. Required charging pump A.1 Suspend CORE ALTERATIONS. Immediately inoperable.
AND OR A.2 Suspend positive reactivity Immediately Required charging pump not additions.
capable of being powered by an OPERABLE emergency power source.
TECHNICAL SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY TSR 3.1.3.1 Verify required charging pumps developed head at the In accordance with test flow point is the required developed head. Inservice Testing Program Watts Bar-Unit 1 3.1-5 Revision 38 Technical Requirements 11/29/06
G00600.03 012 t:cAd::.
Given the following plant conditions;
- The Unit is being cooled down in preparation for a refueling outage per GO-6, Unit Shutdown From Hot Standby To Cold Shutdown.
Which of the following is when GO-6 will direct both SI pump hand switches be placed in Pull to Lock, and the associated breakers tagged?
a Before any RCS Cold Leg temperature drops below 325°F.
- b. After RCS Tavg drops below 325° F.
- c. Within 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> after RCS temperature reaches 325°F.
- d. Before any RCS Cold Leg temperature drops below 350° F.
The correct answer is A
I j4I GO-6, PLANT SHUTDOWN FROM HOT STANDBY TO COLD SHUTDOWN 3-OT-G00600 Revision 4 Page 4 of 83 I. PROGRAM Watts Bar Operator Training II. COURSE License Training Non-License Training III. TITLE GO-6, Unit Shutdown From Hot Standby to Cold Shutdown IV. LENGTH OF LESSON License Training 3 Hours Non-License Training 3 Hours V. TRAINING OBJECTIVES AR S S U OR T 0 0 A X X X 1. Explain the reason for each Precaution and Limitation listed in GO-6.
X X X 2. Briefly state the reason for borating the Reactor Coolant System (RCS) prior to cooldown. State the limits for the Reactor Coolant System /Pressurizer (PZR) ACB and explain the preferred method for equalizing the RCS/PZR CB.
X X X 3. Discuss the major steps for taking the unit from Hot Standby to Cold Shutdown per GO-6.
X X X 4. State the precautions and operating requirements for the Reactor Coolant Pumps (RCP5) when performing a cooldown to Cold Shutdown per GO-6.
X X X 5. Describe the manual block and automatic reset of the Low PZR Pressure SI at <1970 (P-il).
I 1!hA GO-6, PLANT SHUTDOWN FROM HOT STANDBY TO COLD SHUTDOWN 3-OT-G00600 Revision 4 Page 5 of 83 V. TRAINING OBJECTIVES (Continued)
AR S S U OR T 0 0 A X X X 6. Identify the cooldownlheatup limits for the RCS and PZR, and given plant conditions, use the cooldown, heatup, and pressure limitations curves to determine that the plant is operating within limits.
X X X 7. State the limit and basis on z\T between the Pressurizer Spray Nozzle and fluid.
X X X 8. State what conditions must exist in order to place Residual Heat Removal (RHR) in service during cooldown per GO-6.
X X X 9. Describe the precautions and basis on solid water Residual Heat Removal operations.
X X X 10. Discuss the operation of 1-PCV-62-81 to maintain RCS pressure and Letdown flow when in a solid water condition.
VI. TRAINING AIDS A. Marker Board and Markers B MultimedialOverhead projector(s)
VII. MATERIALS A. Attachments Attachment 1 - G0-6, Unit Shutdown From Hot Standby To Cold Shutdown Attachment 2 - [INPO SOER 94-2, Boron Dilution Events in PWRs.j Attachment 3 S1-68-44, RCS Pressure/Temperature Limits Attachment 4 - WBN PERs 77176, 77699, 79910
WBN 10-2011 NRC RO Exam As Submitted 8/1512011
- 40. 022 K4.05 040 Given the following:
- Unit I was operating at 100% power when a design basis LOCA occurred.
Which ONE of the following identifies systems directly providing Containment Cooling during the first minute following the Phase B containment isolation?
Ak Containment Spray and Ice Condenser B. Air Return Fans and Containment Spray C. Containment Ventilation System and Ice Condenser D. Air Return Fans and Containment Ventilation System DISTRACTOR ANAL YSIS:
A. Correct, both the containment spray and the ice condenser will be pro viding containment cooling during the first minute after a Phase B isolation resulting from a design basis LOCA. Containment Spray starts at the Phase B setpoint of 2.8 psid and the ice doors open due to differential pressure between upper and lower containment.
B. lncorrect Plausible because the containment spray pro viding cooling during the first minute is correct and while the Air Return Fans do provide cooling during a design basis LOCA by forcing air recirculation between upper and lower containment, they do not start until 9 minutes after the accident.
C. Incorrect, Plausible because while the containment ventilation systems do cool the containment during normal operations, they are tripped during a design basis LOCA and because the Ice Condenser providing cooling during the first minute is correct.
D. lncorrect, Plausible because while the Air Return Fans do provide cooling during a design basis LOCA by forcing air recirculation between upper and lower containment they do not start until 9 minutes after the accident and the containment ventilation systems do cool the containment during normal operations, but are tripped during a design basis LOCA.
Question Number: 40 Tier: 2 Group: 1 KIA: 022 K4.05 Page 109
WBN 10-2011 NRC RO Exam As Submitted 8/1512011 K/A: 022 K4.05 Containment Cooling System (CCS)
Knowledge of CCS design feature(s) and/or interlock(s) which provide for the following:
Containment cooling after LOCA destroys ventilation ducts Importance Rating: 2.6*! 2.7 10 CFR Part 55: 41.7 IOCFR55.43.b: Not applicable K/A Match: K/A is matched because a design basis LOCA could damage the ventilation duct work in lower containment and the question requires knowledge of the design features (systems) that would provide containment cooling immediately following the accident initiation.
Technical
Reference:
N3-3ORB-4002, Reactor Building Ventilation System, Revision 0022 N3-61-4001, Ice Condenser System, Revision 0018 WBN FSAR Amendment 8 Proposed references None to be provided:
Learning Objective: 3-OT-SYSO61A
- 1. State the design basis of the Ice Condenser System in accordance with FSAR section 6.7.
- 2. State the function of the Ice Condenser System in accordance with the system description.
3-OT-SYSO72A
- 01. Explain the design basis of the Containment Spray System in accordance with FSAR section 6.2.2.
Cognitive Level:
Higher Lower X Question Source:
New Modified Bank X Bank Question History: Surry bank question used on the 2003 exam modified for use on WBN 10/2011 exam.
Comments:
Page 110
WBN System REACTOR BUILDING VENTILATION WBN-SDD-N3-3ORB-4002 Description SYSTEM Rev. 0022 Document Page 47 of 97 3.1.2 Containment Air Cooling System (CACS) (continued)
Standby CRDM coolers may be operated to supplement lower compartment cooling. In this case, a damper downstream of the CRDM will be closed and a damper allowing lower compartment air to enter the CRDM cooler will be opened. Normally the dampers are in the opposite position.
The UCC system includes four fan-coil units located in the upper compartment at El 801.69.
Each unit consists of a plenum, three air cooling coils, vaneaxial fan, instruments and controls. (See Ref. 7.1.3)
The upper containment air is recirculated and cooled during normal reactor operation. The system is designed for three of the four UCCs to operate with one on standby. (See Ref.
7.1.3)
Thermocouples (considered part of the ERCW system), sense return air temperature and provide input to the temperature indicating controllers to modulate valves in the ERCW lines of each cooler. Coolers ERCW flow is controlled to maintain the air temperatures below 120°F in the lower compartment and 110°F in the upper compartment.
The instrument room cooling system consists of two 100% capacity air conditioning systems. Each system includes a serviceable, hermetically packaged water chilling unit and chilled water circulating pump in the auxiliary building penetration room El 692, a fan-coil unit with supply ductwork located in the instrument room, chilled water piping and circulating pump with containment isolation valves, instruments, and controls (for details see 3.2.11).
The minimum required wall thicknesses for the chilled water piping are established in Ref.
7.4.7. This calculation accounts for corrosion/erosion and manufacturing tolerances.
Piping inside and outside containment has been evaluated for breaks and no requirements for leak detection in chilled water piping have been identified (Ref. 7.4.40).
Each chilled water penetration through containment is provided with two isolation globe valves, one located inside and one outside containment. These valves are pneumatic-cylinder operated and are designed to close fail safe within time limits specified in Ref. 7.2.4.
3.1.3 Containment Air Return System The containment air return system includes two 100% capacity fans, located in equipment spaces outside of the crane wall, each of which exhaust air from individual ductwork and a common hydrogen collection header. The fans exhaust air from the upper compartment into the accumulator rooms in the lower compartment.
The air return fans are designed to start automatically after 9+/-1 minutes following a Phase B containment isolation signal (Ref. 7.4.42). Each fan is a direct-drive vaneaxial type with a design capacity of 41,690 cfm (Ref. 7.1.3).
- WBN System REACTOR BUILDING VENTILATION WBN-SDD-N3-3ORB-4002 Description SYSTEM Rev. 0022
. Document Page 48 of 97 3.1.3 Containment Air Return System (continued)
Both fans can be started manually, or automatically upon receiving the containment isolation signal, drawing air from the containment dome, from the reactor cavities, and from the ten dead-ended (pocketed) spaces in containment where there is potential for the accumulation of hydrogen. The ten dead-ended spaces are the four steam generator enclosures, the pressurizer enclosure, the four accumulator spaces and the instrument room. Each fan will mix 1,690 cfm (Ref. 7.1.3) from the enclosed areas in the lower compartment to the general lower compartment atmosphere to prevent excessive localized hydrogen build-up following a MSLB or LOCA.
For hydrogen concentration limits inside containment see Ref. 7.2.17.
Air recirculated by the fans will flow into the lower compartment through the annular equipment areas and ports provided for pressure equalization. The air, along with any steam produced by the accident will leave the lower compartment through the ice condenser doors where the steam will be condensed for as long as sufficient ice remains.
The air return system also includes heavy-duty backdraft dampers to prevent back flow from the lower compartment to the upper compartment under a differential pressure of 15 psig (Ref. 7.4.43). The dampers are counterbalanced to open when the differential pressure across the fan is such that flow from the upper to the lower compartment is assured. The dampers are normally closed (with no airflow). (See Ref. 7.2.10 for details.)
Ductwork associated with the fans consists of hydrogen collectors from the reactor cavity, the containment dome, shared collection headers from the lower compartment, the pressurizer compartment, and the steam generator compartments.
3.1.4 Containment Vent System The containment venting, for continuous pressure relief, is performed during modes 1-5, by opening the containment isolation (Cl) valves FCV-30-40 and -37. This allows continuous venting of containment air into the Annulus through one of the Containment Vent Air Cleanup Units (CVACU)s, which are equipped with HEPA and charcoal filters. The airflow from containment into the Annulus is provided by the motive force of the differential pressure between the containment and the Annulus. This air mixes with the Annulus atmosphere before the AVC fan discharges it into the AB exhaust stack via the suction-side duct of the AB FHA exhaust fans. As an alternate to using the normal vent pathway, for containment pressure relief, either the pair of lower compartment purge lines (one supply and one exhaust), or one of the two pairs of upper compartment purge lines (one supply and one exhaust) may be used. The use of these alternate lines may require re-balancing of the supply duct airflow, as needed, to preclude a containment pressure rise. When an upper, or the lower, compartment purge line is used, the Containment Vent System must be isolated.
The Containment Vent System shall be isolated, during mode 6, by closing the valves FCV-30-40 and FCV-30-37 (Refer to subSection 4.20).
3.2 Component Description 3.2.1 Major Component Description Note: The following is vendor data which describe the performance characteristics for
WBN System REACTOR BUILDING VENTILATION WBN-SDD-N3-3ORB-4002 Description SYSTEM Rev. 0022 Document Page 49 of 97 3.2.1 Major Component Description (continued) major system components. For more detailed information and component requirements, the appropriate contract should be referenced. The information included in this section shall be updated upon any modification, addition, or replacement of existing equipment. The data represent the manufacturers rated capacities and not to be construed as required design values. Refer to Section 3.1 and Table 9.6 for design values.
A. Purge Supply Fans TVA Contract No. - 76K35-83246-1 Manufacturer - H. K. Porter Company, Incorporated Capacity - 14,000 cfm at 9.5 Static Pressure Type - Belt-Driven Centrifugal Motor - 50 hp Seismic - Category I B. Purge Exhaust Fans TVA Contract No. - 76K35-83246-1 Manufacturer - H. K. Porter Company, Incorporated Capacity - 14,000 cfm at 10.75 Static Pressure Type - Belt-Driven Centrifugal Motor - SOhp Seismic - Category I C. Purge Filter Assembly TVA Contract No. - 74C37-83103 Manufacturer - Cryenco, Division of CTI Prefilter Section - 40% Efficiency, NBS Dust Spot Method 0.2 Pressure Drop; Functional at temperatures up to 500°F, withstand gamma dose of 109 rads High-Efficiency Filters - 99.97% Efficiency. 0.30-Micron Hot DOP Test, 1.0 Pressure Drop Carbon Absorber Section - 99.95% Efficiency, Removal of Elemental Iodine; 1.0 Pressure Drop; Ignition temperature 620°F; withstand gamma dose of 109 rads ACU Pressure Drop - 2.2 clean, 4.7 dirty (Ref. 7.4.14)
Air Flow Rate - 14,000 cfm Seismic - Category I D. Butterfly Isolation Valves TVA Contract No. - 76K51-83264-1 Manufacturer - Posi-Seal International, Incorporated
NPG System ICE CONDENSER SYSTEM N3-61 -4001 Description Rev. 0018 Document Page 20 of 90 1.0
SUMMARY
The Ice Condenser System (ICS) is designed to absorb thermal energy released in the event of a loss-of-coolant accident (LOCA) or a high energy line break (HELB), for the purpose of limiting the peak pressure in the containment (CNTMT). The ICS will limit CNTMT pressure to below its design pressure for all pipe break sizes up to and including a double-ended severance
. A sodium tetraborate solution produced by ice-melt helps absorb 1
and retain iodine released during an accident and serves as neutron absorber and a heat transfer medium for cooling of the reactor core following the postulated accident. In the event of LOCA or HELB, the ice-melt solution serves as a heat sink for lower CNTMT as it breaks into droplets during the free fall from the ICS floor drain to the sump. Thus, the ICS plays no role in the normal operation of the plant, but serves only to mitigate the consequences of a LOCA or HELB.
The ICS is designed to provide a flow passage between the lower compartment holding the reactor coolant system (RCS) and the upper CNTMT compartment during accident conditions, and to act as a static, insulated cold storage compartment during normal operation.
It consists of three parts: lower plenum, ice bed, and upper plenum (see Figure 1). The lower plenum consists of lower inlet doors which swing in during a LOCA or HELB to allow steam to enter the ice condenser, the ice condenser floor, the lower support structure, and turning vanes which change the direction of the steam 9O to direct it upward to the ice bed.
The ice bed is a mass of sodium tetraborate ice stored in cylindrical ice baskets located between the lower and upper plenums, and over a 3QQ0 arc between the CNTMT vessel wall and crane wall. Steam flows through and is condensed on the ice bed.
The upper plenum consists of both intermediate and top deck doors, both of which open in a LOCA or HELB. Also located in the upper plenum are the air handling units (AHU5) which keep the ice condenser area cooled.
Auxiliary subsystems are provided to make and load borated ice for initial inventory and subsequent maintenance, and to provide refrigeration to remove heat associated with the various functions, such as the making, conveying, and storage of ice. Figure 2 shows a simplified flow diagram of the system, from initial filling of the system with the glycol to the deposition of the ice in the ice baskets.
The system description is based on general information provided by Ref. 7.1.1 through 7.1.15, 7.5.4 through 7.5.11, and 7.2.20.
2.0 DESIGN CRITERIA 2.1 Functions 2.1.1 Safety Functions A. Design Basis Events (DBE5)
The ICS shall be required to mitigate the DBEs defined below and in WB-DC-40-64 (Ref. 7.2.18)
WBNP-6 6.2 CONTAINMENT SYSTEMS 6.2.1 Containment Functional Design 6.2.1.1 Design Bases 6.2.1.1.1 Primary Containment Design Bases The containment is designed to assure that an acceptable upper limit of leakage of radioactive material is not exceeded under design basis accident conditions. For purposes of integrity, the containment may be considered as the containment vessel and containment isolation system.
This structure and system are directly relied upon to maintain containment integrity. The emergency gas treatment system and Reactor Building function to keep out-leakage minimal (the Reactor Building also serves as a protective structure), but are not factors in detenriining the design leak rate.
The containment is specifically designed to meet the intent of the applicable General Design Criteria listed in Section 3.1. This section, Chapter 3, and other portions of Chapter 6 present information showing conformance of design of the containment and related systems to these criteria.
The ice condenser is designed to limit the containment pressure below the design pressure for all reactor coolant pipe break sizes up to and including a double-ended severance. Characterizing the performance of the ice condenser requires consideration of the rate of addition of mass and energy to the containment as well as the total amounts of mass and energy added. Analyses have shown that the accident which produces the highest blowdown rate into a condenser containment will result in the maximum containment pressure rise; that accident is the double-ended guillotine or split severance of a reactor coolant pipe. The design basis accident for containment analysis based on sensitivity studies is therefore the double-ended guillotine severance of a reactor coolant pipe at the reactor coolant pump suction. Post-blowdown energy releases can also be acconimodated without exceeding containment design pressure.
