0% 1234567891011121314151617181920212223242526272829303132333435363738394041424344454647484950515253545556575859606162636465666768697071727374757677787980 The test starts the moment you click on the Start button. You may work on your test until the time allotted for it ends. Duration: 3 hours Your time is up! Your test is submitted automatically whether you’re finished or not. Well Control Drilling Well Control Supervisory The number of attempts remaining is 5 Please fill your information FULL NAMEEmailPhone Number 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? a. Pit level would increase due to gas expansion then decrease as gas exits the choke b. Pit level would decrease due to gas expansion then stay constant as gas exits the choke c. Pit level would increase due to gas expansion then stay constant as gas exits the choke d. Pit level would decrease due to gas expansion then increase as gas exits the choke 2 / 80 2. What is the purpose of a flame arrester in the flare stack (end of the vent line on a separator? a. To allow gas to bring a fire back into the separator b. All choices c. A passive device that allows gas to pass through it but stops the propagation of a flame d. To allow your vent line to light up the rig location when circulating out a kick 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. a. 2,165 psi b. 952 psi c. 1925 psi d. 433 psi 4 / 80 4. What is the function of vent/ bleed/ straight through line in the choke manifold? a. To apply back pressure while controlling a kick b. To bleed high volume of formation fluid by-passing the choke c. To facilitate easy handling of choke 5 / 80 5. How do you know that a self-fill float is plugged? a. Trip monitoring returns will increase to closed end displacement b. Hook load increases c. Trip monitoring returns will decrease to closed end displacement d. Running time increases 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 ? a. Inside blowout preventer b. Drop in check valve c. Full opening safety valve d. Circulating head 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? a. Choke was out b. Choke plugging c. Drill string washout d. Plugged bit nozzle 8 / 80 8. When using the Wait and Weight method to circulate kill mud down to the bit, the drill pipe pressure should: a. Slowly increase b. Slowly decrease c. Stay the same 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? a. 5,164 psi b. 4,303 psi c. 4,815 psi d. 4,454 psi 10 / 80 10. What is the main function of the choke in the overall BOP system? a. To direct hydrocarbons to the flare b. To hold back pressure while circulating out a kick c. To direct wellbore fluids to the mud/gas separator d. To shut the well in softly 11 / 80 11. When running in the hole with casing what is a benefit of routine fill-ups? a. To prevent casing burst due to high internal pressure b. To provide hydrostatic support to the casing and related components c. To minimize surge pressure when running in d. To reduce Hook Load and wear on the drilling line 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? a. 600 psi b. More than 600 psi c. Less than 600 psi. 13 / 80 13. What is the main function of the choke in the overall BOP system? a. To direct wellbore fluids to the mud/gas separator b. To hold back pressure while circulating out a kick c. To shut the well in softly d. To direct hydrocarbons to the flare 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 a. Bottoms-Up time b. Annular velocity time c. Gas Migration time d. Lag time 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)? a. Contact the Mud Logger and request the best possible calculation of the Initial Circulating Pressure to use during the well kill b. Use the SIDPP as the circulating pressure. c. Choose the kill rate circulating pressure you took with the last BHA in the hole nearest to the depth where the kick took place. Add 100 psi to this value as a safety margin. d. Follow correct start-up procedure. Read the pressure on the drill pipe gauge, subtracting any overbalance/safety margin pressure. This is the 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)? a. Choose the kill rate circulating pressure you took with the last BHA in the hole nearest to the depth where the kick took place. Add 100 psi to this value as a safety margin b. Contact the Mud Logger and request the best possible calculation of the Initial Circulating Pressure to use during the well kill c. Follow correct start-up procedure. Read the pressure on the drill pipe gauge, subtracting any overbalance/safety margin pressure. This is the ICP d. Use the SIDPP as the circulating pressure 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? a. Open