Startup / Shutdown

Question 1

1. During a reactor startup why do we commence shell warming at 60 psig?

Answer 1

To reduce the potential for the Turbine to roll off the Turning Gear, shell warming should begin as close to 60 psig Reactor pressure as possible.
OP-21 P&L-13

Question 2

2. With shell warming in progress the procedure provides guidance for removing turbine lift pumps. Why would we need to remove lift pumps from service and how many total can be removed from service during turbine shell warming?

Answer 2

Remove pumps from service to prevent turbine from rolling off the turning gear. Should not exceed 50RPM. May shutdown 6 of 8 lift pumps, must maintain lift pumps for bearings 9 and 10 (P6G/H - Generator Bearings) running.
OP-21 page 22

Question 3

3. While performing a turbine startup, OP-21 provides directions to trip the turbine under certain turbine conditions. In addition to listing the requirements for tripping the turbine on vibration, list 3 other items that require a turbine trip during startup in accordance with OP-21?

Answer 3

~CAUTION~
If water induction is evident while Turbine is accelerating, Turbine must immediately be tripped and placed on turning gear to prevent or minimize damage to the Main Turbine.
IF any of the following occur WHILE bringing the Turbine to speed, THEN immediately trip Turbine per N2 SOP 21, Turbine Trip [C4].
• Signs of water induction into Main Turbine
~NOTE~
Turbine Bearing Vibration indications shall be confirmed using adjacent bearing(s) indication, bearing temperature indication, (etc. 2CEC-PNL842 and computer points indications) or local investigation.
• Any confirmed Turbine Bearing Vibration greater than 9 mils with greater than 3 mils/minute rate of change
• IF any confirmed Bearing Vibration is greater than or equal to 12 mils WITH two consecutive readings on recorder 2TMI NBR134.
• Any confirmed Turbine Bearing Vibration greater than or equal to 10 mils for 15 minutes
• Smoke OR fire associated with Main Turbine OR Generator/Exciter
• Other unusual conditions as directed by SM/CRS
OP-21 E.5.15

Question 4

4. What is the heatup rate limit when warming up the cross around piping during shell warming?

Answer 4

To reduce metal thermal stresses and potential rubbing due to uneven component expansions during activities such as shell warming and changes in load, High Pressure Turbine Shell Temperature changes should have a target rate of less than 125°F/Hr and are limited to a rate of 150°F/Hr, or about 40°F every 15 minutes.
P&L 22

Question 5

5. When is chest warming required to be performed during a turbine startup?

Answer 5

~NOTE~
Chest warming is required if Control Valve Inner Temperature is less than 500°F (Computer Point TMITA02 or Recorder 2TMI TR137/ZDR135, Point 6).
OP-21 E.4

Question 6

6. What is the high pressure turbine shell temperature requirement to support startup of the turbine?

Answer 6

OP-21 E.5.3.2 High Pressure Turbine Shell Inner Temperature is greater than 250°F.

Question 7

7. During turbine rollup to rated speed at what speed range would you expect to experience the highest vibration levels?

Answer 7

~NOTE~
• Personnel performing this procedure should be familiar with expected Turbine startup vibration. Vibration should peak during Rotor Critical Speeds (about 900 to 1300 rpm).
• No automatic turbine trip exists on high vibration.
OP-21 above E.5.4

Question 8

8. SRO Only – While preparing to take the mode switch to startup OP-101A requires verification of all Mode 2 surveillance requirements being up to date, list 4 things that you would check to ensure that Mode 2 surveillance were current?