The functional design of the containment is based upon the following accident input source term assumptions and conditions:
- 1. The design basis blowdown energy of 346.3 x 106 Btu and mass of 549.7 x i0 3 lb put into the containment (See Section 6.2.1.3.6).
- 2. A core power of 3459 MWt (plus 0.6% allowance for calorimetric error) (See Section 6.2.1.3.6).
6.2.1-1
WBNP-1
- 3. The minimum engineered safety features are (i.e., the single failure criterion applied to each safety system) comprised of the following:
- a. The ice condenser which condenses steam generated during a LOCA, thereby limiting the pressure peak inside the contaimnent (see Section 6.7).
- b. The containment isolation system which closes those fluid penetrations not serving accident-consequence limiting purposes (see Section 6.2.4).
- c. The containment spray system which sprays cool water into the containment atmosphere, thereby limiting the pressure peak (particularly in the long term see Section 6.2.2).
- d. The emergency gas treatment system (EGTS) which produces a slightly negative pressure within the annulus, thereby precluding out-leakage and relieving the post-accident thernial expansion of air in the annulus (see Section 6.5.1).
- e. The air return fans which return air to the lower compartment (See Section 6.8).
Consideration is given to subcompartment differential pressure resulting from a design basis accident discussed in Sections 3.8.3.3, 6.2.1.3.9, and 6.2.1.3.4. If a design basis accident were to occur due to a pipe rupture in these relatively small volumes, the pressure would build up at a faster rate than in the containment, thus imposing a differential pressure across the wall of these structures.
Parameters affecting the assumed capability for post-accident pressure reduction are discussed in Section 6.2.1.3.3.
Three events that may result in an external pressure on the containment vessel have been considered:
- 1. Rupture of a process pipe where it passes through the annulus.
- 2. Inadvertent air return fan operation during normal operation.
- 3. Inadvertent containment spray system initiation during normal operation.
6.2.1-2
WBNP-3 The design of the guard pipe portion of hot penetrations is such that any process pipe leakage in the annulus is returned to the containment. All process piping which has potential for annulus pressurization upon rupture is routed through hot penetrations. Section 6.2.4 discusses hot penetrations.
Inadvertent air return fan operation during normal operation opens the ice condenser lower inlet doors, which in turn, results in sounding an alarm in the MCR.
The logic and control circuits of the containment spray system are such that inadvertent contaimnent spray would not take place with a single failure. The spray pump must start and the isolation valve must open before there can be any spray. In addition, the Watts Bar containment is so designed that even if an inadvertent spray occurs, containment integrity is preserved without the use of a vacuum relief.
The containment spray system is automatically actuated by a hi-hi containment pressure signal from the solid state protection system (SSPS). To prevent inadvertent automatic actuation, four comparator outputs, one from each protection set are processed through two coincidence gates.
Both coincidence gates are required to have at least two high inputs before the output relays, which actuate the containment spray system, are energized. Separate output relays are provided for the pump start logic and discharge valve open logic. Additional protection is provided by an interlock between the pump and discharge valve, which requires the pump to be running before the discharge valve will automatically open.
Section 3.8.2 describes the structural design of the containment vessel. The containment vessel is designed to withstand a net external pressure of 2.0 psi. The containment vessel is designed to withstand the maximum expected net external pressure in accordance with ASME Boiler and Pressure and Vessel Code Section III, paragraph NE-7l 16.
6.2.1.2 Primary Containment System Design The containment consists of a containment vessel and a separate Shield Building enclosing an annulus. The containment vessel is a freestanding, welded steel structure with a vertical cylinder, hemispherical dome, and a flat circular base. The Shield Building is a reinforced concrete structure similar in shape to the containment vessel. The design of these structures is described in Section 3.8.
6.2.1-3
WBNP-1 The design internal pressure for the containment is 13.5 psig, and the design temperature is 250°F. The design basis leakage rate is 0.25 weight percent/24 hr. The design methods to assure integrity of the containment internal structures and sub-compartments from accident pressure pulses are described in Section 3.8.
6.2.1.3 Design Evaluation 6.2.1.3.1 Primary Contaimnent Evaluation
- 1. The leaktightness aspect of the secondary containment is discussed in Section 6.2.3. The primary containment s leaktightness does not depend on the operation of any continuous t
monitoring or compressor system. The leak testing of the primary containment and its isolation system is discussed in Section 6.2.6.
- 2. The acceptance criteria for the leaktightness of the primary containment are such that at containment design pressure, there is a 25% margin between the acceptable maximum leakage rate and the maximum permissible leakage rate.
6.2.1.3.2 General Description of Containment Pressure Analysis The time history of conditions within an ice condenser containment during a postulated loss of coolant accident can be divided into two periods for calculation purposes:
- 1. The initial reactor coolant blowdown, which for the largest assumed pipe break occurs in approximately 10 seconds.
- 2. The post blowdown phase of the accident which begins following the blowdown and extends several hours after the start of the accident.
During the first few seconds of the blowdown period of the reactor coolant system, containment conditions are characterized by rapid pressure and temperature transients. It is during this period that the peak transient pressures, differential pressures, temperature and blowdown loads occur.
To calculate these transients a detailed spatial and short time increment analysis was necessary.
This analysis was performed with the Transient Mass Distribution (TMD) computer code with the calculation time of interest extending up to a few seconds following the accident initiation (See Section 6.2.1.3.4).
6.2.1-4
WBNP-O Physically, tests at the ice condenser Waltz Mill test facility have shown that the blowdown phase represents that period of time in which the lower compartment air and a portion of the ice condenser air are displaced and compressed into the upper compartment and the remainder of the ice condenser. The containment pressure at or near the end of blowdown is governed by this air compression process. The containment compression ratio calculation is described in Section 6.2.1.3.4.
Containment pressure during the post blowdown phase of the accident is calculated with the LOTIC code which models the containment structural heat sinks and containment safeguards systems.
6.2.1.3.3 Long-Term Containment Pressure Analysis Early in the ice condenser development program it was recognized that there was a need for modeling of long-term ice condenser containment perfonnance. It was realized that the model would have to have capabilities comparable to those of the dry containment (COCO) model.
These capabilities would permit the model to be used to solve problems of containment design and optimize the containment and safeguards systems. This has been accomplished in the development of the LOTIC code.
1 The model of the containment consists of five distinct control volumes; the upper compartment, the lower compartment, the portion of the ice bed from which the ice has melted, the portion of the ice bed containing unmelted ice, and the dead ended compartments. The ice condenser control volume with unmelted ice is further subdivided into six subcompartments to allow for maldistribution of break flow to the ice bed.
The conditions in these compartments are obtained as a function of time by the use of fundamental equations solved through numerical techniques. These equations are solved for three distinct phases in time. Each phase corresponds to a distinct physical characteristic of the problem. Each of these phases has a unique set of simp1ifing assumptions based on test results from the ice condenser test facility. These phases are the blowdown period, the depressurization period, and the long term.
The most significant simplification of the problem is the assumption that the total pressure in the containment is uniform. This assumption is justified by the fact that after the initial blowdown of the reactor coolant system, the remaining mass and energy released from this system into the containment are small and very slowly changing. The resulting flow rates between the control volumes will also be relatively small. These small flow rates then are unable to maintain significant pressure differences between the compartments.
6.2.1-5
I..022K4.05.1 I 3/14/2003 Exit Surry 1 ExamLevel IR Question IEI ord Search one of the following systems directly provides Containment Cooling during the first minute following a design basis LOCA?
Question Containment Spray System.
Answer:
1 Service Water System.
Distracter 1 Distracter 2 Containment Ventilation System.
Distracter JRecirc Spray flowing through at least 2 RSHXs.
Distracter Analysis:
Answer: IC. Correct the Containment Spray System cools and depressurizes containment during a DBLOCA.
Distracter 1 A. Incorrect, SW cools the RSHXs but containment is cooled by 45 degree RWST water from the Containment Spray System.
Distracter 2: lB. Incorrect, containment ventilation cools the containment during normal operations but not during a DBLOCA.
Distracter 3: D. Incorrect, The Recirc spray system aids in cooling the containment but it is designed to provide for core cooling after a DBLOCA.
c.
3-OT-SYSO6 1 A Revision 5 Page 4of62 PROGRAM Watts Bar Operator Training II. COURSES CERTI Fl CATI ON NOTP LICENSED OPERATOR REQUAL AUO REQUAL III. TITLE Ice Condenser System IV. LENGTH OF LESSON Certification 1 .5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> Non-Licensed Training 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> NOTP 2.0 HOURS LICENSED OPERATOR AND AUO REQUAL TIMES WILL BE DETERMINED WHEN OBJECTIVES ARE IDENTIFIED V. TRAINING OBJECTIVES 0 0 D
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- 1. State the design basis of the Ice Condenser System in accordance x with FSAR section 6.7.
- 2. State the function of the Ice Condenser System in accordance with the system description.
- 3. Describe the 1 1 components of the ice condenser structure and give a brief description of each.
- 4. Discuss the ice condenser drains, include how they are sealed and where they drain.
- 5. Sketch a profile of the ice condenser and indicate how steam flow will be directed from lower containment to upper containment.
- 6. Describe the ice condenser doors and state at what pressures they open.
- 7. Discuss which doors in the ice condenser have position indication.
3-OT-SYS06 1 A Revision 5 Page5of62 0 0 D 0 C) C,)
- 8. Describe the ice condenser instrumentation, as outlined in this lesson x plan, and give two locations where ice condenser temperatures can be read.
- 9. Describe how the ice condenser is cooled; include the temperature range and areas that have cooling coils.
- 10. Describe the glycol chiller; include power supply, logic and capacity.
11.Statetheglycolchilleroutlettemperature.
- 12. State the purpose of the glycol circulation system.
x x x
- 13. List and describe all the major components in the glycol system.
- 14. Discuss the normal arrangement of the 6 glycol pumps and chillers.
- 15. Describe the glycol pumps; include power supply, logic and capacity.
- 16. Describe the logic for the glycol containment isolation valves.
x x x 17. Given a loss of instrument air/control power, determine the effect on the following valve:
- a. FCV-61-194
- 18. Discuss what provisions have been made for glycol expansion after the x x glycol system is isolated from the containment.
- 19. Explain how glycol is added to the glycol system.
- 20. Describe how the glycol system and the ice system interface.
- 21. Explain how to place a glycol pump in service.
- 22. Discuss how to place a glycol chiller in service.
- 23. List the checks to be made on a glycol chiller that is in service.
3-OT-SYSO6 1 A Revision 5 Page 6 of 62
- 24. Regarding Technical Specifications and Technical Requirements for this system:
- a. Identify the conditions and required actions with completion time of one hour or less.
- b. Explain the Limiting Conditions for Operation, Applicability, and Bases.
- c. Given a status/set of plant conditions, apply the appropriate Technical Specifications and Technical Requirements.
- 25. Correctly locate control room controls and indications associated with the Ice Condenser System, including:
- a. Ice Condenser Lower Inlet Door Monitor
- b. Ice Bed Temperature Monitor
3-OT-SYSO6 1 A Revision 5 Page9of62 I INTRODUCTION Learning Goals
- 00. Demonstrate an understanding of lURES 1122 knowledges and abilities associated with the Ice Condenser System that are
- 1. Preview learning objectives.
rated s2.5 during Initial License Training r
and 2 3.0 during License Operator Requalification Training for the appropriate To develop the knowledge, skills and ability license position as identified in Appendix A.
C1 I. State the design basis of the Ice Condenser to operate the Ice Condenser System (ICS) in a U)
System in accordance with FSAR section 6.7. safe and efficient manner.
UI 2. State the function of the Ice Condenser System in accordance with the system description. 2. Discuss the purpose and scope of the ICS system
- 3. Describe the 11 components of the ice
-J condenser structure and give a brief lesson.
U) description of each.
- 3. Discuss the importance of the ICS system to plant NOTE: Objectives 21-23 operation.
should be addressed during review of operating procedures.
OBJECTIVE 2 Introduction Purpose and Function Discuss the functions of the Ice Condenser system (ICS).
The purpose of the
) Ice Condenser The purpose of the ICS is to absorb SstCS> to thermal energy released in the event of a DBE.
energy released in the event of a DBE
- The ice-melt solution serves as a heat sink for lower containment as it breaks into droplets during the free fall from the ICS floor drain to the into droplets during the free fall from the CS floor drain to the sump.
sum 0 ICS acts as a static, insulated cold storage compartment during normal ICS acts as a static, insulated cold storage operation, compartment during normal operation.
0)
III
-I co
3-OT-SYSO6 1 A Revision 5 Page 10 of 62 Safety Function Safety Function 4. Discuss the safety function provided by the ICS The Ice Condenser System absorbs thermal energy released in the event of:
system.
- Loss of Coolant Accident (LOCA)
A pipe break or spurious valve thing in the
- The Ice Condenser System absorbs reactor coolant system in excess of the makeup system capacity.
thermal energy released in the event of:
High Energy Line Break (HELB).
A pipe break of a high pressure or high
- Loss of Coolant Accident (LOCA) iii temperature system. including double-ended guillotine or split severance of a A pipe break or spurious valve lifting in the reactor coolant pipe.
reactor coolant system in excess of the makeup system capacity.
I High Energy Line Break (HELB).
A pipe break of a high pressure or high temperature system, including double-ended guillotine or split severance of a reactor doolant pipe.
- Containment Spray and ARES assist ICS in meeting its design safety function.
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OBJECTIVE I The ice condenser is designed to limit the containment pressure below the design pressure DesignB for all reactor coolant pipe break sizes up to and h The ice condenser is designed to limit including a double-ended severance.
the containment pressure below the design pressure for all reactor coolant
- Analyses have shown that double-ended pipe break sizes up to and including a double-ended severance.
guillotine or split severance of a reactor coolant 5- Analyses have shown that double-ended pipe accident produces the highest blow down rate co guillotine or split severance of a reactor into containment which will result in the maximum coolant pipe accident produces the highest blowdown rate into containment containment pressure rise.
which will result in the maximum containment pressure rise.
General Description The Ice Condenser consists of three parts: 1. Discuss the three main parts of the ice condenser.
lJnper Plenum S
- I Upper Plenum.
Intermediate Deck and Doors.
Ui I Top Deck and Doors.
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3-OT-SYSO72A Revision 9 Page6of33 PROGRAM A. Watts Bar Operator Training COURSES A. License Training B. NOTP C. License Requalification D. AUO Requalification III. TITLE A. Containment Spray System IV. IV. LENGTH OF LESSON A. License Training 2 Hour B. NOTP 4 Hours License Requalification and AUO Requalification times will be determined after objectives are identified.
V. TRAINING OBJECTIVES 0 0 D
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X X 01. Explain the design basis of the Containment Spray System in accordance with FSAR section 6.2.2.
X X 02. Draw a simplified diagram of the Containment Spray System showing major components, valves, and flow paths.
X X 03. List each place from which the Containment Spray System can take suction.
X X 04. Identify the systems with which the Containment Spray System interfaces.
X X 05. Describe the Containment Spray Pumps, include power supply, logic, capacity and type.
X X 06. Describe the auto start signals for the Containment Spray Pump room coolers.
X X
- 07. Describe the Containment Spray Heat Exchanger.
X 08. Describe the logic (interlocks) on the Containment Spray suction, discharge header, and containment sump valves.
X X 09. Identify the power supplies to the major valves of the Containment Spray System.
X X 10. Describe the auto operation of the Containment Spray mini-flow valves.
- 11. Deleted.
X X 12. Describe the auto action that must be verified after each Containment Spray Pump breaker operation.
3-OT-SYSO72A Revision 9 Page 7of33 0 0<
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X X X 13. Regarding Technical Specifications and Technical Requirements for this system:
- a. Identify the conditions and required actions with completion time of one hour or less.
- b. Explain the Limiting Conditions for Operation, Applicability, and Bases.
- c. Given a status/set of plant conditions, apply the appropriate Technical Specifications and Technical Requirements.
X X X X 14. Describe the in plant location of the following:
- a. Containment Spray Pumps
- b. Containment Spray Hxs
- d. Containment Spray Pumps RWST Suction
- e. Containment Spray Pumps Sump
- f. Containment Spray Pump Mini flow
- g. Containment Spray System Test Line Flow Indicator
- i. Containments two 14 inch Drain Lines Between Upper and Lower Containment X X X 15. Correctly locate all control room controls and indications associated with the Containment Spray System.
X X X 16. Given a set of plant conditions, determine the correct response of the Containment Spray System.
X X X 17.Deleted.
X X X X 18. Describe how corrosion is controlled in the Containment Spray system during lay-up.
X X X X 19. Identify the basis, requirements and interlocks required to place the RHR spray in service.
X X X 20. Explain Tech Spec bases for Containment Spray components and parameters governed by Tech Specs.
3-OT-SYSO72A Revision 9 33 I INTRODUCTION flIsnex1;r. Learning Goals OBJECTIVES
- 1. Explain the design basis of the Containment 1. Preview learning objectives.
Spray System in accordance with FSAR section 6.2.2.
- Brief statement to cue the instructor on the scope
- 2. Draw a simplified diagram of the Containment Spray System showing major of the objectives. Example as follows:
components, valves, and flow paths.
- 3. List each place from which the Containment
- To develop the knowledge, skills and ability to Spray System can take suction.
w 4. Identify the systems with which the operate the Containment Spray System (CSS)
Containment Spray System interfaces.
system in a safe and efficient manner.