BOP and observe the flowline for a decrease in flow b. Circulate bottom up through choke c. Open BOP and drill while watching the pit volume d. Continue drilling and monitor flowback decreasing 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) a. 1 b. 5 c. 6 d. 4 e. 2 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}? a. BHP will decrease b. BHP will increase c. BHP will stay constant d. There is no way to know what will happen to BHP 20 / 80 20. Why is MD used to calculate ECD instead of in the well? a. Changes in hydrostatic pressure. b. Because of the water in open formation. c. Because the friction of the mud solids and cuttings impact the entire annulus. d. Does not matter. 21 / 80 21. What is the generally accepted minimum number of barriers that must be in place and tested for most drilling operations? a. 4 b. 1 c. 2 d. 3 22 / 80 22. How does increasing wellbore temperature affect non-aqueous (oil-based) mud density? a. No effect on density b. Decreases density c. Increases 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? a. No air pressure at the panel b. The 3-position Ram valve on the accumulator has not moved c. Possible blockage in the line between the accumulator unit and BOP stack d. Master valve not held down for 5seconds 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? a. Increase WOB now that ROP is stable b. Continue drilling al is good c. Prepare to mix LCM as you may be losing some mud to the formation d. Make a flow check w check why pit volume is stable 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? a. 6.35 bbls b. 5.36 bbls c. 5.96 bbls d. 7.35 bbls 26 / 80 26. What increases the risk of surging when running casing in the hole? a. Excessive casing running speed b. Cleaning the hole of cuttings before running the casing c. Reducing the casing running speed d. Conditioning the mud before running the casing 27 / 80 27. What gauge is used to record the Slow Circulating Rate (SCR) pressure? a. The casing pressure gauge at the Standpipe Manifold b. The drill pipe pressure gauge on the Choke Control panel c. The pump pressure gauge at the mud pump d. The casing pressure gauge on the Choke Control panel 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? a. Shut-in the well and prepare for kill operations immediately b. Line the diverter up to the choke manifold, activate the diverter system, and remove non-essential personnel from the rig floor c. Keep pumping mud into the well at the same SPM and circulate bottoms up d. Activate the diverter system and follow rig-specific shallow gas plan 29 / 80 29. What pressure is held constant during the first circulation of the Driller's Method? a. Initial Circulating Pressure b. Final Circulating Pressure c. Shut in Casing Pressure d. Shut in Drill Pipe Pressure 30 / 80 30. When should you recalculate the Maximum Allowable Annular Surface Pressure (MAASP)? a. Every tour b. After a bit change c. After a mud weight change d. After every 300 to 500 feet drilled 31 / 80 31. Why must you leave spare capacity in the active pit system when circulating out a kick? a. If the kick is gas it will expand and pit level will increase b. To store the kick fluid as it is circulated from the well c. If the kick is oil, it will expand, and pit level will increase d. If the kick is salt water, it will expand, and pit level will increase 32 / 80 32. What is the percentage of void space in a formation? a. Shale Density b. Low Pressure Formation c. Permeability d. Porosity 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? a. Decrease b. Increase c. Stay the same 34 / 80 34. What effect will an expanding gas bubble have on ECD as it is circulated out of a well? a. Decreases b. Stays the same. c. Increases. 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? a. When the kick is in the portion of the annulus that maximizes its height b. When kick reaches the surface. c. When kick is just below the shoe. d. When kill mud reaches bit. 36 / 80 36. Why is it good practice during a well kill to monitor the top of the well on the trip tank? a. To check for leaks across the BOP b. To check for a secondary influx during the kill c. To monitor returns from the mud gas separator d. To check for losses at the Shoe 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)? a. Contact the Mud Logger and request the best possible calculation of the Initial Circulating Pressure to use during the well kill b. Use the SIDPP as the circulating pressure c. Choose the kill rate circulating pressure you took with the last BHA in the hole nearest to the depth where the kick took place. Add 100 psi to this value as a safety