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Well Control Drilling Supervisory

 

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Well Control Drilling

Well Control Supervisory

The number of attempts remaining is 5

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1 / 80

1. You are circulating a gas kick out of the well using the Driller's method. What would normally happen to active pit level during the circulation?

2 / 80

2. What is the purpose of a flame arrester in the flare stack (end of the vent line on a separator?

3 / 80

3. A well is shut in and a gas kick migrates 1000 feet with no expansion in the annulus. Well Information:
Gas Volume = 20 bbl
Total Depth = 6,000ʹ MD and TVD
Casing Shoe = 2,200ʹ MD and TVD
Open Hole = 8.5ʺ
Mud Weight = 8.33 ppg
What is the increase in bottom hole pressure due to gas migration? Assume no losses to the formation.

4 / 80

4. What is the function of vent/ bleed/ straight through line in the choke manifold?

5 / 80

5. How do you know that a self-fill float is plugged?

6 / 80

6. Before cutting the drilling line, with the bit at the casing shoe, which item of equipment must be installed to improve well control capability ?

7 / 80

7. During the first circulation of the Driller's method, casing pressure starts to increase and after the lag time the drill pipe pressure starts to increase. What could be the problem?

8 / 80

8. When using the Wait and Weight method to circulate kill mud down to the bit, the drill pipe pressure should:

9 / 80

9. A well 9,850 feet (TVD) is filled with 9.2 ppg brine. The plan is to run in the hole to 6,200 feet TVD (6,600 feet measured depth) and displace with drill water of 8.4 ppg. Calculate the hydrostatic pressure at 9,850 feet when the drill water has been circulated back to the surface?

10 / 80

10. What is the main function of the choke in the overall BOP system?

11 / 80

11. When running in the hole with casing what is a benefit of routine fill-ups?

12 / 80

12. An influx has been circulated out of the well with the well control choke using the driller method's first circulation. The well is balanced with a Final Circulating Pressure of 600 psi @ 200 GPM. To continue drilling ahead with the same MW through an MPD manifold, what surface pressure will be needed with the pump rate 450 GPM?

13 / 80

13. What is the main function of the choke in the overall BOP system?

14 / 80

14. While maintaining FCP (Final Circulating Pressure) you make an adjustment to the choke. The amount of time it takes to see the pressure change on the drill pipe gauge is called

15 / 80

15. You shut in a kick but do not know the slow circulating rate pressure. What procedure should you use to obtain the correct initial circulating pressure (ICP)?

16 / 80

16. You shut in a kick but do not know the slow circulating rate pressure. What procedure should you use to obtain the correct initial circulating pressure (ICP)?

17 / 80

17. While drilling ahead, a long flowback happened, the driller stopped drilling and closed the BOP. After checking the SIDPP & SICP, there was 150 psi in both. What should be the next action?

18 / 80

18. A trip sheet was prepared while a tripping out operation, a record for the trip tank volume was taken every 5 stands, by checking the trip sheet, at which record was the first evidence that abnormal pressure occurred?

(5 stands = 3.78 bbl’s)

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19 / 80

19. During a well kill on a surface BOP installation, the pump rate is increased while holding drill pipe pressure constant. How will this affect Bottom-hole Pressure (BHP}?

20 / 80

20. Why is MD used to calculate ECD instead of in the well?

21 / 80

21. What is the generally accepted minimum number of barriers that must be in place and tested for most drilling operations?

22 / 80

22. How does increasing wellbore temperature affect non-aqueous (oil-based) mud density?

23 / 80

23. You close a ram preventer using the remote BOP panel the ram open light goes out and the close light illuminates but you notice that the accumulator pressure has remained static. What has happened?

24 / 80

24. You are drilling ahead with a 12.25-inch Bit with an average ROP of 95 feet/hour. For the last 60 minutes there has been no change to the pit level. What action would you take?

25 / 80

25. A 30.0 bbls 14.5 ppg slug is pumped prior to tripping out of the hole. Mud Weight is 12.3 ppg. What mud volume, in addition to the slug volume, should we expect returned due to the slug  u-tubing into position?

26 / 80

26. What increases the risk of surging when running casing in the hole?

27 / 80

27. What gauge is used to record the Slow Circulating Rate (SCR) pressure?

28 / 80

28. While drilling the top-hole section on a surface stack rig, a shallow gas flow is encountered. What is the safest action to secure the safety of the rig and personnel on the rig?

29 / 80

29. What pressure is held constant during the first circulation of the Driller's Method?

30 / 80

30. When should you recalculate the Maximum Allowable Annular Surface Pressure (MAASP)?

31 / 80

31. Why must you leave spare capacity in the active pit system when circulating out a kick?

32 / 80

32. What is the percentage of void space in a formation?

33 / 80

33. A weighted pill is pumped into the well. As the pipe is pulled out of the pill, what will happen to bottom hole pressure?

34 / 80

34. What effect will an expanding gas bubble have on ECD as it is circulated out of a well?

35 / 80

35. On a surface stack rig, a salt-water kick with no associated gas was encountered and the well was shut in. If drill string has drill pipe and drill collars, when will the surface casing pressure be maximum during the well kill?

36 / 80

36. Why is it good practice during a well kill to monitor the top of the well on the trip tank?

37 / 80

37. You shut in a kick but do not know the slow circulating rate pressure. What procedure should you use to obtain the correct initial circulating pressure (ICP)?