-J NOTE: Objectives 14, 15 and 16 are global objectives that are covered throughout this lesson.
OBJECTIVE I Purpose I Function F.
PIFeoe 1. Discuss the functions of the purpose and function of LU
- 1. Helps maintain containment pressure below the design limit following a LOCA or a steam line the CSS.
break inside containment
-J 2, Removes heat from the containment sump
- Helps maintain containment pressure below the during recirculation mode.
C, design limit following a LOCA or a steam line break inside containment.
a Removes heat from the containment sump during recirculation mode.
Safety Function h Containment Heat Removal System (CSS and RHR Spray) 1. Discuss the Safety Function associated with the CS are safety related systems designed to operate only during an accident resulting system.
in containment pressure >2.81 PSID.
a Containment Heat Removal System (CSS and RHR Spray) are safety related systems designed CD to operate only during an accident resulting in Lii containment pressure >2.81 PSID.
-J U)
3-OT-SYSO72A Revision 9 Paqe 11 of 33 OBJECTIVE I Design Basis
- 1. Discuss the design basis of the CSS system.
e Dosignod to spray cool borated wator into the containmont atmosphere in the event of a LOCA I Designed to spray cool borated water into the or a steam line break inside Containment.
C) Assures containment pressure cannot containment atmosphere in the event of a LOCA UI exceed the containment shell design internal pressure of 13.5 PSIG nt 250F.
or a steam line break inside containment.
-J ye Affords protection for all piping sizes up to and including the double-ended rupture of
- Assures containment pressure cannot exceed ci) the largest pipe in the RCS. the containment shell design internal pressure ye Secomes the sole system to remove heat from containment after all ice in the ice of 13.5 PSIG at 250°F.
condenser has melted.
- Affords protection for all piping sizes up to and including the double-ended rupture of the largest pipe in the RCS.
- Becomes the sole system to remove heat from containment after all ice in the ice condenser has melted.
o General Description C There are to: ose crate tra ins of Containment Spray UI hae a:
iontainment, 1. Overview the basic function of the CSS system the 9 1 t
ron conditions that initiate a spray actuation and the Cl) .__
system response.
zmiifl S There are two separate trains of Containment Spray which are normally aligned to the RWST.
°°,
1 e
.u
- After a LOCA or steam line break inside
.: containment, the CSS automatically starts when containment pressure increases to 2.81 PSID.
., I The CSS Pumps deliver borated water from the rr RWST through their respective heat exchangers 5 Hp rtnment which are cooled by Essential Raw Cooling Water.
atmosphere throagh ring headers in the top of the oseeeer
- containment dome.
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WBN 10-2011 NRC RO Exam As Submitted 8115/2011
- 41. 025 A4.01 041 Given the following:
- Unit I is operating at 100% power when a LOCA occurs.
- A Safety Injection has been actuated.
- Containment pressure is 1.1 psig and slowly rising.
Which ONE of the following identifies the expected position of 1 -FCV-61 -110, GLYCOL COOLED FLOOR RETURN HEADER ISOL?
Ak CLOSED due to a containment isolation signal.
B. CLOSED due to an Auxiliary Building isolation signal.
C. OPEN unless the containment pressure rises to Hi-Hi setpoint.
D. OPEN unless Glycol Storage Tank level reaches Lo-Lo setpoint.
DIS TRA CTOR ANAL YSIS:
A. Correct because the valve should be closed due to the safety injection signal actuating a Phase A containment isolation which automatically closes the valve.
B. Incorrect, Plausible because an isolation signal generated from the safety injection signal did close the valve but it is the containment isolation not the Auxiliary Building isolation (both of which are generated when a safety Injection occurs) and the most of the glycol system is located in the Aux Building.
C. Incorrect, Plausible because as the containment pressure continues to rise a Phase B isolation will occur at 2.8 psig. This signal closes other valves. Also plausible because the current containment pressure is below the HI containment pressure setpoint (1.5 psig).
D. Incorrect, Plausible because there are valves that automatically close when the Glycol Expansion tank reaches a Lo-Lo level. (e.g. 1-FCV-61-193B).
Page 111
WBN 10-2011 NRC RO Exam As Submitted 8115/2011 Question Number: 41 Tier: 2 Group 1 K/A: 025 A4.O1 Ice Condenser System Ability to manually operate and/or monitor in the control room:
Ice condenser isolation valves Importance Rating: 3.0* / 2.7*
10 CFR Part 55: 41.7 / 45.5 to 45.8 IOCFR55.43.b: Not applicable KIA Match: K/A is matched because the question requires the ability to determine the expected position of a valve in the ice condenser glycol flow path during off-normal plant conditions.
Technical
Reference:
1-47W611-63-1 R13 1-47W611-61-2 R6 1-47W611-88-1 R24 1-47w611-30-6 R13 Proposed references None to be provided:
Learning Objective: 3-OT-SYSO61A
- 16. Describe the logic for the glycol containment isolation valves.
Cognitive Level:
Higher X Lower Question Source:
New X Modified Bank Bank Question History: New question for the WBN 10-2011 NRC exam Comments:
Page 112
3-OT-SYS06 1 A Revision 5 Page 4of62 PROGRAM Watts Bar Operator Training II. COURSES CERTI FICATION NOTP LICENSED OPERATOR REQUAL AUO REQUAL III. TITLE Ice Condenser System IV. LENGTH OF LESSON Certification 1 .5 hours5.787037e-5 days <br />0.00139 hours <br />8.267196e-6 weeks <br />1.9025e-6 months <br /> Non-Licensed Training 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br /> NOTP 2.0 HOURS LICENSED OPERATOR AND AUO REQUAL TIMES WILL BE DETERMINED WHEN OBJECTIVES ARE IDENTIFIED V. TRAINING OBJECTIVES 0 0<
DO I O (I) Cl)
- 1. State the design basis of the Ice Condenser System in accordance with FSAR section 6.7.
- 2. State the function of the Ice Condenser System in accordance with the system description
- 3. Describe the 1 1 components of the ice condenser structure and give a brief description of each.
- 4. Discuss the ice condenser drains, include how they are sealed and where they drain.
- 5. Sketch a profile of the ice condenser and indicate how steam flow will be directed from lower containment to upper containment.
- 6. Describe the ice condenser doors and state at what pressures they open.
- 7. Discuss which doors in the ice condenser have position indication.
3-OT-SYS06 1 A Revision 5 Page 5 of 62 0 0 D 0 I Cl) Cl,
- 8. Describe the ice condenser instrumentation, as outlined in this lesson plan, and give two locations where ice condenser temperatures can be
. read.
- 9. Describe how the ice condenser is cooled; include the temperature range and areas that have cooling coils.
10 Describe the glycol chiller include power supply logic and capacity 1 1 State the glycol chiller outlet temperature 12 State the purpose of the glycol circulation system
- 13. List and describe all the major components in the glycol system.
- 14. Discuss the normal arrangement of the 6 glycol pumps and chillers.
- 15. Describe the glycol pumps; include power supply, logic and capacity.
- 16. Describe the logic for the glycol containment isolation valves.
- 17. Given a loss of instrument air/control power, determine the effect on the following valve:
- a. FCV-61-194
- 18. Discuss what provisions have been made for glycol expansion after the glycol system is isolated from the containment.
- 19. Explain how glycol is added to the glycol system.
20 Describe how the glycol system and the ice system interface 21 Explain how to place a glycol pump in service
- 22. Discuss how to place a glycol chiller in service.
- 23. List the checks to be made on a glycol chiller that is in service.
x x
3-OT-SYSO6 1 A Revision 5 Page 6 of 62 0 0<
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- 24. Regarding Technical Specifications and Technical Requirements for this system:
- a. Identify the conditions and required actions with completion time x x x of one houror less.
- b. Explain the Limiting Conditions for Operation, Applicability, and Bases.
- c. Given a status/set of plant conditions, apply the appropriate Technical Specifications and Technical Requirements.
- 25. Correctly locate control room controls and indications associated with the Ice Condenser System, including:
xxx a. Ice Condenser Lower Inlet Door Monitor
- b. Ice Bed Temperature Monitor
WBN 10-2011 NRC RO Exam As Submitted 811512011
- 42. 026 A1.06 042 Which ONE of the following describes the auto start logic for the Containment Spray Pump room cooler?
A. ONLY auto start is when the Containment Spray pump starts.
B. ONLY auto start is when the room temperature increases to 95°F.
C. Will auto start when either the Containment Spray pump starts or the room temperature increases to 95°F.
D. Will auto start when room temperature increases to 95°F ONLY if the Containment Spray pump is running.
DISTRACTOR ANAL YSIS:
A. Incorrect, Plausible because the cooler does start when pump starts but also starts when room temp increases to 95°F.
B. Incorrect, Plausible because the cooler does start when room temp increases to 95°F but also starts on pump start.
C. Correct Logic for auto start of the containment spray pump room cooler is the pump starting or the room temperature increasIng to 95°F.
D. Incorrect, Plausible because the start of the pump and the temperature are starting conditions for the room cooler but it is either, not both. The logic is OR not AND.
Page 113
WBN 10-2011 NRC RO Exam As Submitted 8/1512011 Question Number: 42 Tier: 2 Group 1 K/A: 026 A1.06 Containment Spray System (CSS)
Ability to predict and/or monitor changes in parameters (to prevent exceeding design limits) associated with operating the CSS controls including:
Containment spray pump cooling Importance Rating: 2.7 / 3.0 10 CFR Part 55: 41.5 IOCFR55.43.b: Not applicable K!A Match: K/A is matched because the question requires the ability to predict the changes in Containment Spray Pump cooling associated with operating the CSS system and controls.
Technical
Reference:
1 -45W760-72-1 Ri 3 1-45W760-30-19 R9 Proposed references None to be provided:
Learning Objective: 3-OT-SYSO72A
- 06. Describe the auto start signals for the Containment Spray Pump room coolers.
Cognitive Level:
Higher Lower X Question Source:
New Modified Bank Bank X Question History: SQN bank question with the correct answer relocated.
Comments:
Page 114
5(LN (i\/I( (ftS71O,i 026 A1.06 043 Which ONE of the following describes the auto start logic for the Containment Spray room cooler?
A. Only auto starts when the associated pump starts.
B. Only auto start is on increasing room temperature at 95°F.
C. Only auto starts when room temperature increases to 95°F with the associated pump running.
D Only auto starts when associated pump starts OR when room temperature increases to 95° F.
3-OT-SYSO72A Revision 9 Page 6 of 33 PROGRAM A. Watts Bar Operator Training II. COURSES A. License Training B. NOTP C. License Requalification D. AUO Requalification III. TITLE A. Containment Spray System IV. IV. LENGTH OF LESSON A. License Training 2 Hour B. NOTP 4 Hours License Requalification and AUO Requalification times will be determined after objectives are identified.
V. TRAINING OBJECTIVES 0 0<
DO Q H L Cl) Cl)
X X X X 01. Explain the design basis of the Containment Spray System in accordance with FSAR section 6.2.2.
X X X 02. Draw a simplified diagram of the Containment Spray System showing major components, valves, and flow paths.
X X X 03. List each place from which the Containment Spray System can take suction.
X X X 04. Identify the systems with which the Containment Spray System interfaces.
X X X 05. Describe the Containment Spray Pumps, include power supply, logic, capacity and type.
X X X X 06. Describe the auto start signals for the Containment Spray Pump room coolers.
X X X X
- 07. Describe the Containment Spray Heat Exchanger.
X X X 08. Describe the logic (interlocks) on the Containment Spray suction, discharge header, and containment sump valves.
X X X X 09. Identify the power supplies to the major valves of the Containment Spray System.
X X X X 10. Describe the auto operation of the Containment Spray mini-flow valves.
- 11. Deleted.
X X X X 12. Describe the auto action that must be verified after each Containment Spray Pump breaker operation
3-OT-SYSO72A Revision 9 Page 7of33 0 0 D I C,) Cl)
X X X 13. Regarding Technical Specifications and Technical Requirements for this system:
- a. Identify the conditions and required actions with completion time of one hour or less.
- b. Explain the Limiting Conditions for Operation, Applicability, and Bases.
- c. Given a status/set of plant conditions, apply the appropriate Technical Specifications and Technical Requirements.
X X X X 14. Describe the in plant location of the following:
- a. Containment Spray Pumps
- b. Containment Spray Hxs
- d. Containment Spray Pumps RWST Suction
- e. Containment Spray Pumps Sump
- f. Containment Spray Pump Mini flow
- g. Containment Spray System Test Line Flow Indicator
- i. Containments two 14 inch Drain Lines Between Upper and Lower Containment X X X 15. Correctly locate all control room controls and indications associated with the Containment Spray System.
X X X 16. Given a set of plant conditions, determine the correct response of the Containment Spray System.
X X X 17.Deleted.
X X X X 18. Describe how corrosion is controlled in the Containment Spray system during lay-up.
X X X X 19. Identify the basis, requirements and interlocks required to place the RHR spray in service.
X X X 20. Explain Tech Spec bases for Containment Spray components and parameters governed by Tech Specs.
3-OT-SYSO72A Revision 9 PaQe l4of 33 OBJECTIVE 5 Containment Spray Pumps
- 1. Discuss the design parameters associated with the CD P 700 lIP otor-dricen single stage horizontal centrifugal pumps.
CS pumps.
B 700 HP motor-driven single stage horizontal P Pump capacity: 4000 gpnr 435TDH.
0- Pump oil real ecohasger is cooled by UI 0-Component Cooling Water.
PowerSopplins:
centrifugal pumps.
o Pump A: IA-A 1.0kV chuldown hccrd.
-J
- Pumpu:10.000kVnhutdnWnhocrd. I Pump capacity: 4000 gpm @435 TDH.
Cl)
B Pump oil heat exchanger is cooled by Component Cooling Water.
- Power Supplies:
B Pump A: lA-A 6.9kV shutdown board.
- Pump B: lB-B 6.9kV shutdown board.
OBJECTIVE 6 2. Describe the function and operation of the CS pump room coolers B Each CSS pump room has a room cooler located 0- Each CSS pump room has a room 000lor 0-located inside thu pomp room.
ERCW proordes the cooling medium for the inside the pump room.
CSS pomp rootn coolers.
0- The room coolers aotumatrcaily tort when
- The c tedp mp 0-V OR F o 0 intli,, rumi in lmcllyc,upwflnr tog ci F
CV pump room coolers.
d e to F)
UI Eaclt rome 000let has a manual tart witch I The room coolers automatically start when:
in the pump mum B The associated pump starts OR
-J Cl) I Room temperature increases to 95°F.
(automatically stop when room temperature decreases to 90°F)
B Each room cooler has a manual start switch in the pump room.
OE Link to OE homepage and discuss Wolf Creek OE 17667, Foreign Material in CS Room Cooler Event.
OBJECTIVE 12 3. Discuss the MCR controls associated with the CSS Co Pumps and the GOl-7 requirements for checking the UI closing spring on 6.9KV and 480V ACBs.
- When 6.9KV and 480V ACBs are made operable
-J and after any operation on safeguards equipment, U) a check shall be made to ensure the applicable ACB closing spring is charged.
501 7 Reqrmmrernent:
When 6.0KV and 460V ACBs are trade operable and after any operation on safeguards equipment, a oheuk shall be made to ensure the appliuable ACB closing spring is uharged.
WBN 10-2011 NRC RO Exam As Submitted 811512011
- 43. 026 A4.05 043 Given the following:
- Containment spray pumps are running after automatically starting during a LOCA.
- Containment pressure has dropped and the procedure directs the pumps be stopped.
Which ONE of the following identifies the minimum signals required to be reset to allow the Containment Spray pumps to remain off when their control switches are returned to A AUTO after the pumps are stopped?
A Containment Spray, only B. Phase B and Containment Spray, only C. Safety Injection and Containment Spray, only D. Safety Injection, Phase B and Containment Spray DIS TRA CTOR ANAL YSIS:
A. Correct, In accordance with the references, the minimum actions required to stop Containment Spray pumps and place them in AUTO is to reset the Containment Spray signal.
B. Incorrect, Plausible because the Phase B is a signal required to be reset once it has been actuated and it would be actuated with the conditions in the question, however, only the Containment Spray signal is required to be reset to allow the spray pumps to be removed.
C. Incorrect, Plausible because Safety Injection is a signal required to be reset once it has been actuated and it would be actuated with the conditions in the question, however, only the Containment Spray signal is required to be reset to allow the spray pumps to be removed.
D. Incorrect, Plausible because Safety Injection and Phase B are signals that are required to be reset once they have been actuated and both would be actuated with the conditions in the question, however only the Containment Spray signal is required to be reset to allow the spray pumps to be removed.
Question Number: 43 Tier: 2 Group 1 Page 115
WBN 10-2011 NRC RO Exam As Submitted 8/15/2011 K/A: 026 A4.05 Containment Spray System (CSS)
Ability to manually operate and/or monitor in the control room:
Containment spray reset switches Importance Rating: 3.5 / 3.5 10 CFR Part 55: 41.7/45.5 to 45.8 IOCFR55.43.b: Not applicable K/A Match: K/A is matched because the question requires the ability to operate the switches required to allow the containment spray pumps to be stopped and placed in AUTO after starting due to a accident signal.
Technical
Reference:
1-47W611-72-1 R8 1-47W611-88-1 R24 E-1, Loss of Reactor or Secondary Coolant, Revision 0016 Proposed references None to be provided:
Learning Objective: 3-OT-SYSO72A
- 05. Describe the Containment Spray Pumps, include power supply, logic, capacity and type.