Answer 8

• CR Logs
• ESL
• Clearance Module
• PMST
• NewCap
  iaw The Scag

Question 9

9. At what point in the reactor startup are we required to go to single notch withdrawal of control rods? (List at least 4)

Answer 9

Single notch control rod movement shall be performed from notch positions 00 to 36: [C19]
− At the direction of the Reactor Engineer if Estimated Critical Range (ECR) is PRIOR to Rod Worth Minimizer (RWM) rod group 3.
− IF 3 count rate doublings are approached on at least 2 SRMs PRIOR to RWM rod group 3.
− Starting with RWM rod group 3 UNTIL criticality is achieved.
− For RWM rod groups 3 AND 4 AFTER the reactor is critical, unless otherwise directed by Reactor Engineer.
OP-101A att 1.D.1

Question 10

10. Match the approximate rod worth to the list rod position.

a. 00-04
b. 04-08
c. 08-12
d. 12-16
e. 16-24
f. 24-48

1. Highest
2. Low
3. Minimal
4. High

Answer 10

Position Worth

00-04	Low
04-08	High
08-12	Highest
12-16	High
16-24	Low
24-48	Minimal

OP-101A att 1.D.2

Question 11

11. Who is responsible to determine what systems will be required to have valve / electrical lineups performed on prior to performing a plant startup?

Answer 11

The General Supervisor Operations (or designee) shall identify those systems for which a system lineup is NOT required. This decision will be based on the extent of work performed on the system during the outage and the safety significance of the system.
OP-101A Att 3

Question 12

12. What are the requirements for performing rod exercising prior to startup if the shutdown was the result of a reactor scram?

Answer 12

1. Insert Flush until Stall Flow Stabilizes.
2. Continuous Withdraw to 48*
3. Withdraw Flush Until Stall Flow Stabilizes
4. Full Stroke Time Any Rods with Insert Stall Flows > 3.5 gpm and adjust fast control rods Estimated Time = 30-36 hours
   OP-AB-300-1005 Attachment 2

Question 13

13. How many days prior to startup should the Off-Gas Recombiner heat trace be placed in service?

Answer 13

Commence Off Gas recombiner heat trace warming per N2 OP 42 at least three days PRIOR to planned start up of Off Gas System.
OP-101A Attachment 3.D.5

Question 14

15. SRO – A plant startup is in progress following an outage which required work on the Reactor Core Isolation Cooling System. Per the startup schedule N2-OSP-ICS-Q@002 is a required PMT for the work performed. When during the startup does the 12 hour clock start to complete the surveillance test?

Answer 14

Can NOT exceed 150psig before performing N2 OSP ICS Q@002 for SR3.5.3.4 (OP-101A E.2.37)

~NOTE~
When reactor pressure exceeds 935 psig with 1 turbine bypass valve full open and N2 OSP ICS Q@002 is required, a 12 hour clock for test performance will start. (SR 3.5.3.3)
OP-101A above E.3.18

Question 15

16. During power ascension we place condensate demineralizers in service as needed to maintain condensate demineralizer flow between what values?

Answer 15

~NOTE~
Eight demineralizers are required for 100% power. Nine demineralizers are preferred for additional operational margin.

Place Condensate Demineralizers in service as required in order recommended by Chemistry AND maintain individual demineralizer flows between 2000 AND 3300 gpm (3500gpm MAX) AND a system delta P less than or equal to 55 psid (60 psid maximum).
OP-101A E.5.4

Question 16

17. SRO – Reactor Power exceeded 23% at 1300 today, when must the Jet Pump Operability surveillance test be completed by?

Answer 16

Within 24 hours AFTER exceeding 23% of RATED THERMAL POWER, perform N2 OSP LOG D001, Daily Checks, Jet Pump Operability. (TS 3.4.3)
OP-101A E.5.9.3

Question 17

18. Why do we transfer Feedwater Level Control to Single Element at ~ 25% power during a plant shutdown?

Answer 17

~Caution~
It is possible, following RCS pump downshift, that steam flow indication can drop low enough to cause difficulty with 3-element feedwater level control. Should this occur, G.1.26.1, “Placing feedwater level control in single element,” should be performed without delay following the downshift.

N2-OP-101C Section G (pg. 18 of 92)

Question 18

19. Why are 3 Heater Drain Pumps required to reach full power?

Answer 18

HDL Pumps provide 1/3 of total condensate flow – may have trouble maintaining RPV Level at 100% without challenging the Condensate System with Runout.
Additionally iaw P&L 17 of OP-8, long term operation on the high level dumps could cause condenser damage.

Question 19

20. What actions are available to support control of reactor water level if the Feedwater LV10’s are suspected of having leakby?