38 / 80

38. What measures can be taken to prevent "blow-through" .in a mud gas separator?

39 / 80

39. You have shut-in on a well and are planning a kill operation. The Mud Engineer estimates it will take 3200 sacks of barite to weight up the fluid system to kill weight. The rig has 2500 sacks of barite onsite and more will not arrive for 3 days. Shut in pressures have increased since the well was shut in indicating gas migration. The shoe strength is a concern if pressures continue to build. Which Kill Method would be the best to implement

40 / 80

40. During a well kill operation what pressure do we want to keep the bottom hole pressure at least equal to?

41 / 80

41. You are circulating a gas kick out of the well using the Driller's method. What would normally happen to active pit level during the circulation?

42 / 80

42. Select the correct definition of the "closing ratio" of a ram preventer.

43 / 80

43. During a well kill operation what pressure do we want to keep the bottom hole pressure at least equal to?

44 / 80

44. Slow circulating rate pressure= 300 psi at 30 SPM

The well has been shut in after a kick:

Shut In Drill Pipe Pressure           600 psi

Shut In Casing Pressure   750 psi

Before starting to kill the well, there is a complete power failure at the pumps.

Which pressure should be kept constant in order to maintain the correct bottom hole pressure if the influx migrates?

45 / 80

45. What should happen while making stripping through annular?

46 / 80

46. If a well is shut in with 0 psi SICP and 435 psi SIDPP, what is the reason for zero SICP?

47 / 80

47. What is the purpose for having the flow line capable of venting to the Mud Gas separator?

48 / 80

48. What is the main reason for a trip drill ?

49 / 80

49. What are the benefits of using MPD while drilling a well ?

50 / 80

50. A 500-foot long cement plug is set inside the casing shoe. The mud in the hole is to be displaced to a new mud density. Mud density below the cement plug = 11.8 ppg

New mud density = 12.8 ppg

Top of cement plug= 8200 feet

I f the plug failed and allowed pressure to pass between the top and the bottom of the plug, what would happen to the bottom hole pressure?

51 / 80

51. What action should a Driller take if a sudden increase m mud gas level is recorded?

52 / 80

52. You run back to the shoe and carry out a slip-and-cut on the drilling line. The operation normally takes 60 minutes. What is the best way to monitor the well?

53 / 80

53. You have shut-in on a well and are planning a kill operation. The Mud Engineer estimates it will take 3200 sacks of barite to weight up the fluid system to kill weight. The rig has 2500 sacks of barite onsite and more will not arrive for 3 days. Shut in pressures have increased since the well was shut in indicating gas migration. The shoe strength is a concern if pressures continue to build. Which Kill Method would be the best to implement

54 / 80

54. During the first circulation of the Driller's method, casing pressure starts to increase and after the lag time the drill pipe pressure starts to increase. What could be the problem?

55 / 80

55. What is the correct definition of Porosity?

56 / 80

56. The Mud Engineer starts the degasser and the desilter. What will happen to flow rate from the well?

57 / 80

57. In a well with the Bit to Shoe volume greater than drill string volume, which of the following kill methods will minimize the risk of losses?

58 / 80

58. During the 2nd Circulation of the Driller's Method, kill weight mud is returning at the shakers. The well is shut in correctly. What should the pressure gauges read assuming no trapped pressure in the well?

59 / 80

59. If the Rotating Control Device is leaking drilling fluid in a hydrostatically overbalanced well, what is the first course of action the driller should take?

60 / 80

60. You close a ram preventer using the remote BOP panel the ram open light goes out and the close light illuminates but you notice that the accumulator pressure has remained static. What has happened?

61 / 80

61. You are running a non-shearable tool in the hole on a surface stack rig. What option is available to the Driller if the well flows when the tool is across the BOP stack?

62 / 80

62. What is the only function of a diverter?

63 / 80

63. The rig team has just calculated Kick Tolerance for a range of Kick Intensities, and the operational Kick Tolerance Window is provided below.
From the graph, determine the maximum volume of gas that can be swabbed into the well (0 ppg Kick Intensity), shut-in and circulated out without breaking down the shoe?

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64 / 80

64. While tripping out of the hole, the Assistant Driller (AD) has noted improper hole fill: After pulling five stands, the hole has taken no fluid from the trip tank. It should have taken three barrels. The AD informs the Driller of the problem. What is the action should the Driller take?

65 / 80

65. Which are not main components of an RCD system?

66 / 80

66. What are the key elements of Bullheading?

67 / 80

67. Why is the Mud Weight measured at the Shakers at regular intervals?

68 / 80

68. A well is shut in on a kick and the shut-in pressures on the gauges have stabilized. The SIDPP reads 350 psi and the SICP reads 900 psi. What is happening in the well?

69 / 80

69. You run back to the shoe and carry out a slip-and-cut on the drilling line. The operation normally takes 60 minutes. What is the best way to monitor the well?

70 / 80

70. Reduced mud weight causes kick, how could mud weight be accidentally reduced?

71 / 80

71. What is the main function of the Trip Tank?

72 / 80

72. A mud system consists of 4 tanks (9 ft length, 12 ft width, 8 ft height), if the fluid depth in the tanks is 6 ft, how many barrel can be added to the system?

73 / 80

73. After successfully shutting-in on a kick, which of the following is a crucial responsibility of the Supervisor?

74 / 80

74. When should you recalculate the Maximum Allowable Annular Surface Pressure (MAASP)?

75 / 80

75. What is the correct definition of Permeability?

76 / 80

76. What is the definition of fracture pressure?

77 / 80

77. Why do we pressure test a cement job?

78 / 80

78. Where is the best place to put a heavy pill?

79 / 80

79. During the 2nd Circulation of the Driller's Method, kill weight mud is returning at the shakers. The well is shut in correctly. What should the pressure gauges read assuming no trapped pressure in the well?

80 / 80

80. In a well with the Bit to Shoe volume greater than drill string volume, which of the following kill methods will minimize the risk of losses?

Well Control Drilling Supervisory

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