- 16. Given a set of plant conditions, determine the correct response of the Containment Spray System.
Cognitive Level:
Higher Lower X Question Source:
New Modified Bank Bank X Question History: Turkey point question 026 A4.05 9 (used on a Turkey Point Audit exam) in 2008 changed to make applicable to WBN but not significantly modified.
Comments:
Page 116
WBN Loss of Reactor or Secondary Coolant E-1 Unit I Rev. 0016 Step Action/Expected Response Response Not Obtained
- 9. DETERMINE if cntmt spray should be stopped:
- a. MONITOR cntmt pressure a. WHEN cntmt pressure is less than 2.0 psig. less than 2.0 psig, THEN PERFORM Substeps 9b thru e.
- b. CHECK at least one cntmt b. IF both spray pumps stopped, spray pump RUNNING. THEN GO TO Step 10.
- 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 PLACE breakers OFF for pumps STOPPED [M-15]: pumps that fail to stop:
- 1 -HS-77-41 0.
- 480V AB Com MOO A compt 2C.
- 1 -HS-77-41 1.
Page 7of24
TURKEYPINT DRAFT AUDIT EXAM -11/11/08 Q#43 026A4.05 A LOCA caused Containment pressure to increase to 21 psig.
Which ONE of the following identifies the minimum actions required to stop Containment Spray pumps and place them in Standby?
Reset:
A. Phase B lockout relays.
B. SI and reset Phase B lockout relays.
D. SI and reset Containment Spray.
NOTE: LOCA: Loss of Coolant Accident SI: Safety InjecUon Psig: pounds per square inch gauge 85
3-OT-SYSO72A Revision 9 Page6of33 PROGRAM A. Watts Bar Operator Training COURSES A. License Training B. NOTP C. License Requalification D. AUO Requalification III. TITLE A. Containment Spray System IV. IV. LENGTH OF LESSON A. License Training 2 Hour B. NOTP 4 Hours License Requalification and AUO Requalification times will be determined after objectives are identified.
V. TRAINING OBJECTIVES 0 0<
DO I
< Q U) Cl)
X X X X 01. Explain the design basis of the Containment Spray System in accordance with FSAR section 6.2.2.
X *X X X 02. Draw a simplified diagram of the Containment Spray System showing major components, valves, and flow paths.
X X X 03. List each place from which the Containment Spray System can take suction.
X X X 04. Identify the systems with which the Containment Spray System interfaces.
X X X X 05. Describe the Containment Spray Pumps, include power supply, logic, capacity and type.
X X X X 06. Describe the auto start signals for the Containment Spray Pump room coolers.
X X X X
- 07. Describe the Containment Spray Heat Exchanger.
X X 08. Describe the logic (interlocks) on the Containment Spray suction, discharge header, and containment sump valves.
X X X 09. Identify the power supplies to the major valves of the Containment Spray System.
X X X X 10. Describe the auto operation of the Containment Spray mini-flow valves.
- 11. Deleted.
X X X X 12. Describe the auto action that must be verified after each Containment Spray Pump breaker operation.
3-OT-SYSO72A Revision 9 Page 7 of 33 0 0<
DO I
< 0::: Cl) CI)
X X )( 13. Regarding Technical Specifications and Technical Requirements for this system:
- a. Identify the conditions and required actions with completion time of one hour or less.
- b. Explain the Limiting Conditions for Operation, Applicability, and Bases.
- c. Given a status/set of plant conditions, apply the appropriate Technical Specifications and Technical Requirements.
X X X X 14. Describe the in plant location of the following:
- a. Containment Spray Pumps
- b. Containment Spray Hxs
- d. Containment Spray Pumps RWST Suction
- e. Containment Spray Pumps Sump
- f. Containment Spray Pump Mini flow
- g. Containment Spray System Test Line Flow Indicator
- i. Containments two 14 inch Drain Lines Between Upper and Lower Containment X X X 15. Correctly locate all control room controls and indications associated with the Containment Spray System.
X X X 16. Given a set of plant conditions, determine the correct response of the Containment Spray System.
X X X 17.Deleted.
X X X X 18. Describe how corrosion is controlled in the Containment Spray system during lay-up.
X X X X 19. Identify the basis, requirements and interlocks required to place the RHR spray in service.
X X X 20. Explain Tech Spec bases for Containment Spray components and parameters governed by Tech Specs.
WBN 10-2011 NRC RO Exam As Submitted 8/1512011
- 44. 039 K5.08 044 Given the following plant conditions:
- At EOL, a reactor startup is in progress following a 6-day outage.
- The Reactor Engineer has provided an ECP which predicts the reactor going crftical at 120 steps on Control Bank D.
Which ONE of the following condifions will result in the critical rod height being HIGHER than the value predicted by the ECP?
A. A dilution of 500 gallons is performed.
B. Feedwater flow is increased to all SGs due to a controller malfunction.
C. Steam Dump Controller 1-PlC-i -33 fails, resulting in a steam pressure decrease of 50 psig.
D. An improperly performed step in the Post Maintenance Test procedure results in the closure of all MSIVs.
DISTRA CTOR ANAL YSIS:
A. Incorrect, A dilution results in a positive reactivity addition. This causes the critical rod height to be lower than the ECP.
B. Incorrect, An increase in feedwater flow results in a drop in RCS temperature. The drop in RCS temperature results in a positive reactivity addition. This causes critical rod height to be lower than the ECP.
C. Incorrect, A drop in pressure resulting from the failure of 1-PIC-1-33 causes a drop in RCS temperature. The drop in RCS temperature results in a positive reactivity addition. This causes critical rod height to be lower than the ECP.
D. Correct, The closure of the MSIVs results in an increase in steam pressure, and causes the SG PORVs to lift. This results in an increase in RCS temperature, which results in a negative reactivity addition. This causes critical rod height to be HIGHER than the ECP.
Page 117
WBN 10-2011 NRC RO Exam As Submitted 8115/2011 Question Number: 44 Tier: 2 Group 1 K/A: 039 K5.08 Main and Reheat Steam System (MRSS)
Knowledge of the operational implications of the following concepts as the apply to the MRSS:
Effect of steam removal on reactivity Importance Rating: 3.6 I 3.6 10 CFR Part 55: 41.5/45.7 IOCFR55.43.b: Not applicable KIA Match: K/A is matched because the question requires the knowledge of how changing steam flow (e.g. SG PORVs vs Steam Dump setpoints) affects Tavg and how that change in Tavg affects reactivity.
Technical
Reference:
GO-2, Reactor Startup, Revision 0039 3-OT-G00200, Revision 7 Proposed references None to be provided:
Learning Objective: 3-OT-G00200
- 8. Given conditions indicative of an erroneous Estimated Critical Position (ECP) calculation during the initial pull to critical, describe what steps should be taken by the operator and why.
3-OT-SIPI 100
- 2. Describe the six variables which affect the Estimated Critical Condition.
Cognitive Level:
Higher X Lower Question Source:
New Modified Bank Bank X Question History: WBN Bank question 039 K5.08 044 Comments:
Page 118
WBN Reactor Startup GO-2 Unit I Rev. 0039 Page33of43 Date_________ Initials_____
5.3 Reactor Startup (continued)
NOTE TAVG will vary as a function of reactor power until the unit is greater than 15% turbine load (05) and the Tavg program is maintained by AUTO or manual rod control. The TAVG-TREF deviation alarm is expected as reactor power approaches 7% RTP.
[31] (p) ADJUST Control Rods or RCS OB to RAISE Reactor power, at a rate of less than I dpm, to between I and 4%.
CAUTION IF AFW is controlling levels in one or more SGs, THEN Reactor power must be maintained within AFW capability (less than 4% power).
[32] STABILIZE Reactor power between I and 4%:
[32.1] MAINTAIN RCS Steam Dumps in Pressure Mode, set at 84% (1092 psig.), or SG PORVs set at 84%.
[32.2] (p) FOLLOW Xenon by Rod movement or Boration to maintain control banks ABOVE the LO INSERTION LIMIT.
3 -0T-G00200 Revision 7 Page 18 of28 X. LESSON BODY iNSTRUCTOR NOTES
- 12. CHECK Shutdown Banks fully withdrawn, AND CHECK the ROD BANK UPDATE was updated on the ICS Computer (ROD BANK UPDATE is on NSSS Screen).
- 13. ENSURE the following are completed as required:
TI-34.04
- 1-SI-47-76
- 1-SI-47-77
- 14. ENSURE a member of Operations Management Staff who is NOT a member of the operating crew, is present in the control room during the approach to criticality.
- 15. ANNOUNCE Reactor startup over P/A (N/A if previously performed).
CAUTION 1: Do not exceed +1 DPM.
CAUTION 2: If the approach to criticality is Suggested questions:
suspended or delayed the core shall be maintained sufficiently subcritical to avoid What parameters and which inadvertent criticality. direction of change would insert positive reactivity?
Boron decrease Xenon decrease RCS temp decrease FW flow rate increase Steaming rate increase
- 16. INITIATE Reactor Startup by performing the following:
- a. INITIATE Inverse Count Rate Ratio monitoring (ICRR).
- b. RECORD both SR NIS readings for ICRR base counts.
3 -OT-G00200 Revision 7 Page 8 of 28 X. LESSON BODY INSTRUCTOR NOTES
- c. Pzr-RCS CB difference should be less than For a more dilute Pzr an or equal to 50 ppm and is maintained by outsurge would cause a use of Pzr heaters and spray. positive reactivity insertion and possible Reactor power change.
For a more borated Pzr, an outsurge could cause MTC to go positive at the Beginning-Of-Life (BOL).
- d. Reactor Engineering should be contacted for guidance on core operating recommendations during unusual power maneuvers such as startup at End of Life (EOL).
- e. After refueling, NIS indications may be [SOER 90-31 inaccurate until calibrated at higher power
[Redundant indications of levels. NIS calibration procedures will reactor power should be used adjust PRM trip setpoints lower than until confidence is normal to ensure excore detectors protect against an overpower condition. established in the Power Range (PR) indicators.]
- Normally, reduced by 50% or less if GO-2, Section 5.3, Caution startup is after refueling or if activities prior to Step 6 lists AT and have occurred which could cause non Turbine Power as alternate conservative NIS response.
indications of power level.
- f. In Mode 2 (less than or equal to 5%),
Objective 2 sudden temperature decreases, or CB changes greater than 10 ppm, should be Reactivity Management avoided. Effects The operator should be alert to secondary Objective 2 steam flow to avoid cooling the RCS Could cause spurious Safety below the Minimum Temperature for Injections.
Criticality of greater than or equal to 555°F, and/or causing a spurious Safety T.S. Limit is 55 1°F while Injection. GO-2 requires 555°F to account for inaccuracies.
- A negative moderator temperature Objective 2 coefficient provides more stable reactor operation because it inhibits power changes from continuing in either direction (i.e. increase or decrease).
3 -OT-G00200 Revision 7 Page 9 of 28 X. LESSON BODY INSTRUCTOR NOTES
- Normally boron concentration Objective 2 changes should not have a significant affect on the reactor. If counts double, (i.e., halving the shutdown reactivity) it is significant.
- Moderator temperature increases at Objective 2 higher boron concentrations may add positive reactivity.
- A critical reactor has the capability of Objective 2 heating the moderator suddenly; therefore, a bubble in the Pzr is required to prevent overpressurization of the RCS
- g. All jumper installation and removal shall be in accordance with 0-PI-OPS-l.1, Jumper Control Process.
- h. In Mode 2, trip function of all Turbine Driven Main Feedwater Pumps (TDMFWP) is required when one or more (TDMFWP) is supplying feedwater to the Steam Generators. Refer to Tech Spec 3.3.2 condition J.
- 2. Limitations
- a. In Mode 2 with Keff less than 1.0, or in Mode 3 or 4, Shutdown Margin shall be maintained greater than or equal to 1600 pcm (T.S. 3.1.1).
- b. In Mode 3, at least two RCPs shall be operable with two loops in operation when the Rod Control System is capable of rod withdrawal and at least one RCP in operation when the Rod Control System is not capable of rod withdrawal (T.S. 3.4.5).
- c. SOURCE RANGE HI FLUX AT SHUTDOWN alarm shall be in operation any time the Reactor is shutdown with fuel in the Reactor vessel.
- 1. 039 K5.08 044 Given the following plant conditions:
- At EOL, a reactor startup is in progress following a 6-day outage.
- The Reactor Engineer has provided an ECP which predicts the reactor going critical at 120 steps on Control Bank D.
Which ONE of the following conditions will result in the critical rod height being HIGHER than the value predicted by the ECP?
A. A dilution of 500 gallons is performed.
B. Feedwater flow is increased to all SG5 due to a controller malfunction.
C. Steam Dump Controller 1-PlC-I -33 fails, resulting in a steam pressure decrease of 50 psig.
D. An improperly performed step in the Post Maintenance Test procedure results in the closure of all MSIVs.
DISTRA CTOR ANAL YSIS:
A. Incorrect, A dilution results in a positive reactivity addition. This causes the critical rod height to be lower than the ECP.
B. Incorrect An increase in feedwater flow results in a drop in RCS temperature. The drop in RCS temperature results in a positive reactivity addition. This causes critical rod height to be lower than the ECP.
C. Incorrect, A drop in pressure resulting from the failure of 1-PIC-1-33 causes a drop in RCS temperature. The drop in RCS temperature results in a positive reactivity addition. This causes critical rod height to be lower than the ECP.
D. Correct, The closure of the MSIVs results in an increase in steam pressure, and causes the SG PORVs to lift. This results in an increase in RCS temperature, which results in a negative reactivity addition. This causes critical rod height to be HIGHER than the ECP.
3 -OT-G00200 Revision 7 Page 3 of 28 I. PROGRAM WATTS BAR OPERATOR TRAINING II. COURSE LICENSE TRAIN1NG LICENSE REQUAL III. TITLE GO-2, REACTOR STARTUP IV. LENGTH OF LESSON LICENSE TRAINING 3 Hours LICENSE OPERATOR REQUAL TIME WILL BE DETERMINED WHEN OBJECTIVES ARE IDENTIFIED.
V. TRAINING OBJECTIVES AR S S U OR T 0 0 A X X X 1. Identify the reason for each prerequisite and precaution discussed in this lesson or provided in GO-2.
X X X . Discuss the reactivity management concerns when performing GO-2, Reactor Startup identified in this lesson plan.
X X X 3. State the actions required should an unexplained source range count rate increase occur while performing a reactor startup per GO-2.
X X X 1. Identify the major steps the operator must follow to take the unit from HOT STANDBY (Mode 3) at normal operating temperature and pressure to between 1 and 4% reactor power (Mode 2).
X X X 5. Explain why 0.5 cps is required on the highest reading source range detector prior to pulling the Reactor critical.
K K K 5. [Identify the means/indications used by the Operator to prevent premature criticality during reactor startup SOER 88-2, Rec. 2]
3 .OT-GOO2OO Revision 7 Page 4 of 28 V. TRAiNING OBJECTIVES (Continued)
A R S S U 0 R T 0 0 A X X X 7. Explain the actions taken when power level reaches 1.66 x 1 0 % on 1/2 Intermediate Range (IR) monitors.
X X X 8. Given conditions indicative of an erroneous Estimated Critical Position (ECP) calculation during the initial pull to critical, describe what steps should be taken by the operator and why.
VI. TRAINING AIDS Marker Boards and Markers VII. MATERIALS A. Appendix
- 1. None B. Attachments, Handouts (Latest Revision) One copy of each of the following for each participant:
- 1. Attachment 1, GO-2, Reactor Startup
- 2. Attachment 2, [INPO SOER 88-2, Premature Criticality Events During Reactor Startup] (12 Pages)
- 3. Attachment 3, Power Point Presentation
3-OT-SIP1 100 Revision 5 Page 3 of 20 I. PROGRAM Watts Bar Operator Training II. COURSE LICENSE TRAINING III. TITLE ESTIMATED CRITICAL POSITION IV. LENGTH OF LESSON LICENSE TRAINING 2 HOURS V. TRAINING OBJECTIVES A R S S U 0 R T 0 0 A X X X 1. Explain why the operator should not rely solely on 1-51-0-11, Estimated Critical Position, when taking the reactor critical.
X X X 2. Describe the six variables which affect the Estimated Critical Condition.
X X X 3. Identify the two ways that changes in the Reactor Coolant System Average Temperature are accounted for in the ECP calculation.
X X X 4. Explain how the ECP is derived from the difference in the summations of Reactivity Worths (previous minus estimated).
X X X 5. Identify two ways in which Xenon worth can be determined for both the previous and estimated conditions.
X X X 6. Identify two conditions requiring the ECP to be calculated with a fixed rod control position.
X X X 7. Explain how previous reactor power distributions can effect integral rod worth.
X X X 8. Explain the change in Total Power Defect experienced from BOL to EOL.
VI. TRAINING AIDS A. Marker Boards and Markers B. MultimedialOverhead Projector(s)
WBN 10-2011 NRC RO Exam As Submitted 8/1512011
- 45. 059 A3.03 045 Given the following:
- Unit 1 is operating at 550 MWe.
- Operators have placed the second main feed pump in service.
- Annunciator 49-E, MN/STBY FWP SUCTION NPSH LO, alarms.
- The operating crew determines Main Feed Pump Suction pressure to be 120 psig.