Answer 19

~CAUTION~
Seat leakage problems have been experienced with the 2FWS LV10s in the past. After valve repair, the leakage is eradicated or minimized but will degrade as the valve wears. If leakage past the LV10s has been observed to be degrading, caution needs to be observed when opening 2FWS MOV47A, B, C valves. Leakage past the LV10s can cause level and associated power excursions, particularly at lower reactor pressures. [C3]

IF 2FWS LV10A(B) leak by is suspected,
THEN make 2FWS MOV47A(B) throttleable per H.3.0 of this procedure.

OP-3 E.3.43.1

Question 20

21. During a plant shutdown by individual control rod insertion a pressure control malfunction requires the use of SRVs to maintain the ordered pressure band, what actions are required by procedure for control of the reactor?

Answer 20

IF SRV opening is required to control rising Reactor Pressure, THEN exit this procedure AND enter N2 SOP 101C, Reactor Scram.
OP-101C G.4.19

Question 21

22. What portion of the reactor startup do we implement controls for Infrequently Performed Test or Evolutions? List 5 things that we do to manage the risk during the IPTE?

Answer 21

WHEN Reactor pressure reaches approximately 925 psig, THEN perform the following:
IPTE portion of plant startup is now complete. Log completion in Control Room Log.
OP-101A E.2.49

Question 22

23. While performing actions in SOP-101C pressure control leg, you are taking action to place the Mechanical Vacuum Pumps in service. How do you verify that there are no indications of fuel failure prior to starting the vacuum pumps?

Answer 22

Verify Main Steam Line Hi-Hi Rad Alarms are Clear

SOP-101C Discussion 5.8

Question 23

24. While preparing to commence a plant startup, why must we secure shutdown cooling before we can place the mode switch to startup and enter Mode 2?

Answer 23

Residual Heat Removal System removed from Shutdown Cooling mode AND operable for LPCI mode per N2 OP 31, Residual Heat Removal System

OP-101A E.1.16.1

All ECCS Must be Operable prior to Mode 2 Entry iaw Tech Spec
Additionally, you do not want anything other than Rods affecting reactivity during startup.

Question 24

25. While performing a reactor startup and heatup, drywell pressure rises to .5 psig. Describe the potential impact on inerting the containment and any required actions?

Answer 24

To prevent crossflow from the primary containment to the reactor building when using the 20” line to GTS, (2GTS*AOV101), the following plant parameters shall be maintained:
i. Primary containment pressure less than 0.41 psig.
ii. Reactor building pressure shall not be more negative than −1.0” water.
iii. Purge flow (air/nitrogen) shall be maintained less than GTS out flow.
OP-61A P&L 7

Question 25

26. While performing Shell Warming of the main turbine you note the 1st Stage Pressure is 100 psia and rising. If no operator actions are taken what is the most likely consequence?

Answer 25

~CAUTION~ • First Stage Pressure must remain <111 psia during shell warming to prevent a possible Reactor scram. Particular attention is required if shell warming is being performed in conjunction with raising Reactor Pressure. OP-21 above E.3.17 ~CAUTION~ During shell warming, exceeding 100 PSIA first stage pressure may result in a Reactor SCRAM. Particular attention is required if shell warming is being performed in conjunction with raising Reactor pressure. OP-101A above E.2.36 The concern is that you may unbypass the EOC-RPT (Turbine Trip) Scram

Question 26

27. While performing a reactor startup what is the power limit for having the condenser air removal pumps in service and what is the reason for that limit?

Answer 26

Do not operate the Mechanical Vacuum Pumps with Reactor Power greater than 5% as indicated on APRMs. The plant exhaust stack is not detonation proof and at powers greater than 5% it is possible for the hydrogen generation rate to produce explosive concentrations in the system. OP-9 P&L 2

Question 27

28. SRO – When performing a reactor startup from cold shutdown, when must RCIC be operable by?

Answer 27

N2-OP-101A E.2.37 • Prior to exceeding 150 psig and upon meeting RCIC initial test conditions. (SR 3.5.3.4) • When reactor pressure exceeds 935 psig with 1 turbine bypass valve full open and N2-OSP-ICS-Q@002 is required, a 12 hour clock for test performance will start. (SR 3.5.3.3)

Question 28

29. A plant startup is in progress and actions are in progress to start the first feedwater pump, what is the potential impact if only 4 condensate demineralizers are in service?

Answer 28

During normal operation, the Condensate Demineralizer system is limited to: [C1] • Differential Pressure of ≤ 55 psid with maximum of ≤ 60 psid. • Flow less than 3300 gpm with a maximum not to exceed 3500 gpm • Effluent Conductivity of less than 0.08 micromhos • Design temperature 140°F OP-5 P&L 11 There is a possibility of high flow or DP on the condemins, or possibly low suction pressures on the running Feedpump or Booster Pumps

Question 29

30. SRO – During plant startup 15% power is achieved on 2/18 at 2230. What is the maximum allowable time to reduce containment O2 below 4%?

Answer 29

24 hours from 2/18 2230 (2/19 2230) concentration needs to be below 4% or you have 24 additional hours to restore concentration to <4% (i.e. 48hrs total).

Question 30

31. SRO – While performing a reactor shutdown by manual control rod insertion IRM’s “A” and “C” fail the overlap surveillance requirements. What are your required actions and how would you continue the plant shutdown?

Answer 30

IF any operable IRM in Step G.4.1.6 above is determined to be outside of required overlap limits, THEN notify Reactor Engineering to assess IRM indication. (Problem with control rod pattern OR valid IRM problem). IF control rod manipulations are required, THEN adjust control rod pattern using an approved Reactivity Maneuver Form. IF any operable IRM in Step G.4.1.6 above remains outside of required overlap limits, THEN notify SM AND take Action required by Tech Spec 3.3.1.1. If unsuccessful, one would be bypassed and declared INOP and the other would be declared INOP and you would have 12 hrs to trip the channel. N2-OP-101C Step G.4.1.7 - 4.1.9

Question 31

32. What is the required Operations Staffing for performing a reactor startup?

Answer 31

The General Supervisor Operations shall ensure that as a minimum, two additional Reactor Operators and one additional Senior Reactor Operator above the normal operating shift manning are available during reactor startup. [C19] OP-101A C.2

Question 32

33. While performing a reactor startup you withdrawal a control rod and receive an SRM Short Period alarm and observe reactor period stable at 55 seconds on all SRMs. What, if any are your required actions?

Answer 32

Establish a stable positive period between 100 AND 300 seconds using control rods as required. IF a positive period of less than 50 seconds is experienced, THEN perform the following: N/A, Period of less than 50 seconds has NOT been experienced • Insert the last control rod which was withdrawn to its previous position. • Notify the Control Room Supervisor. • Request further direction from Reactor Engineering N2-OP-101A E.2.20 and 2.21

Question 33

34. Why do we try to limit our heatup rate to ~ 40 degrees per hour between 0 and 150 psig?

Answer 33

~CAUTION~ Reactor heatup from approximately 200°F to 350°F (1 to 150 PSIG) may be limited by reject flow capacity. Failure to limit heatup to approximately 40°F/hour until Reactor Pressure greater than 150 PSIG could result in a high RPV level condition. Careful monitoring of RPV level at heatup rates greater than 40°F/hr is warranted. OP-101A above E.2.29

Question 34

35. Following a plant shutdown pressure control (cooldown rate) is high and action is required to stabilize pressure. List 5 actions that can be taken to reduce cooldown?