Which ONE of the following identifies the action required by the Annunciator Response Instruction?
A. If suction pressure cannot be restored to greater than 250 psig, a turbine trip is required.
B Suction pressure is low and needs to be raised but currently is above the minimum required.
C. Unless suction pressure is restored to greater than 250 psig, a trip of one MFP is required.
D. Unless suction pressure is restored to greater than annunciator 49-E setpoint, a trip of both MFPs is required.
DIS TRACTOR ANAL YSIS:
A. Incorrect, Plausible because 250 psig is the minimum required MFP suction pressure for loads greater than 600 MWe. If both MFPs were required to be tripped, a turbine trip would be required.
B. Correct, the minimum suction pressure for the MFPs is 100 psig when operating at less than 600 MWe and 250 psig when operating at greater than 600 MWe. With the unit at 550 MWe the pressure is above the minimum required pressure but as evidenced by the alarm, it is lower than normal and needs to be increased.
C. lncorrect. Plausible because if the load had been greater than 600 MWe and suction pressure could not be maintained above 250 psig, a trip of one of the MFP would be required by the ARI.
D. Incorrect, Plausible because both of the main feed water pumps would be required to be tripped if the required minimum suction pressure could not be maintained but this alarm is a differential pressure not the actual suction pressure to the MFPs.
Page 119
WBN 10-2011 NRC RO Exam As Submitted 8115/2011 Question Number: 45 Tier: 2 Group 1 K/A: 059 A3.03 Main Feedwater (MFW) System Ability to monitor automatic operation of the MEW, including:
Feedwater pump suction flow pressure Importance Rating: 2.5 / 2.6 IOCFRPart55: 41.7/45.5 IOCFR55.43.b: Not applicable K/A Match: K/A is matched because the question requires the knowledge of the response to an alarm associated with low MFP suction pressure.
Technical
Reference:
SOl-2&3.01, Condensate And Feedwater System, Revision 0112 ARI-43-49, CNDS & Condenser, Revision 0013 Proposed references None to be provided:
Learning Objective: 3-OT-SYSOO3A
- 14. Evaluate precautions and limitations necessary for operation of the Eeedwater System per S01-2 &
3.01, CONDENSATE AND EEEDWATER SYSTEM.
Cognitive Level:
Higher X Lower Question Source:
New X Modified Bank Bank Question History: New question for the WBN 10-2011 NRC exam Comments:
Page 120
WBN CNDS&CONDENSER ARI-43-49 Unit I Rev. 0013 Page 45 of 50 49-E Source Setpoint 1-PS-2-129A 100 psid MNISTBY FWP SUCTION NPSH LO (Page 1 of 2)
NOTE 1-PS-2-129A receives a signal from 1-PM-2-129 which compares MFPs suction (1-PT-2-129, high side) to Heater A2 shell press (1-PT-5-31A, low side).
Probable A. Increasing load Cause: B. Loss of Condensate System pumps C. Associated pump recirc valve open D. Feedwater heater isolation Corrective [1] MONITOR MFWP suction press on 1-PI-2-129 [1-M3].
Action: [2] ENSURE the following pumps/flow paths are operating as required by current unit load and plant conditions:
- Hotwell Pumps
- Condensate Demin Pumps
- Condensate Booster Pumps
- No. 7 HDT Pumps
- No. 3 HDT Pumps
[3] IF unable to recover suction pressure by restoring required Condensate flow, THEN REFER TO AOI-39, RAPID LOAD REDUCTION, to reduce Turbine load.
Continued on next page
WBN CNDS & CONDENSER ARI-43-49 Unit I Rev. 0013 Page 46 of 50 49-E MN/STBY FWP SUCTION NPSH LO Corrective Action: (Continued)
(Page 2 of 2)
NOTE The low suction press limits given in the table below are conservative, and allow time for the operator to attempt recovery actions.
[4] IF unable to recover suction pressure by restoring required Condensate flow or reducing load, THEN PERFORM the followinci:
Turbine Load Suction pressure Limit Action Less than or equal to 100 psig TRIP one MFP Comi 600MW **
GOTOAOI-16 Greater than 250 psig TRIP one MFP O,3rcf 600MW **
GO TO AOI-16
References:
1 -47W6 10-2-3 1 -47W61 0-5-1 1-47W61 1-2-2 AC 1-16
WBN Condensate And Feedwater System SOI-2&3.01 Uniti Rev.0112 Pagel5of242 3.0 PRECAUTIONS AND LIMITATIONS (continued)
- 5. A feedwater isolation (FWI) signal will cause the SMFP miniflow valves to fully open. The valves will return to their modulated position on FWI signal reset, or they can be controlled manually. This design change was made to give the miniflow valves a head start open signal on FWI to limit the delta pressure transient across the valves for improvement of operation and service life.
- 6. The following are monitored during Standby MFP operation. Pump is manually tripped if manufacturers limit is reached and no auto-trip occurs.
PARAMETER MANUFACTURERS LIMIT Low Suction Press 100 psig (below 50% load) 250 psig (50% load or above)
High Discharge Press 1363 psig Low Bearing Oil Press 8 psig or less (Auto Trip) 10 psig or less (Auto Trip)
High Bearing Metal Temp 225°For more (Journal & Thrust)
- 7. If SBMFP vibration is greater than or equal to 5 mils, evaluate Unit load reduction to allow removal of pump from service. If vibration reaches 10 mils, immediately trip the pump.
- 8. The following guidance may be used to start or stop the SBMFP during hot weather:
NOTE The MFPT CONDENSER VACUUM LO alarm [Window 55-D} comes in at 12.5 Hg vacuum (17.5 HgA). This corresponds to a MFPT condenser drain temperature of 1 85°F.
If the SBMFP is in service due to elevated hotwell and circulating water temperatures, the following guidance may be used to remove the SBMFP from service as water temperatures drop:
The SBMFP may be secured if any of the following conditions exist:
- a. Both MFPT condensers are 12.5 in. HgA, OR
- b. Hotwell pump discharge temperature drops to 129°F, OR
WBN Condensate And Feedwater System SOI-2&3.01 Uniti Rev.0112 Page 16 of 242 3.0 PRECAUTIONS AND LIMITATIONS (continued)
- c. C zone main condenser back pressure drops to 5.0 in. HgA, OR
- d. CCW inlet temperature drops to 87°F (should be secured prior to 67°F) with all 4 CCW pumps in service, OR
- e. MFPT Condenser drain temperature 171°F.
If the SBMFP is NOT in service, the following guidance may be used to place the SBMFP in service as water temperatures rise:
The SBMFP should be placed in service if any of the following conditions exist:
- f. Either MFPT condensers are >15.4 in, HgA, OR
- g. Hotwell pump discharge temperature achieves the maximum allowable condensate polisher inlet temperature of 140°F, OR
- h. C zone main condenser back pressure achieves the alarm setpoint when operating above 90% power, OR
- i. Plant power is power limited due to C Zone main condenser back pressure exceeding the associated alarm setpoint, OR
- j. MFPT Condenser drain temperature >180°F.
- 9. All jumper installation and removal shall be in accordance with 0-Pl-OPS-1 .1, Jumper Control Process.
H. MFWPs/MFPTs
- 1. MFPTs and MFPs Motor, Gear, and Pump Lube systems should be heated to 140 to 160°F oil leaving the bearings before placing RCW in service to the oil coolers. Oil temp alarm is 170°F. This helps limit startup vibration.
- 2. The MFPT turning gear is NOT designed to be rolled off like the main turbine. Any action or evolution that could spin the MFP turbine while the turning gear is in operation could result in damage if the turning gear is NOT removed from service. Example: Unisolating the manual valves to the HP or LP steam supply.
- 3. MFP suction press should be kept as low as possible to help prevent exceeding the discharge piping design pressure of 1230 psig. However, short duration disch press up to 1363 psig is acceptable.
3-OT-SYS0O3A Revision 10 Page5of35 I. PROGRAM Watts Bar Operator Training II. COURSES License Training NOTP License Requalification NAUO Requalification III. TITLE Main Feedwater System IV. LENGTH OF LESSON A. License Training 3 Hours B. NOTP 3 Hours License Requalification and NAUO Requalification times will be determined after objectives are identified.
V. TRAINING OBJECTIVES ARS UOR 0 0 X X 1. Describe the purpose of the Feedwater System.
X X 2. Describe the flow path per SOl-2 & 3.01, Condensate And Feedwater System, or the lesson body through the feedwater system for the following
- a. Long Cycle Recirculation
- b. Normal Alignment X X 3. Describe the Main Feed Pumps as to type, capacity, and steam supply.
X X 4. Explain the operation of the Main Feed Pump automatic recirculation valve.
X X 5. List the conditions which will cause the main Feed Pumps to automatically trip.
X X 6. Describe the MFPT Speed Control Program.
X X 7. Describe the Standby Main Feed Pump as to type, capacity, and power supply.
X X 8. Explain the operation of the Standby Main Feed Pump automatic recirculation valve.
X X 9. Identify the permissives required to be met before the Standby Main Feed Pump can be automatically or manually started.
X X 10. Evaluate the conditions that will cause a Standby Main Feed Pump to trip.
X X 11. Identify the Feedwater Isolation Signals.
3-OT-SYS003A Revision 10 Page 6 of 35 ARSS UORT 0 OA X X X X 12. List the equipment affected by a Feedwater Isolation Signal.
X X X X 13. Describe the three steps to reset FW Isolation Signal.
X X X X 14. Evaluate precautions and limitations necessary for operation of the Feedwater System per SOl-2 & 3.01, CONDENSATE AND FEEDWATER SYSTEM.
X X X X 15. List the normal, full load condensate pressures and temperatures after each of the major components from the main feed pump suction to the Steam Generators. -
X X X X 16. Describe the inpiant location of all major pumps, heat exchangers, and valvesof the Feedwater system.*
X X X X 17. Deleted. (Objective moved to SYSO46A)
X X X X 18. Demonstrate the contrasting differences in Long Cycle De-Aeration and Long Cycle Operation.
- Objective 16 is accomplished during plant walkdowns of the system. The student is responsible for this information.
3-OT-SYSO03A Revision 10 Page 14 of 35
-J Cl) Feedwater Pressures & Tern peratures
- 1. Discuss the normal, full load condensate pressures and temperatures after each of the major compohents from the main feed pump suction to the Steam Generators.
- MFP Inlet temperature approx. 405 °F.
- MFP Inlet pressure approx. 400 PS 1G.
- #1 heater outlet temperature approx. 441 °F.
- #1 heater outlet pressure approx. 1215 PSIG.
END OF INTRODUCTION
3-OT-SYS0O3A Revision 10 OBJECTIVE 4 Feedwater Pump Low Load Bypass Valves
- 1. Discuss the function and operation of the Feedwater Pump Low Load Bypass Valves.
B Located on each pump discharge and routed to
- the main condenser zone A.
w ___j B They are air-operated, fail open valves that modulate to maintain recirc. flow at 4000 GPM.
- The valves are closed on pump start, then modulate based on input from the Low-Load Bypass Controller.
- 3. Discuss the MCR alarms and setpoints associated with the Main Feedwater Pumps. (note 1A pump alarms are listed. Instructor should point out to the students that the 1 B pump alarms also exist and that their setpoints are the same as 1A).
B Annunciator window XA-55-3A, Window 49-E MN/STBY FWP SUCTION NPSH LO (100 PSID) o B Annunciator window XA-55-3B, Window 55-D MFPT CONDENSER VACUUM LOW (12.5 in Hg Vacuum)
U Annunciator windowXA-55-3C, Window 57-A MFP 1A FLOW LO (1.72 X 106 lbs/hr lowering)
B Annunciator window XA-55-3B, Window 50-E MFP 1A INJ WATER AP LO (5 PSID)
WBN 10-2011 NRC RO Exam As Submitted 8/1512011
- 46. 061 A3.04 046 Given the following:
- Unit I was at 100% power with the TD AFW pump unavailable.
- S/G #2 experiences a steam line break inside containment.
- S/G #2 conditions are as follows:
- Level is currently 12% WR.
- Pressure is 80 psig.
- No operator action has been taken on the AFW system.
Which ONE of the following identifies which, if any, Motor Driven AFW level control valves will be closed automatically?
Note: 1-LCV-3-156 is MD AFW PUMP IA-A SG 2 LEVEL CONTROL 1-LCV-3-156A is SG 2AUXFEEDWATER I-LCV-3-156 BYPASS A ONLY 1-LCV-3-156 B. ONLY 1-LCV-3-156A C. Both 1-LCV-3-156 and 1-LCV-3-156A D. Neither 1-LCV-3-156 nor 1-LCV-3-156 DISTRACTOR ANAL YSIS:
A. Correcl I-LCV-3-156 automatically closes at 500 psig decreasing pressure to protect the MD AFW LCV from cavitation.
B. Incorrect, Plausible if the applicant believes that the 2 bypass line is the line that isolates on low pressure.
C. Incorrect, Plausible because I-LCV-3-156 does automatically close on lowering pressure and there are conditions that will close both the main and bypass valves in the feedwater system (e.g. high level in the steam generator as well as feedwater isolation automatically closes both valves in the main feedwater system.)
D. Incorrect, Plausible because, while I-LCV-3-156 does automatically close, the applicant could incorrectly conclude that pressure is not low enough to cause the isolation.
Page 121
WBN 10-2011 NRC RO Exam As Submitted 8/1512011 Question Number: 46 Tier: 2 Group 1 KJA: 061 A3.04 Auxiliary I Emergency Feedwater (AFW) System Ability to monitor automatic operation of the AFW, including:
Automatic AFW isolation.
Importance Rating: 4.1 / 4.2 IOCFRPart55: 41.7/45.5 IOCFR55.43.b: Not applicable KIA Match: K/A is matched because the question requires the knowledge of the automatic setpoints which would isolate portions of the AFW system from the steam generators.
Technical
Reference:
N3-3B-4002, Auxiliary Feedwater System, Rev. 0016 SOI-3.02, Auxiliary Feedwater, Revision 0049 Proposed references None to be provided:
Learning Objective: 3-OT-SYSOO3B
- 22. Identify the initiating signals that swap the Motor Driven Pumps LCVs from normal to the bypass LCV.
Cognitive Level:
Higher X Lower Question Source:
New X Modified Bank Bank Question History: New question for the WBN 10-2011 NRC exam Comments:
Page 122
WBN Auxiliary Feedwater System SOI-3.02 Unit I Rev. 0049 Page 8 of 74 3.0 PRECAUTIONS AND LIMITATIONS (continued)
K. After each AFWP start, 6.9kV ACB closing spring must be checked to ensure it is charged.ic.ioi L. An operator with no other duties will be assigned to initiate AFW any time the auto initiation circuits are inoperable. Engineering or Maintenance personnel must notify the Shift Manager (SM) if this condition exists.[c.8]
M. Excessive RCS cooldown is possible when using AFW System.
N. Any time Turbine Driven or Motor Driven AFW Pumps are running, oil level and temperature should be checked frequently. Pumps must be TRIPPED if pump bearing oil temperature exceeds 165°F and cause of overheating determined, and corrected prior to pump resuming operation.
- 0. Turbine Bearing Oil pressure should be above 15 psig, and Turbine Bearing Oil temperature below 180°F. TD AFW Pump should be TRIPPED if Turbine Bearing Oil Temperature exceeds 200°F.
P. When SGs are above 212°F, backleakage to the AFW system can lead to pump steam binding. AUO rounds require periodic checking of the pumps for this condition. Venting is required until the cause is found and corrected whenever this condition occurs. [ci, C.2, C.4, C.6, c.7]
Q. 4 LCVs from M-D AFWPs auto close when Feedwater header pressure drops below 500 psig to prevent cavitation damage to LCV.
R. Low flow operation of both motor and turbine driven AFW pumps must be minimized to prevent possible degradation of pump impeller. Main Feedwater System should be utilized for low flow conditions if available.
S. The minimum pressure that the backup nitrogen supply bottles can reach and still supply the required volume to cycle one train of LCVs five times is 1085 psig. Bottles should be changed out when pressure lowers to 1200 psig or below.
T. With the additional recirculation line in service, use of the Motor-driven pump(s)
(if available), is preferred over the use of the Turbine-driven pump during low flow conditions when the AFW demand is within the capability of the Motor-driven pump(s).
U. SGBD isolation will initially raise indicated Calorimetric Power associated with the resulting feedwater flow transient. It may take several minutes for Calorimetric Power and Feedwater Flow to stabilize at their new lower values.[c.i 1]
- WBN System AUXILIARY FEEDWATER SYSTEM WBN-SDD-N3-3B-4002 Description Rev. 0016
. Document Page 51 of 101 3.3.2 Turbine-Driven Pump (TDP) (continued)
D. TDP speed, and therefore capacity, are governed by pump flow. The TDP flow signal is relayed to a flow controller (FIC-46-57), which provides a 10 to 50 mA signal to the turbine governor system. 10 mA corresponds to a rated low speed of 2076 rpm, and 50 Ma corresponds to rated high speed of 3950 rpm. The governor system uses this electrical signal to position the governor valve (GV) via hydraulic-mechanical controls (see subSection 3.3.9) so that system flow demand is satisfied. With the control in Auto flow is no greater than 850 gpm (plus or minus control loop inaccuracies). Manual speed control is also provided to enable the operator to control speed from 2076 to 3950 rpm (Refs. 7.5.7 and 7.4.15). Use of the speed control in combination with the LCVs allow the operator to control the flow from 0 to 720 gpm.