Answer 34

During Shutdown OP101C G.2.2.6 Transfer Reboiler Steam Supply from Main Steam to Auxiliary Boiler Steam per N2 OP 25, Subsection F.4.0. Post Shutdown / Scram OP101C During first hour following Reactor scram, maintain pressure greater than or equal to 410 psig to assure excessive cooldown is NOT occurring. -OP-101C G.3.3.2 At 2CEC*PNL603, reset scram using Scram Reset Switches AND verify eight RPS scram pilot valve solenoids white lights are illuminated. -OP-101C G.3.9 IF excessive cooldown occurs, THEN perform the following steps (the steps are listed in order of increasing impact. Actual order will be based on plant conditions AND rate of cooldown): [C1], [C2] 1.1.1 At 2CEC PNL824, verify closed the following Steam Line Drains (87s and 88s) 1.1.2 IF excessive cooldown continues to occur, THEN perform the following: a. PRIOR to startup of Mechanical Vacuum pump, verify NO indication of fuel damage by: • MSL rad monitors downscale. • 2OFG RE13A AND B rad levels are below the ALERT (yellow) alarm IF in service. b. Close 2ASS MOV152, Main Steam Supply to Steam Jet Air Ejector. c. Start Mechanical Vacuum pump per N2 OP 9, Subsection G.1.0. 1.1.3 IF excessive cooldown continues, THEN close 2ASS MOV148. 1.1.4 IF required (cooldown rate remains excessive), THEN close MSIVs (preferably the outboards, preferably SLOW Close). [C4] -OP-101C G.3.20

Question 35

36. Why is it preferred to maintain cooldown rate less that 45 degrees per hour between 400 degrees and 200 degrees?

Answer 35

~NOTE~ • Industry experience has shows that a reduced cooldown rate (less than 45°F/hr) between 400°F and 200°F can significantly reduce the magnitude of a crud burst. To reduce the resultant radiological impact, cooldown should be minimized during shutdown for refueling outages. OP-101C above 3.24.17

Question 36

37. Why do we typically raise water level to a band of 227 inches to 243 inches when the plant is shutdown. What RPV level instrument is used to maintain this band?

Answer 36

~NOTE~ • Raising Reactor water level to the band of 227 to 243" will support natural circulation if Reactor Recirculation Pumps are secured or will be secured. • In addition, the level and temperature transient when Shutdown Cooling is initiated will be minimized. • Industry best practices for vessel flood up have employed a slow fill method for the reactor vessel at the beginning of refuel outages which is effective in reducing Cobalt 60 peak crud burst by approximately 35 percent. • In the following steps, the RPV water level will be raised by adjusting Reject flow, RDS and Condensate/Feedwater. • RPV level should rise approximately 1 inch every two to three minutes to equate to approximately 80 gpm. As directed by SM, begin to raise reactor water Level to target band of 227 to 243" on Shutdown Range Level Indicator. OP-101C G.3.24.18

Question 37

38. During a plant shutdown Reactor Water Cleanup is aligned to return to a single feedwater header when can we restore to return to both feedwater headers?

Answer 37

~NOTE~ • During plant shutdown when restoring WCS flow to Normal with the Reactor Water above 200°F, previous experience shows that flashing may occur in the WCS Delta flow Transmitters resulting in a High Delta Flow timer actuation and alarm. This actuation cleared in about 10 seconds. • This subsection is performed when reactor water temperature has been reduced to less than 325°F or when reactor power has exceeded 20%. OP-37 F.7 When Reactor Water Temperature is greater than or equal to 325°F and Reactor Power is less than 20%, WCS shall be operated with a minimum flow to one thermal tee (2WCS*MOV404A OR B) of 600 gpm nominal flow for one or two pump operation or Full Reject for one pump operation, except as required to support N2-EOP-6, Attachment 19. OP-37 P&L 5

Question 38

39. While performing a reactor shutdown by manually driving all control rods in why do we try to keep RPV pressure as stable as possible until all rods are fully inserted?

Answer 38

Prevents unnecessary changes in reactivity while we are shutting down, particularly, if lowering pressure due to the drop in temperature having the potential to bring the reactor critical again.

Question 39

40. While performing a plant shutdown what must rodline be less than in order to transfer Recirc pumps to slow speed?

Answer 39

WHEN Reactor power has been lowered to approximately 40% AND below 61% rodline, transfer Reactor Recirculation pumps to LFMG set per N2 OP 29, Subsection G.1.0. OP-101C G.1.17 Recirculation Pump upshift or pump start shall be performed between the 47% Rodline and the 58% Rodline. OP-101D D.1.4.

Question 40

41. At approximately what power level would you expect to receive 603112(412). RPS A(B) Control and Stop Valve Closure Bypassed alarms? What would be the impact if the alarms were NOT lit and the turbine was tripped.

Answer 40

At OR below 26% Rated Thermal Power, THEN verify the following: • Annunciator 603112 (603412), RPS A(B) CONT & STOP V CLOSURE BYPASSED alarm comes in. • Rod Block Monitor BYPASS (white) light lit on 2CEC*PNL603. OP-101C G.1.21 – If not bypassed, then a Reactor Scram will occur

Question 41

42. While making preparation to remove the main turbine from service we lower LOAD SET to achieve ½ - 1 ½ open on the turbine bypass valves, why?

Answer 41

- At main generator Load Selector controls, depress Load Selector DECREASE button AND slowly reduce generator load set to lower Main generator output UNTIL approximately ½ to 1½ Bypass Valves are open. - Verify Main Turbine Bypass valves are controlling Reactor pressure. OP-101C G.1.26 Prevents an excessive pressure transient when tripping turbine.

Question 42

43. What are the control rod verification requirements for perform a reactor shutdown by driving all the control rods fully into the core?

Answer 42

While performing a shutdown of the plant, an optional BPWS control rod sequence may be used provided that all fully withdrawn control rods have been confirmed to be coupled. The rods may be inserted without the need to stop at intermediate positions since the possibility of a Control Rod Drop Accident is eliminated by the confirmation that withdrawn control rods are coupled. When using this control rod insertion sequence for shutdown, the Rod Worth Minimizer may be reprogrammed to enforce the requirements of the improved control rod insertion process or bypassed per the allowance in the technical specifications. In order to use the improved BPWS shutdown process the control rods must be confirmed to be coupled by ensuring the control rod monthly exercising procedure is current for rods that are fully withdrawn or the control rod is fully inserted before going below the low power setpoint (LPSP) (approximately 10% power). OP-101C P&L34

Question 43

44. Why do we want to reset RPS as soon as possible after a reactor scram?

Answer 43

Limits the cooldown of the Reactor Vessel Bottom Head to prevent violation a cooldown rate of 100F/Hr by stopping flow from the charging header into the RPV

Question 44

45. List the actions to manually scram the reactor in order of preference as listed in SOP-101C.

Answer 44

* Reduce Recirc Flow to 55 mlbm/hr per N2-SOP-101D. * Place MODE Switch to SHUTDOWN position. * Arm AND depress BOTH Manual Scram pushbuttons on either side of 2CEC*PNL603. * Manually initiate RRCS.

Question 45

46. What is required to be done if any problems occur while moving control rods?

Answer 45

A CRD Deficiency Log entry should be made at any time during the performance of this procedure when a control rod drive mechanism does not perform as expected. OP-101A P&L 17

Question 46

47. How long must long cycle flush be established prior to startup?

Answer 46

Verify Condensate AND Feedwater System long cycle flush commenced at least twelve hours PRIOR to startup per N2 OP 3, Condensate and Feedwater System. OP-101A. -E.1.7

Question 47

48. During a starup, it is noted that there is a positive temperature coefficient and a heatup rate of 85F/Hr. What is required to be done?

Answer 47

A +MTC can be observed as a period that gradually becomes shorter after the initial criticality, without any further rod withdrawals. If a +MTC is observed, the period should be monitored such that IRM range changes remain controllable. Additionally, heatup rate should be monitored to remain less than 20F every 15 minutes. If period or heatup rate become excessive, single notch insertion may be used, backwards in the sequence, to maintain the reactor critical on a controllable period. [C18] OP-101A - D.2.9

Question 48

49. What is the maximum capacity of the CNM-LV137?

Answer 48

When controlling RPV water level using 2CNM LV137, steam loads and water level should be monitored to ensure capacity of 2CNM LV137 is not exceeded. The maximum capacity of 2CNM LV137 is achieved at about 75% valve position. [C1]

Question 49

50. What is performed during a startup just prior to 600psig? Why?

Answer 49

2. 49 PRIOR to RPV pressure exceeding 600 psig, perform the following: 2. 49.1 Reset HPCS Reactor high water level at Panel P601. 2. 49.2 Observe HPCS reactor high level seal in white light extinguishes. OP-101A - E.2.49 have to wait to reset due to the cal conditions of the wide range detectors.