The 850 gpm reflects controller inaccuracies to assure a minimum of 720 gpm.
E. The TDP reaches maximum speed within a few seconds and, the potential exists for tripping the turbine during startup due to overspeed. The governor system is equipped with a ramp generator, which controls turbine acceleration rate up to a speed determined by flow controller output. That is, turbine speed could go to the high speed associated with the 50 mA flow controller signal if necessary to satisfy flow demand, or it could go to a lower speed if this satisfies flow demand. In either case, acceleration during starting is controlled by the ramp generator so that overspeed trip is avoided.
F. As TDP discharge and steam inlet pressure change with SG conditions, the appropriate milliamp signal will be sent to the turbine to maintain required pump flow.
See Table 8 for the pump flow and head this unit was designed to provide (See Section 3.3.7 for overspeed trip).
3.3.3 MDP Pressure Control Valves (PCVs)
A. A 4 PCV in the discharge of each MDP throttles closed to create sufficient backpressure to prevent pump run-out when SG pressures are low (during cooldown or for a faulted SG). This avoids potential for pump cavitation damage. The PCV throttles closed in response to lowered differential pressure (DP) across the pump. It continues to close until a predetermined pump DP, corresponding to an acceptable operating point on the pump curve is achieved. The PCV will control flow to less than 700 gpm. The value used for MSLB analysis assumed failure of this controller.
B. The PCVs are safety-grade air operated valves (AOV5) and have trained air supplies (Ref. 7.2.2). The train A MDPs PCV is supplied by train A air, and the train B pumps PCV is supplied by train B air. Remote manual controls for these valves are in the ACR, which duplicates the MCR functions. Transfer switches are provided to shift control of these valves from the MCR to the ACR to provide electrical isolation of the MCR upon evacuation of the MCR.
3.3.4 MDP Level Control Valves (LCVs)
A. The 4 LCVs are AOVs powered by separate trains of ACA (see Ref. 7.2.2) and 1E dc power. These valves are normally closed (energized solenoid) which begin to modulate (de-energized solenoid) to automatically control SG level by regulating MDP flow whenever the associated MDP is operating. These valves close when their associated downstream pressure switches (PS) sense feedwater header pressure less than their setpoint which is intended to prevent cavitation damage to the LCV.
3-OT-SYSOO3B Revision 13 Page 6 of 60 A SS R
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X X X X 9 Identify the power supplies to the Motor-Driven AFW pumps X X X X 10 Identify the A-Auto start signals of the Motor-Driven AFW pumps X X X X 11 Describe the automatic actuations that occur when an AFW pump is started 12 Explain the reasons (bases) for precautions associated with AFW operation as described in SOI-3 02 (NOTE 3) 13 Describe the caution associated with opening the ERCW supply valves as stated in SOl-3.02.
- 14. Describe the normal and alternate steam supplies to the Turbine-Driven AFW x Pump.
X X X X 15. Describe the sequence of events that occur on a steam supply swapover.
- 16. Identify the isolation signals of the steam supply valves x x x (FCV-1-17 &18) to the Turbine-Driven AFW pump.
X X X X 17 Identify the Turbine-Driven Auxiliary Feedwater pump Auto start signals
- 18. List the trips on the Auxiliary Feedwater Pumps and include any local steps to resetting them.
19 Identify the pressure at which the Motor-Driven AFW pump discharge pressure control valve should be set X X X X 20 Identify what the SIG level setpoint is for the AFW system LCV s
- 21. Explain how to manually control SIG levels with the Motor-Driven Auxiliary Feedwater pumps LCVs.
- 22. Identify the initiating signals that swap the Motor-Driven Pumps LCVs from normal to the bypass LCV.
- 23. Using plant drawings, determine the effect of a loss of instrument air/control power on the following valves/components:
X X X a. MDAFWP regulating valve (main and bypass)
- b. TDAFWP regulating valve c AFW pumps 24 [Identify the problem that disables the AFW pumps and describe Watts Bars solution to the problem (SOER 84-3 Rec #1-4)]
3-OT-SYS0O3B Revision 12
- LCVs for SIGs 1 and 2 are located in Auxiliary 0 LCVs for SIGn I and 2 are located in Aaoilivry Bailding elevatian 737 overhead near the west wall. Building elevation 737 overhead near the west p LCVs for Sf25 3 and 4 are also located en elevation 737 overhead near thnwest wall on a separate platform. wall.
- LCVs for SIGs 3 and 4 are also located on elevation 737 overhead near the west wall on a separate platform w
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OBJECTIVE 22
0 Motnr-Ddven APEd pamps LCVs operate an a split-range 3-15 psigenntrnline.
S The 2 bypass valve will throttle full close to Thy 2 bypass vOlvo will thrvllln Evil vlvnv tv fall vpvv (row 2.9 PSIG (v.50% dewvvd(.
full open from 3-9 PSIG (0-50% demand).
Thy vsviv (4( vvlav vslli lhrvtliv fall vlvvv lv (all vpvv (row P-IS PSIG (00lPO%dvwavsl(
0 The 4 valve receives an isolation signal ashen 5(2 feed S The main (4) valve will throttle full close to full line prossarn decreases to <Sot psig and nannvt be opened in aateorinnaaeaal. open from 9-15 PSIG (50-100% demand).
S The 4 valve receives an isolation signal when S!G feed line pressure decreases to <500 psig and cannot be opened in auto or in manual.
w
-J U)
WBN 10-2011 NRC RO Exam As Submitted 8115/2011
- 47. 061 K4.02 047 Given the following:
- Unit I is operating at 4% power.
- Main Feed Pump B is in service.
- Main Feed Pump A is NOT reset.
- All Steam Generator levels are at 38% NR.
Which ONE of the following identifies the status of the AFW Pumps immediately after Main Feedwater Pump B trips?
A. Only the TDAFW pump has automatically started.
B. Only the MDAFW pumps have automatically started.
C Both the MDAFW pumps and TDAFW Pump have automatically started.
D. Neither the MDAFW pumps nor TDAFW Pump have automatically started.
DISTRA CTOR ANAL YSIS:
A. Incorrec1, Plausible because there is a condition (blackout) where only the TD AFW pump would be automatically started immediately.
B. Incorreci, Plausible because there is a condition (level low in only one steam generator) where only the MD AFW pump would be automatically started immediately.
C. Correct, When the MFPT lB trips, the control circuit will see both MFPTs as tripped due to MFPT 1A not being reset. Both MFPTs tripped is a condition that will start both MD AFW pumps and the TD AFW pump.
D. Incorrect, Plausible because none of the AFW pumps would have been started if MFPT IA had been reset when MFPT lB tripped and because the steam generator levels are above the level required to start any AFW pump.
Question Number: 47 Tier: 2 Group 1 KIA: 061 K4.02 Auxiliary I Emergency Feedwater (AFW) System Page 123
WBN 10-2011 NRC RO Exam As Submitted 8/15/2011 KIA: 061 K4.02 Auxiliary / Emergency Feedwater (AFW) System Knowledge of AFW design feature(s) and/or interlock(s) which provide for the following:
AFW automatic start upon loss of MFW pump, SIG level, blackout, or safety injection Importance Rating: 4.5 / 4.6 10 CFR Part 55: 41.7 10CFR55.43.b: Not applicable K/A Match: K/A is matched because the question requires knowledge of AFW design features and/or interlocks which provide for starting the AFW pumps upon loss of MEW pump.
Technical
Reference:
1-47W611-3-1 R12 1-47W611-3-3 R12 1-47W611-3-4 R18 SOl-3.02, Auxiliary Feedwater System, Revision 0049 Proposed references None to be provided:
Learning Objective: 3-OT-5Y50038
- 10. Identify the A-Auto start signals of the Motor-Driven AFW pumps.
Cognitive Level:
Higher X Lower Question Source:
New Modified Bank X Bank Question History: Robinson bank question 000054AA1 .02 (used on Robinson 2008 exam) modified to make applicable to WBN.
Comments:
Page 124
WBN Auxiliary Feedwater System S0I-3.02 Unit I Rev. 0049 Page 20 of 74 6.0 NORMAL OPERATION AFW provides a RCS heat sink during cooldown and when the Main Feedwater (MFW) System is unavailable. AFW is normally in STANDBY subject to the following AUTO-STARTS:
I Loss of both MFW Pumps I Loss of both MFW Pumps -Co 2 Lo-Lo Level in any SG 2 Lo-Lo Level in 2/4 SGs 3 Safety Injection 3 Safety Injection 4 Blackout ç\ i. D 4 Blackout 5 AMSAC 5 AMSAC After starting, the respective Level Control Valves (LCV5) automatically maintain SG levels at 38%. 200,000 gal in the CST will maintain the unit at HOT STANDBY for 2 hours2.314815e-5 days <br />5.555556e-4 hours <br />3.306878e-6 weeks <br />7.61e-7 months <br />, followed by a 4 hour4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br /> cooldown to 350°F, while dumping steam to atmosphere concurrent with total loss of offsite power. If an additional supply to AFW is needed, ERCW discharge headers can be aligned to AFW Pumps suction automatically on low suction pressure or manually by the operator.
With the additional recirculation line in service, use of the Motor-driven pump(s) (if available), is preferred over the use of the Turbine-driven pump during low flow conditions when the AFW demand is within the capability of the Motor-driven pump(s).
Applicable attachments are performed at discretion of operations Superintendent or designee. Attachments will normally be performed for system alignment verification in Mode 5 or when alignment verifications needed.
SGBD isolation will initially raise indicated Calorimetric Power associated with the resulting feedwater flow transient. It may take several minutes for Calorimetric Power and Feedwater Flow to stabilize at their new lower values.
7.0 SHUTDOWN AFW System remains in STANDBY alignment.
og HLC-08 NRC Written Exam
- 10. Given the following:
- The Reactor is at 4% RTP in preparation for Turbine startup.
- Main Feedwater Pump A is under clearance for maintenance.
Main Feedwater Pump B is operating.
- Narrow range Steam Generator levels are at 44%.
Which ONE (1) of the following statements describes the AFW Pump status immediately after Main Feedwater Pump B trips?
A. The MDAFW and SDAFW Pumps must be manually started.
B. The MDAFW Pumps have auto started but the SDAFW Pump must be manually started if required.
C. The SDAFW Pump has auto started but the MDAFW Pumps must be manually started if required.
D. The MDAFW and SDAFW Pumps have auto started.
10
3-OT-SYSOO3B Revision 13 Page 5 of 60 I. PROGRAM Watts Bar Operator Training II. COURSES License Training NOTP License Requalification NAUO Requalification III. TITLE Auxiliary Feedwater System IV. LENGTH OF LESSON A. License Training 4 Hours B. NOTP 4 Hours License Requalification and NAUO Requalification times will be determined after objectives are identified.
V. TRAINING OBJECTIVES A SS R
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2 State the function of the AFW system in accordance with the System Description Manual.
- 3. Describe how the Auxiliary Feedwater pumps are protected from low flow conditions.
X X X X 4. Identify the steam generators that each AFW pump supplies.
- 5. Describe the Reserve Auxiliary Feedwater Capacity in the CSTs and include how it is ensured.
- 6. Identify the required CST volume needed for AFW operation as stated in Tech Specs and the basis for this volume 7 Identify in which Modes the CST and the AFW System are governed by Tech Specs
3-OT-SYSO03B Revision 13 Page6of60 A S R
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X X X X 9. Identify the power supplies to the Motor-Driven AFW pumps.
X X 10. Identify the A-Auto start signals of the Motor-Driven AFW pumps.
X X 1 1. Describe the automatic actuations that occur when an AFW pump is started.
- 12. Explain the reasons (bases) for precautionsassociated with AFW operation as described in S01-3.02. (NOTE 3) 13 Describe the caution associated with opening the ERCW supply valves as stated in SOI-3.02.
- 14. Describe the normal and alternate steam supplies to the Turbine-Driven AFW Pump.
X X X X 15. Describe the sequence of events that occur on a steam supply swapover.
- 16. Identify the isolation signals of the steam supply valves (FCV-1-17 &18) to the Turbine-Driven AFW pump.
X X X X 17. Identify the Turbine-Driven Auxiliary Feedwater pump Auto start signals.
- 18. List the trips on the Auxiliary Feedwater Pumps and include any local steps to x x resetting them.
- 19. Identify the pressure at which the Motor-Driven AFW pump discharge pressure control valve should be set.
X X X 20 Identify what the S/G level setpoint is for the AFW system LCV s
- 21. Explain how to manually control SIG levels with the Motor-Driven Auxiliary Feedwater pumps LCVs.
- 22. Identify the initiating signals that swap the Motor-Driven Pumps LCVs from normal to the bypass LCV.
- 23. Using plant drawings, determine the effect.of a loss of instrument air/control power on the following valves/components:
X X X a. MDAFWP regulating valve (main and bypass) b TDAFWP regulating valve c AFW pumps 24 [Identify the problem that disables the AFW pumps and describe Watts Bar s x x solution to the problem (SOER 84-3 Rec #1-4)]
3-OT-SYSO03B Revision 13
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- 25. Describe the changes that take place when the Turbine-Driven AFW pump transfer switch (XS-46-57) is placed in Aux position.
- 26. Identify the steps to gain local control of the Turbine-Driven Auxiliary Feedwater pump and SG levels.
- 27. Describe how to take manual control of the Turbine-Driven AFW pump from x x the control room.
- 28. [Describe how to reset an electrical and mechanical overspeed trip on the X X X X Turbine-Driven AFW pump, both electrically and locally (SOER-82-08, Rec.
4)]
- 29. Explain the purpose of each controller and indicator on the local Control panel for the Turbine-Driven AFW Pump.
- 30. [Identify three (3) contributing factors that have left the Trip and Throttle valve in a tripped position when the Operators thought it was reset and describe controls put in place at WBN to keep this from occurring. (SOER 82-8, Rec.
- 4)]
- 31. [Identify the dominant causes of failures leading to significant losses of AFW.
- 32. [Identify three possible adverse effects which could occur if the AFW pump turbine overspeeds (SOER-89-01)]
X X X X 33. Sketch the Auxiliary Feedwater System, beginning at the CSTs and ending at the SGs. (NOTE 1)
X X X X 34. List each main isolation valve in the suction line of the Auxiliary Feedwater System and state in which building it is located. (NOTE 1)
X X X X 35. List each of the checks that should be made on the Auxiliary Feedwater Pumps normally and while running.
3-OT-SYSOO3B Revision 13 Page 8 of 60 X 36. Describe the in-plant location of the following: (NOTE 1)
- a. Auxiliary Feedwater Pumps
- b. Auxiliary Feedwater Level Control Valves
- c. Flood Mode Spool Pieces
- d. Auxiliary Feedwater Supply Valves
- e. Steam Supply Valves to Turbine-Driven Auxiliary Feedwater Pumps
- f. Turbine-Driven Auxiliary Pump Trip and Throttle Valve
- g. Motor-Driven AFW Recirc Valves
- 37. Correctly locate control room controls and indications associated with the AFW system, including: (NOTE 2)
- a. AFWPs
- b. AFW regulating valve
- c. SIG level
- d. CST level NOTE 1: Objective accomplished during walk downs of the system. Student is responsible for this information.
NOTE 2: Objective accomplished during simulator demo of the system. Student is responsible for this information.
NOTE 3: Use latest revision of S0I-3.02 for discussion of the precautions and limitations for AFW.
WBN 10-2011 NRC RO Exam As Submitted 811512011
- 48. 062 A2.01 048 Given the following:
- Unit 1 is operating at 60% power.
- 480V Shutdown Board 1A2-A de-energizes due to an internal fault.
Which ONE of the following identifies...
(1) how the loss of the board affects the operation of the unit and (2) the action required to mitigate the impact of the condition?
A. (1) Increasing Main Turbine Oil temperature.
(2) Place 1-TIC-24-69, MTOT TEMP TEMP CONTROL, in MAN and open theTCV.
B (1) Loss of most radiation monitor rate meters in the MCR.
(2) Transfer Instrument Power Rack A to ALTERNATE.
C. (1) A turbine trip due to Stator Cooling Water Temperature (2) Transfer Instrument Power Rack A to ALTERNATE.
D. (1) Increasing Generator Hydrogen temperature.
(2) Place 1-TIC-24-48, GENERATOR H2 TEMP CONTROL, in manual and open the TCV.
Page 125
WBN 10-2011 NRC RO Exam As Submitted 8/1512011 DISTRACTOR ANAL YSIS:
A. Incorrect, Plausible because of loss of the main turbine oil temperature control would result if the 480V Shutdown Board 182-B had been lost resulting in a loss of Instrument Power Rack B instead of loss of the Instrument Power Rack A. Placing the controller to manual would have allowed the operator to manually control the oil temperature.
B. Correct, the loss of the board will result in a loss of power to the Instrument Power Rack A which will result in a loss of power for most of the radiation monitor rate meters in the main control room and the power can be restored by transferring the rack power to alternate which allows the rate meters to then be reset.
C. lncorrect Plausible because the Stator Cooling water temperature control loop is supplied from the Instrument Power Rack A but its loss does not result in a loss of cooling for the system. However, a 480V Shutdown Board 182-B resulting in a loss of hydrogen cooling will cause the Stator Cooling Water system to heatup causing an automatic turbine trip unless the Rack B is swapped to alternate or manual control of Hydrogen temperature is established.