Question 50

51. After bringing the reactor critical, what is the definition of subcritical?

Answer 50

After achieving criticality a delay in rod withdrawal during reactor heat up or other issues that add negative reactivity can result in the reactor becoming subcritical, as indicated by all of the following: 1. Before reaching the Point of Adding Heat (POAH) • Multiple SRM or IRM or WRNM readings continuously lowering without rod insertions 2. After reaching the Point of Adding Heat (POAH) • Multiple SRM or IRM or WRNM readings continuously lowering without rod insertions AND • Multiple IRMs or WRNM are at least 2 levels below the levels established at POAH OP-101A Attachment 12.

Question 51

52. What is required to be done if the reactor goes subcritical after criticality?

Answer 51

• IF the reactor goes subcritical, THEN insert control rods until only group 1 control rods are withdrawn and follow guidance in the “Sub-Criticality Flowchart” OP-101A Attachment 12.

Question 52

53. What is required if the reactor goes "Re-Critical"?

Answer 52

• IF Reactor goes RE CRITICAL un intentionally (Rx from a SUBCRITICAL condition to a CRITICAL condition) ~OR~ Rod insertion cannot overcome the positive reactivity insertion due to moderator temperature changes AND/OR Xenon changes due to low rod worth OR other equipment issue, THEN SCRAM the reactor

Question 53

54. Why is Control Rod Worth higher at a higher temp?

Answer 53

Moderator Temperature At higher temperatures, neutrons travel further in the slowing down process; AND therefore, have a greater probability of reaching AND being absorbed in a control rod. This results in increased control rod worth at higher temperatures. OP-101A Attachment 1

Question 54

14. At what vacuum should the turbine be tripped when less than 410MWE?

Answer 54

The Main Turbine should not be continuously operated with condenser vacuum less than the low vacuum alarm point (23.8 in. Hg). Turbine load should be reduced under deteriorated vacuum conditions in an attempt to restore vacuum. The Turbine should be manually tripped whenever Turbine load is less than 30% (410 MWe) and annunciator 851359 is in alarm with vacuum less than 24.6 in. Hg. OP101D D.1.6.

Question 55

55. Where is the Reactivity SRO required to be during the startup?

Answer 55

All reactivity changes shall be directly supervised by a Senior Reactor Operator. In order to provide this oversight, the SRO shall be stationed at the Controls Area of the Control Room. OP-101D D.1.12. Sounds Stupid, but this has made it onto past NRC Exams....

Question 56

56. Who is required to be present for planed power changes greater than 10%?

Answer 56

For planned power changes greater than or equal to 10%, General Supervisor oversight is required. OP-101D D.1.30.

Question 57

57. A Reactor startup is in almost complete. Power is currently 85% and being raised slowly. A condensate booster pump trips off. What would you expect to happen iaw OP-101D?

Answer 57

D.1.37. Failure to have 3 Condensate Booster Pumps (if not inhibited) and 2 Feedwater Pumps in service prior to steam flow exceeding 12.7 Mlbm per hour (approximately 72% power) will result in a Recirc Flow Control Valve Runback.

Question 58

58. What is the power limit of the Main Generator?

Answer 58

Rated generator output at 3988 MWth is 1369 MWe. However, variations in generator output above 1369 MWe are permitted provided generator operation remains within the generator capability curve of N2 OP 68. The 233 MVAR lagging reactive load limit is based on a generator real load of 1380 MWe OP-101D F.4 Note

Question 59

59. What is the Max operating hotwell temperature?

Answer 59

Maximum operating hotwell temperature is less than or equal to 140°F OP-101D F.4 Note

Question 60

60. How is rated power reached when raising power above 3966MWT?

Answer 60

When withdrawing control rods to raise power or rod line, the predicted power achieved with control rods shall be maintained less than 3966 MWth. The final approach to rated at 3966 MWth and above will be done with recirculation flow. This caution should not preclude the use of inserting rods to raise rod line at the end of cycle, “Reverse Power Effect”, for power maintenance. There should be a minimum of three minute wait prior to any further adjustments with Recirculation Flow. OP-101D F.4.2 Note