D. Incorrect, Plausible because of loss of the generator hydrogen temperature control would result if the 480V Shutdown Board 182-B had been lost resulting in a loss of Instrument Power Rack B instead of loss of the Instrument Power Rack A. Placing the controller to manual would have allowed the operator to manually control the generator hydrogen temperature.
Question Number: 48 Tier: 2 Group: 1 KIA: 062 A2.01 AC Electrical Distribution System Ability to (a) predict the impacts of the following malfunctions or operations on the ac distribution system; and (b) based on those predictions, use procedures to correct, control, or mitigate the consequences of those malfunctions or operations:
Types of loads that, if de-energized, would degrade or hinder plant operation.
Importance Rating: 3.4 I 3.9 10 CFR Part 55: 41.5/43.5/45.3/45.13 IOCFR55.43.b: Not applicable K/A Match: K/A is matched because the question requires knowledge of secondary side loads that are affected by the loss of a 480V Page 126
WBN 10-2011 NRC RO Exam As Submitted 8115/2011 K/A Match: K/A is matched because the question requires knowledge of secondary side loads that are affected by the loss of a 480V shutdown board and the actions required to mitigate the consequence of the affect.
Technical
Reference:
AOl-43.01, Loss of Unit 1 Train A Shutdown Board, Revision 0009 1-45W700-1 R31 1-45W600-351 R12 1 -45W600-35-2 Ri 1 1 45W600-35-4 Ri 1 1-45W1646-3 R18 1-45W1646-4 R23 1 -45W600-47-6 R6 Proposed references None to be provided:
Learning Objective: 3-OT-A0l4300
- 2. Analyze alarms and indications for loss of a 6.9kV Shutdown Board, and evaluate their importance to system operation per AOl.
Cognitive Level:
Higher X Lower Question Source:
New X Modified Bank Bank Question History: New question for the WBN 10/2011 NRC exam Comments:
Page 127
WBN Loss of Unit I Train A Shutdown AOl-43.0I Unit I Boards Rev 0009 Step Action/Expected Response Response Not Obtained 3.5.4 Compensatory Actions Loss of 480V SD BD 1A2-A NOTE Appendix A provides list of Unavailable Equipment resulting from a loss of 480V SD BD I A2-A.
MONITOR 480V SD BD 1A2-A supply sources, WHEN power supply AVAILABLE, THEN ** GO TO Section 3.5.2 Step 5.
- 2. ENSURE Unit I Instrument Power A Rack selected to ENERGIZED feeder (amber light ON)[I-M-7]
AND RESET Radiation Monitor modules and alarms on O-M-12.
- 3. MONITOR containment upper and START containment cooling fans as lower compartment average air needed to maintain temp. within limits:
temperatures are within limits: (SOl-30.03)
S/R 3.6.5.1, Computer Point
- CRD Mech Cooler Fans U901
- Lower Compartment Cooler o S/R 3.6.5.2, Computer Point Fans U9020 Upper Compartment Cooler Fans
- 4. ENSURE Aux Bldg General Supply and Exhaust Fans in-service as required to maintain ventilation and pressure (SOl-30.05).
- 5. ENSURE MCR Air Conditioning Unit B-B in-service (SOI-31.O1).
Page 52 of 69
WBN Loss of Unit I Train A Shutdown AOI-43.0I Unit I Boards Rev. 0009 Step Action/Expected Response Response Not Obtained 3.5.2 Energize 480V SD BD 1A2-A (continued)
- 11. CHECK voltage available from 480V PERFORM ONE of the following SD XFMR IA-A on 480V SD BD 1A2-A actions:
secondary inst. voltmeter. [480V SD
- IF conditions allow, THEN BD 1A2-A CI4A]
ENERGIZE 480V SD XFMR lA-A by closing 1-BKR-212-A-A [6.9kv SD BD IA-A Cmpt 5],
OR GO TO Section 3.5.4, Compensatory Actions for Long Term Loss of 480V SD BD 1A2-A.
- 12. CHECK I -BKR-21 2-A2/1 B-A, Normal Supply Breaker 52N, OPEN. [CuB]
- 13. CLOSE 1-BKR-21 1-A2/4B-A, ALT Supply Breaker 54E.
- 15. ENSURE the following
- a. Unit I Instrument Power A Rack aligned to Normal feeder (amber light ON). [1-M-7].
- b. Radiation Monitor modules and alarms on 0-M-12 RESET.
- 16. RETURN TO procedure in effect.
End of Section Page 48 of 69
3-OT-AO 14300 Rev 4 Page 4 of 130 I. PROGRAM Watts Bar Operator Training II. COURSE License Training III. TITLE AOI-43, Loss of 6.9KV Shutdown Board IV. LENGTH OF LESSON License Training 1.5 Hours NOTP 1.0 Hours V. TRAINING OBJECTIVES A S U R 0 0 X 1. Demonstrate ability to recognize a loss of any 6.9KV Shutdown Board.
X 2. Analyze alarms and indications for loss of a 6.9KV Shutdown Board, and evaluate their importance to system operation per AOl.
X 3. Given plant conditions, determine if Tech Spec entry is required, what actions(s) must be taken, and the bases for those actions.
X X X 4 Demonstrate ability/knowledge of AOl by a Recognizing Entry conditions b Responding to Actions c Responding to Contingencies (RNO) d Responding to Notes/Cautions X X 5. Discuss methods of restoring power to a 6.9KV Shutdown Board X X 6. Describe the Purpose/Goal of AOI-43, Loss of 6.9KV Shutdown Board.
WBN 10-2011 NRC RO Exam As Submitted 8115/2011
- 49. 063 G2.1.25 049 Given the following:
- Unit 1 is operating at 100% power.
- A battery discharge test is in progress on 125v DC Battery IV and the 125v DC Battery Board V is connected to the 125v DC Battery Board IV.
- 0-S 1-0-3, Weekly Log, is being performed.
Using 0-SI-0-3, Appendix A, which ONE of the following identifies the status of the 1 25v DC Battery Board IV and the I 20v AC Vital lnverter 2-IV?
REFERENCE PROVIDED 125v DC Battery Board IV Vital Inverler 2-IV A. Operable Inoperable B. Operable Operable C Inoperable Inoperable D. Inoperable Operable Page 128
WBN 10-2011 NRC RO Exam As Submitted 8/1512011 DIS TRACTOR ANAL YSIS:
A. Incorrect, Plausible because the 125V DC Battery Board IV can remain operable when connected to 125v DC Vital Battery Board V and there is a charger on the board. However, charger V is not a qualified charger. Also, because the inverter being inoperable due to not having a DC power supply is correct.
B. lncorrect. Plausible because the 125V DC Battery Board IV can remain operable when connected to 125v DC Vital Battery Board V and there is a charger on the board. However, charger V is not a qualified charger. Also, because the inverter is in service, has an available supply from Bat Bd IV. The applicant must understand the meaning of available and if misapplied then the inverter could be determined to be operable in error.
C. Correct When the 125V DC Battery V is being used to supply one of the 125v DC Vital Battery Boards, the 125V DC Battery Charger V must be disconnected from the 125v DC Battery Board V and a spare charger aligned to the Battery Board being supplied. Also, for the inverter to be operable it must be aligned to a DC power supply. The completed charts show that the 125V DC Battery Charger V remains connected with no spare charger connected and that the inverter is not aligned to a DC supply.
D. Incorrect, Plausible because the 125V DC Battery Board IV being inoperable is correct due to the charger alignments and because the inverter is in service, has a power supply (connected to the Instrument Power Board) and has an available supply from Bat Bd IV. The applicant must understand the meaning of available and if misapplied then the inverter could be determined to be operable in error.
Page 129
WBN 10-2011 NRC RO Exam As Submitted 8115/2011 Question Number: 49 Tier: 2 Group: 1 K/A: 063 G2.1.25 D.C. Electrical Distribution Conduct of Operations Ability to interpret reference materials, such as graphs, curves, tables, etc.
Importance Rating: 3.9 I 4.2 IOCFRPart55: 41.10/43.5/45.12 IOCFR55.43.b: Not applicable K/A Match: K/A is matched because the question requires ability to extract information from completed tables in a surveillance procedure to determine the status of the D.C. Electrical Distribution system and the 120v AC vital system it supports.
Technical
Reference:
0-SI-0-3, Weekly Log, Revision 0045 Tech Spec 3.8.7, Inverters-Operating 1-45W700-1 R31 Proposed references 0-S 1-0-3, Weekly Log, Appendix A, Rev 0042 pages 9 to be provided: and 10 with Notes removed from page 10 Learning Objective: 3-OT-SYSO57P
- 11. State the 1 25V DC Vital system parameters governed by TS Cognitive Level:
Higher X Lower Question Source:
New X Modified Bank Bank Question History: New question for the WBN 10/2011 NRC exam Comments:
Page 130
WBN Weekly Log 0-Sl-0-3 UnitO Rev. 0042 Page 20 of 43 Appendix A (Page 9 of 24)
SR3.8.4.3 SR S .5 I SR 3.8.7.1 SR 3.8.8.1 480V SD BD 2B2-B 480V SD BD 2A1-A SR 3.8.9.1 SR 3.8.10.1 (4 NC (bA)
X- CLOSED TRANSRARSINJCH Iv A- A)VJLSBLE I- U4OPERSEI.I O-PNL-236-4 O-SW-236-4:5W 4 80V AC VITAL
- DISCONNECT PNL CHANNEL IV (NC \
___ I 4.ITW-TE--(55V1 I FROM 0-SW -2361 S)V3 f \ (NC)
I 0.XSW-236-790C2-S, OUTPUT 2 (NC) .1 25V DC TRANSFER SWITCH 125VTAL SELECT CHARGERS 7-SINS z TB!
IS-CHGR-2364 (12SVVEALBATTERY BATT IV NOTE 2
/ Nc CHARGER IV oSW230Ll sW5 (NC)
ICHG vi I (NC) I 1 ltN (t joq 22)
NC) NyJ (SC) (Nfl) 125V VITAL I BATTBDIV 301 I \ N6 I (NC) (NC)
F 1-BICL-235-1C5301 O-BIDC-235-4CBWI ( t 1-BE.R-23V-.1CBVOI I (NC)
(NC) (NO)
E-BIC)C-233--!CB4 2-BEG1-23)-4CEI I-BER-23)-4.CEI (NC) (NO) I I I I I - i I-E0-T.-23)--4-cIN2 (NC)
O-BER-23-CB2 I 2-SI-23)--(CE2 J
i-XSW-235-4 125 VAC VITAL 2-CS W-205-4 125 VAC VITAL ALT 1 NOR NOTE TOWER SD -IV TRANSFER aS -I- - NOTE PCWER 50 2-10 NC )
1 C 12lL TRANSFER NC 2-SW-23S- 120 Vac VITAL EOSTR POWER ED 2-IVOISC 1-ED 235-4 723 Vac VITAL 2-ED 235-4 120 Vac VITAL NOTE POWER BDARD 1-V .NSTE POWER SOAND 2-IV NOTE (1) In Modes 5&6 c*-Ily one train of ac/dc PWR is reasired, if this train is not reauired this oace may be N/A.
(2) Whei 7-S or 9-S charger is connected to BaIt Bd then verify assoc. train Transf Switches are closed and Alt bkrs are cpen.
INITIALS OF DATA COLLECTOR: DATE REMARKS:
WBN Weekly Log 0-Sl-0-3 Unit 0 Rev. 0045 Page 21 of 43 Appendix A (Page 10 of 24)
I SR 38.9.1 i480VAux Bldg Corn MCC C SR3.8.10.1 I I 0-BKR-236-5 CBI NCI I l25VVitChgrV 125V VITAL BAHV CB2 1;SVvTAL NC Seenote2 I (101) 8ATTBDV (102)
NO NO,,
NO NO I NO A (301) (302) i (401) NO (402) zzzzzz--- I I I I I I I I I I I I I I I I I I I I
- I I I
- NO NO I N 01 I NO, (1/0) (3/0) , (2/0) , (4/0),
__I I I I__
0-OPL-236-1 00PL-2363 0-DPL-236-2 0-DPL-2364 125V VITAL 125V VITAL 125V VITAL 125V VITAL BATT BD I BATT 80111 BATT BOIl BATT ED IV CLOSED NOTE 1: Only one battery board may be feed from the 5th baoery board at any onetime. AVAILABLE NOTE 2: 0-BKR-236-5/102 mont be OPEN when 5th battery is inservice for batlery bd I, II, III, or IV (j INOPERABLE INITIALS OF DATA COLLECTOR: DATE REMARKS:
WBN Weekly Log 0-SI-0-3 Unit 0 Rev. 0045 Page 20 of 43 Appendix A (Page 9 of 24)
- SR 5 S 5 1 SR 3.8.7.1 SR 3.8.8.1 SR 3.8.9.1 NO (1OA)
SR 3.8.10.1 70- CLOSED IV A- AVAILNEL!
I- 3/OPERABLE 0-PNL-2354 4BOV AC VITAL DISCONNECT PNL CH4GNEL IV O-R)V.2I6l3/V1 FROM I O-SW-236--lS\V3 (NC) D-XSW-236-79DC2S. OUTPUT 2 (INC 25V DC TRANSFERSWITCH I
125V VITAL SELECT CHARGERS 73/95 BATT IV NOTE 2 1-B1)L-1S4CE3OI (NC)
O-S(I0R-23-4CEI (NC) 2-BKR-237-4C52 I-BSW-232-4CB2 (NC)
(NC) 1-XSW-235-h 125 VAC VITAL REIN POWER :N5R (:_____7!;;:
ALT 2-CS W-205-4 120 SAC VITAL 3/SIR POWER ALT f j 1 NOR SO)
SD i-IS TRASFER -j- J SD 2-IS I-SW-205-4 120 SAC VITA.. TRANSFER 2-SW-235-4 120 Vac VIrAL NC 545170 POWER 57)1-3/DISC NC REIN POWER BC 2-3/DISC 7-BD23S4120Vac VITAL 2-RD 225-4 120 Vac VITAL INSIR POWER BOARD 1-IV INSIR POWER BOARD 2-V NOTE (1) In Modes 5&6 otly one train of ac/dc PWR is recuired. if this train is not recuired this pace may be N/A.
(2) When 7-S or 9-S charger is connected to Batt Sd th n rify assoc. train Transfer Swftches are closed and Alt bkrs are cpen.
INITIALS OF DATA COLLECTOR: DATE REMARKS:
V
WBN Weekly Log 0-Sl-0-3 Unit 0 Rev. 0045 Page 21 of 43 Appendix A (Page 10 of 24)
SR 38.9.1 NC I 480V Aux Bldg Corn MCC C SR 3.8.10.1 I,.. I 0-BKR-236-5 I CB1 Nd
, I 125V Vii Chgr V 125V VITAL BATTV I CB2 1 I
I c
-I NC 125V VITAL NC See note 2 I I 101 BATrBDV (102) I NO NO i (201) (202)
I I 125V DC 01ST PNL 5A 125V DC 01ST PNL 58 A NO NO AND I (301) (302) (401) NO (402)
I I I I I I I I I I I I I I I I A I I I A I I I I I NO NO NO, I NO,
, (2/0), i (4/0),
(1/0) (3/0)
I I I I I I I I 0-DPL-230-1 0-DPL-236-3 0-DPL-236-2 0-DPL-236-4 125V VITAL 125V VITAL 125V VITAL 125V VITAL BATT 801 BATT ED Ill BArr 8011 BATT 80 IV CLOSED NOTE 1: Only oae batt board may be feed Ir the 5th ball board at any one Orne. AVAIBLE NOTE 2: 0-BKR-236-5/102 rnust be OPEN when 5th battery in innervce for ballery bd I, II, III, er IV (j) INOPERABLE INITIALS OF DATA COLLECTOR: DATE REMARKS: 7/
V
I nverters-Operating 3.8.7 SURVEILLANCE REQUIREMENTS SURVEILLANCE FREQUENCY SR 3.8.7.1 Verify correct inverter voltage, frequency, and 7 days alignment to required AC vital bus and from associated vital battery board and 480 V shutdown board.
Watts Bar-Unit 1 3.8-38
3-OT-SYSO57P Rev 12 Page 5 of 106 pages I. PROGRAM: WATTS BAR OPERATOR TRAINING II. COURSE:
A. NOTP B. LICENSED REQUALIFICATION C. NAUO REQUALIFICATION D. ILT Ill. TITLE:
PLANT DC SYSTEMS IV. LENGTH OF LESSON:
A. NOTP 2.0 HOURS B. LICENSE REQUALIFICATION 2.0 HOURS C. NAUO REQUALIFICATION 2.0 HOURS D. ILT 2.0 HOURS V. TRAINING OBJECTIVES:
- 1. Describe the 1 25v Vital, 250v, 48v and 24v battery systems in terms of the following:
- a. Purpose
- b. Number and location of batteries
- c. Deleted
- d. Location and normal and alternate supplies to associated battery chargers.
- e. Number and location of battery boards.
- f. Normal and alternate supplies to battery boards.
- g. Typical feeds from battery boards.
- 2. Describe the separation of the 1 25v Vital DC System into channels, including numbering, colors and to which unit they generally supply.
- 3. Identify which plant batteries are grounded.
- 4. Deleted.
- 5. Describe or draw the single line for the 1 25v Vital DC System.
3-OT-SYSO57P Rev 12 Page 6 of 106 pages V. TRAINING OBJECTIVES: (continued)
- 6. Explain how the operator can tell if the 125v Vital Charger or the 1 25v Vital Battery is supplying power to the 1 25v Vital Battery Boards.
- 7. Explain why the BC reset switch (located at the 6.9kv SD logic panel) must be held in RESET until the affected 6.9kv SD DC Bus is energized.
- 8. Identify the failure position (open, closed, or as is) of a 6.9kv or 480V Shutdown Board breaker upon loss of control power to that board.
- 9. Describe the status of the breaker indication lights for equipment fed from 6.9kv or 480V Shutdown Boards when control power is lost to the boards.
- 10. Given the condition/status of the 125V DC Vital system/component and the appropriate sections of Tech Specs, determine if operability requirements are met and what actions, if any, are required.
- 11. State the 1 25V DC Vital system parameters governed by TS.
- 12. Describe or draw the single line of the 250v DC System.
- 13. Explain how the 250v DC Turbine Bldg Distribution Boards auto transfers on undervoltage.
- 14. Deleted.
- 15. Deleted.
3-OT-SYSO57P Rev 12 Page 7 of 106 pages V. TRAINING OBJECTIVES: (continued)
AR S S U OR T 0 CA x X X 16. Correctly locate control room controls and indications associated with the 1 25v DC Vital system, including:
- a. Alarms
- b. Voltmeters
- c. Ammeters x xx 17. Describe the in-plant location of:
- a. 1 25v Vital Batteries
- b. 125v Vital Battery Boards
- c. 1 25v DIG Batteries
- d. 250v Batteries
- e. 250v Battery Boards
- f. 250v Turbine Bldg Distribution Bds
- g. 125v Vital Battery Chargers
- h. 125v Vital Inverters
- i. 48v Telephone Battery
- j. 48vPlantBattery
- k. 24v CAP Battery
OPERATIONS 3-OT-STG-057P PLANT DC SYSTEMS REVISION 3 STUDENT TRAINING GUIDE PAGE 10 OF 52 TRAINING OBJECTIVES
- 1. Describe the 125v Vital, 250v, 48v and 24v battery systems in terms of the following:
- a. Purpose
- b. Number and location of batteries
- c. Deleted
- d. Location and normal and alternate supplies to associated battery chargers.
- e. Number and location of battery boards.
- f. Normal and alternate supplies to battery boards.
- g. Typical feeds from battery boards.
- 2. Describe the separation of the 1 25v Vital DC System into channels, including numbering, colors and to which unit they generally supply.
- 3. Identify which plant batteries are grounded.
- 4. Deleted.
- 5. Describe or draw the single line for the 1 25v Vital DC System.
- 6. Explain how the operator can tell if the 1 25v Vital Charger or the 1 25v Vital Battery is supplying power to the 1 25v Vital Battery Boards.
- 7. Explain why the BC reset switch (located at the 6.9kv SD logic panel) must be held in RESET until the affected 6.9kv SD DC Bus is energized.
OPERATIONS 3-OT-STG-057P A PLANT DC SYSTEMS REVISION 3 STUDENT TRAINING GUIDE PAGE 11 OF 52 AR S S U OR T C CA X X X X 8. Identify the failure position (open, closed, or as is) of a 6.9kv or 480V Shutdown Board breaker upon loss of control power to that board.
X X X X 9. Describe the status of the breaker indication lights for equipment fed from 6.9kv or 480V Shutdown Boards when control power is lost to the boards.
X X 10. Given the condition/status of the 1 25V DC Vital system/component and the appropriate sections of Tech Specs, determine if operability requirements are met and what actions, if any, are required.
X X X X 11. State the 125V DC Vital system parameters governed by TS.
X X X X 12. Describe or draw the single line of the 250v DC System.
X X X X 13. Explain how the 250v DC Turbine Bldg Distribution Boards auto transfers on undervoltage.
- 14. Deleted.
X X X X 15. Deleted.
X X X 16. Correctly locate control room controls and indications associated with the 125v DC Vital system, including:
- a. Alarms
- b. Voltmeters
- c. Ammeters
OPERATIONS 3-OT-STG-057P PLANT DC SYSTEMS REVISION 3 STUDENT TRAINING GUIDE PAGE 12 OF 52 AR S S U OR T 0 CA X X X X 17. Describe the in-plant location of:
- 1. 1 25v Vital Batteries
- 2. 1 25v Vital Battery Boards
- 3. 1 25v DIG Batteries
- 4. 250v Batteries
- 5. 250v Battery Boards
- 6. 250v Turbine Bldg Distribution Bds
- 7. 125v Vital Battery Chargers
- 8. 1 25v Vital lnverters
- 9. 48v Telephone Battery
- 10. 48v Plant Battery
- 11. 24vCAP Battery
OPERATIONS 3-OT-STG-057P PLANT DC SYSTEMS REVISION 3 STUDENT TRAINING GUIDE PAGE 20 OF 52 Charger V also has an equalize timer which must be set to the desired time before the FLOAT I EQUALIZE switch is placed in EQUALIZE. When the timer times out, the charger will automatically revert to float operation. Charger V operating voltages are also slightly different (refer to SOl-236.05), with a float voltage of 1 38.5-Vdc and an equalize voltage of 144.5-Vdc.
Charger V is not safety related and is not in service when battery V is substituted for one of the four channel batteries.
Normally one of the spare chargers will be connected to battery V in this instance. The normal charger will be connected to the normal battery, but can be connected to battery V, if desired.
Table 1 - 125 VDC Vital Battery Charger Power Objective 1 .d, 2 48OVSD RED 6-S and 8-S Bd1B1-B 48OVSD 7-S and 9-S Ill 31-B
) 48OVSD LACK 6-S and 8-S II Bd 1A1-A 48OVSD 480V5D 7-S and 9-S IV Bd 2B2-B Bd 2A1-A SPARE CHARGER 480V RX 480V Rx NA N/A 6-S and 8-S MOV Bd MOV Bd 1A2-A 1B2-B
OPERATIONS 3-OT-STG-057P j PLANT DC SYSTEMS REVISION 3 STUDENT TRAINING GUIDE PAGE 18 OF 52 loads for 4 hours4.62963e-5 days <br />0.00111 hours <br />6.613757e-6 weeks <br />1.522e-6 months <br />, with a loss of all AC power, while maintaining a minimum terminal voltage of 105V DC. The minimum terminal voltage during the first minute is 113V DC. As the state of charge degrades, the terminal voltage will decrease more rapidly and at a voltage < 105 VDC but well before 0 VDC cells will reverse and the battery will fail.
Battery V may be electrically connected to substitute for one of the other batteries and the channel will be considered OPERABLE if the battery surveillances are current for battery V.
Vital Battery V is comprised of 62 lead calcium cells manufactured by Allied C&D Power systems. It is rated at 2320 ampere hours over an 8 hour9.259259e-5 days <br />0.00222 hours <br />1.322751e-5 weeks <br />3.044e-6 months <br /> period.
Each Battery room is equipped with its own ventilation and heating system, maintaining room temperature between 60°F and 104°F. The forced air movement also purges the room of 2 gas released from the batteries while charging.
H 2.1.12 Vital Battery Chargers Objective 1 .d, 17 Each battery has its own independent charger located on Elevation 772 in the Aux Building. Each is provided with both a Normal and an Alternate AC power supply. The charger is only considered OPERABLE when it is aligned to the normal supply.
Each unit also has two spare battery chargers that may be aligned to either train battery for that unit. So long as it is connected to the same train AC source, the battery subsystem is OPERABLE using the spare charger. The Unit 1 chargers are designated 6-S and 8-S the unit 2 chargers are 7-S and 9-S
OPERATIONS 3-OT-STG-057P j PLANT DC SYSTEMS REVISION 3 STUDENT TRAINING GUIDE PAGE 19 OF 52 The chargers can perform both normal float charging and higher voltage equalize charging of the battery. During float operation the charger output voltage is 133 137 VDC, and during equalize it is 138140 VDC. The FLOAT! EQUALIZE push button on the charger selects the mode of operation.
Figure 1 - Typical for Spare Chargers 6-S, 7-S, 8-S and 9-S
WBN 10-2011 NRC RO Exam As Submitted 8115/2011
- 50. 063 1(3.02 050 Given the following
- Unit I was operating at 100% power when a safety injection occurred.
- Eighteen (18) seconds after Safety Injection, a loss of 125v Vital DC Power Channel II occurs.
Which ONE of the following identifies the current status of RHR pump I B-B?
A. RHR pump I B-B is NOT running but can be started from the MCR handswitch.
B. RHR pump lB-B is NOT running and can NOT be started from the MCR handswitch.
C. RHR pump 1 B-B is running and can be stopped from the MCR handswitch.
D RHR pump 1 B-B is running but can NOT be stopped from the MCR handswitch.
DISTRA CTOR ANALYSIS:
A. Incorrect, Plausible if the time delays associated with the pump starting with a blackout present are used. The delay times would exceed the 18 seconds (DG Start and RHR blackout time delay relay) and there are 3 other Vital DC boards available to supply the control power. One of which does supply the breaker but it is a manual transfer, not an automatic transfer.
B. Incorrect, Plausible since RHR pump IA-A cannot be started or stopped from the control room handswitch after the loss of 125v DC Vital channel II and because if a blackout signal had been concurrent with the SI condition, then the DG start time and pump start delay time would have exceeded the time prior to the loss of the control power.
C. lncorrect, Plausible because the pump being running is correct and there are 3 other channels of 125v DC available that could have been determined to be the control power supply for the pumpá breaker.
D. Correct, RHR pump IA-A would have started immediately when the Safety injection was initiated but after the 125v DC Channel II power was losi, the pump could not be stopped from its handswitch in the main control room.
Question Number: 50 Page 131
WBN 10-2011 NRC RO Exam As Submitted 8115/2011 Tier: 2 Group 1 K/A: 063 K3.02 D.C. Electrical Distribution Knowledge of the effect that a loss or malfunction of the DC electrical system will have on the following:
Components using DC control power Importance Rating: 3.5 / 3.7 10 CFR Part 55: 41.7/45.6 IOCFR55.43.b: Not applicable KIA Match: K/A is matched because the question requires the applicant to know a major breaker supplied with control power from I 25v DC Vital Channel II and how a loss of the power supply to the control power affects the ability to start and stop the component.
Technical
Reference:
AOl-21 .02, Loss of DC Vital Battery Bd II, Revision 0021 1 -45W724-2 R24 1-45W760-74-1 R12 Proposed references None to be provided:
Learning Objective: 3-OT-SYSO57A
- 8. Identify the failure position (open, closed, or as is) of a 6.9kv or 480v Shutdown Board breaker upon loss of control power to that board.
Cognitive Level:
Higher X Lower Question Source:
New Modified Bank X Bank Question History: Surry bank question 063 K3.02 used during 10-2009.
Modified for use at WBN. Changes in the stem made a different answer correct.
Comments:
Page 132
WBN Loss of 125V DC Vital Battery Bd II AOl-21.02
- Unit I Rev 0021 1.0 PURPOSE This instruction provides actions to respond to a loss of 1 25V DC Vital Battery Board II. The instruction will stabilize the unit following a Rx trip It also provides a list of major equipment which may be affected.
2.0 SYMPTOMS 2.1 Alarms A. 125 DC VITAL CHGRIBATT II ABNORMAL [18-A].
B. 125 DC VITAL BATT BD II ABNORMAL [18-B].
C. 6.9 SD BD lB-B UV/OV/CONTROL PWR FAILURE [13-B].
D. 480 SD BD 1BI-BI1B2-B FAILURE/ABN [11-D].
E. C & SS AIR COMPR SEQUENCER UNDERVOLTAGE [42-El.
F. TURB RUNBACK SYS CNTL PWR UNDERVOLTAGE [27-El.
G. 6.9 KV SWGR D CONTROL PWR UV [504-C].
2.2 Indications A. Voltmeter (1-El-57-96) when 1-XS-57-96 is selected to Bd II and ammeter (1-El-57-93) for 125V Battery Bd II, on 1-M-1, indicates ZERO.
B. Breaker indicating lights for equipment feeding from 6.9kV SD BD 1 B-B and 480V SD BDs IBI-B/1B2-B will be dark (ACB5 electrically inoperable).
Page 3 of 25
WBN Loss of 125V DC Vital Battery Bd II AOl-21.02
- Unit I Rev. 0021 4.0 DISCUSSION 125V DC Vital Battery Board II supplies the following feeds to the listed control buses:
6.9KV Shutdown Board lB-B normal feed to the NORMAL bus alternate feed to the EMERGENCY bus; 480V Shutdov,,n Boards 1BI-B and 1B2-B normal feed to the NORMAL bus alternate feed to the EMERGENCY bus; 6.9KV Shutdown Board 2B-B alternate feed to the NORMAL bus normal feed to the EMERGENCY bus; 480V Shutdown Boards 2B1-B and 2B2-B alternate feed to the NORMAL bus normal feed to the EMERGENCY bus.
In general, 125V DC Vital Battery Board II supplies power for Unit I Train B equipment. The loss of control power causes breakers on the affected boards (normally Unit I ,Train B 6.9kV and 480V SD Boards) to fail as is. As a result, it will be necessary to use alternate control power if breaker operation is needed. Also, the loss of power to solenoid valves will cause Main Feedwater and Main Steam to be terminated and the Reactor will trip.
Safe shutdown is maintained with all four S/G PORVs and AFW System (Turbine driven pump will feed all 4 S/Gs, IA-A MDAFW Pump will feed S/Gs I & 2 only; also loop 2 S/G PORV will lose indication lights and auto opening on high rate of pressure rise but modulation control with PlC will still be operable). Cooldown control from less than 350°F to cold shutdown is via the Residual Heat Removal System.
Page 14 of 25
$u9Q -rio,v References Provided to Alplicant none Answer: D
- 49. 0063 K3.02 2 A loss of A DC Bus occurs followed by a Safety Injection. Which ONE of the following is correct regarding the operation of 1-SI-P-IA (A Low Head Safety Injection Pump)?
A. 1-SI-P-IA is NOT running but can be started from the MCR.
B. 1-SI-P-lA is NOT running and can NOT be started from the MCR.
C. 1-SI-P-lA is running and can be stopped from the MCR.
D. 1-SI-P-lA is running but can NOT be stopped from the MCR.
K/A DC Electrical Distribution.
Knowledge of the effect that a loss or malfunction of the DC Electrical System will have on the following: Components using DC control power.
K/A Match Analysis Requires the applicant to know the major breakers supplied control power from 1A DC Bus.
Answer Choice Analysis A. In-Correct but plausible since the A LHSI pump will not be running. It cannot be started from the MCR. Plausible if the candidate believes that all 480 V components utilize internal power for control power and forgets that LCC 480V components utilize DC power.
B. Correct C. In-Correct but plausible see distactor A.
D. In-Correct but plausible if the candidate believes that since the charging springs are charged and one breaker operation is normally permitted the breaker will close, but the loss of DC power will prevent opening the breaker.
Supporting References ND-90.3-LP-6, 125 VDC Distribution, Rev. 018, Obj. D References Provided to Applicant none
3-OT-SYSO57P Rev 12 Page 5 of 106 pages PROGRAM: WATTS BAR OPERATOR TRAINING COURSE:
A. NOTP B. LICENSED REQUALIFICATION C. NAUO REQUALIFICATION D. ILT Ill. TITLE:
PLANT DC SYSTEMS IV. LENGTH OF LESSON:
A. NOTP 2.0 HOURS B. LICENSE REQUALIFICATION 2.0 HOURS C. NAUO REQUALIFICATION 2.0 HOURS D. ILT 2.0 HOURS V. TRAINING OBJECTIVES:
A R S S U 0 R T 0 0 A x xx 1. Describe the 1 25v Vital, 250v, 48v and 24v battery systems in terms of the following:
- a. Purpose
- b. Number and location of batteries
- c. Deleted
- d. Location and normal and alternate supplies to associated battery chargers.
- e. Number and location of battery boards.
- f. Normal and alternate supplies to battery boards.
- g. Typical feeds from battery boards.
X X X X 2. Describe the separation of the 125v Vital DC System into channels, including numbering, colors and to which unit they generally supply.
X X X X 3. Identify which plant batteries are grounded.
- 4. Deleted.
x I x X 5 Describe or draw the single line for the 1 25v Vital DC System
3-OT-SYSO57P Rev 12 Page 6 of 106 pages V. TRAINING OBJECTIVES: (continued)
AR S S U OR T 0 0 A X X X 6. Explain how the operator can tell if the 125v Vital Charger or the 1 25v Vital Battery is supplying power to the 1 25v Vital Battery Boards.
X X X X 7. Explain why the BC reset switch (located at the 6.9kv SD logic panel) must be held in RESET until the affected 6.9kv SD DC Bus is energized.
X X X X 8. Identify the failure position (open, closed, or as is) of a 6.9kv or 480V Shutdown Board breaker upon loss of control power to that board.
X X X X 9. Describe the status of the breaker indication lights for equipment fed from 6.9kv or 480V Shutdown Boards when control power is lost to the boards.
X X 10. Given the condition/status of the 1 25V DC Vital system/component and the appropriate sections of Tech Specs, determine if operability requirements are met and what actions, if any, are required.
X X X X 11. State the 1 25V DC Vital system parameters governed by TS.
X X X X 12. Describe or draw the single line of the 250v DC System.
X X X X 13. Explain how the 250v DC Turbine Bldg Distribution Boards auto transfers on undervoltage.
- 14. Deleted.
- 15. Deleted.