margin d. Follow correct start-up procedure. Read the pressure on the drill pipe gauge, subtracting any overbalance/safety margin pressure. This is the ICP 38 / 80 38. What measures can be taken to prevent "blow-through" .in a mud gas separator? a. Use the minimum TVD on the mud seal. b. Restrict the vent line ID. c. Limit the flow rate -into the separator when the influx is entering the separator. d. Allow the hydrostatic head to be reduced in the separator before the influx arrives to the 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 a. Wait and Weight Method of Well Control b. Kill the well with Reverse Circulation c. Begin to Lubricate and Bleed d. Driller's Method of Well Control 40 / 80 40. During a well kill operation what pressure do we want to keep the bottom hole pressure at least equal to? a. At least equal to slow circulating rate b. At least equal to Drill Pipe pressure c. At least equal to formation fluid pressure d. At least equal to Shut in Casing pressure 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? a. Pit level would increase due to gas expansion then stay constant as gas exits the choke b. Pit level would decrease due to gas expansion then stay constant as gas exits the choke c. Pit level would decrease due to gas expansion then increase as gas exits the choke d. Pit level would increase due to gas expansion then decrease as gas exits the choke 42 / 80 42. Select the correct definition of the "closing ratio" of a ram preventer. a. Operating pressure required to close the ram against maximum anticipated wellbore Pressure b. Ratio of the packer area against the piston rod area c. Operating pressure required to close the ram against the formation pressure d. Operating pressure required to open the ram at BOP Rated Working Pressure 43 / 80 43. During a well kill operation what pressure do we want to keep the bottom hole pressure at least equal to? a. At least equal to slow circulating rate b. At least equal to Drill Pipe pressure c. At least equal to Shut in Casing pressure d. At least equal to formation fluid pressure 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? a. 600 psi drill pipe pressure b. 1050 psi casing pressure c. 900 psi drill pipe pressure d. 750 psi casing pressure 45 / 80 45. What should happen while making stripping through annular? a. Regulate annular closing pressure to minimum pressure that control well bore pressure b. Increase annular closing pressure to reduce leakage c. Open choke to reduce well pressure d. Close pipe ram and open annular till tool joint passes 46 / 80 46. If a well is shut in with 0 psi SICP and 435 psi SIDPP, what is the reason for zero SICP? a. Hole packed off around the BHA b. Well was swabbed in c. Drill string failure d. Fractured format on at the casing shoe 47 / 80 47. What is the purpose for having the flow line capable of venting to the Mud Gas separator? a. If mud flow is too excessive then you can dump the excess mud into the separator b. All choices c. If gas levels reach a high level in the flow line then you can vent to the Mud Gas separator. d. It can increase pressure on the flow line on a connection. 48 / 80 48. What is the main reason for a trip drill ? a. To ensure the crew is able to effectively recognize and react to a kick while tripping pipe b. To ensure the crew is trained to kill the well c. To test the pit, flow and trip tank alarms d. To see how fast the Driller can line up on the choke manifold 49 / 80 49. What are the benefits of using MPD while drilling a well ? a. It aids in mitigating pressure-related non productive time events. b. It enables well to be drilled with more consistent BHP. c. All choices d. It enables a Well to be drilled within tight Window between pore pressure and fracture pressure. 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? a. BHP would stay the same b. BHP would increase c. BHP would decrease 51 / 80 51. What action should a Driller take if a sudden increase m mud gas level is recorded? a. Stop drilling. Circulate bottoms-up, record gas levels and inform your supervisor b. Request Mud Engineer to increase mud weight by 0.3 ppg c. Check for flow and call Supervisor d. Increase rate of penetration to minimize the warning signs 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? a. Lines up to mud pits and inform Mud Logger to monitor for gains b. Shut in well and record pressure every 15 minutes c. Install a safety valve in the drill string. Line up to the Trip Tank and set the alarm d. Line up to trip tank and set Trip Tank alarm 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 a. Driller's Method of Well Control b. Wait and Weight Method of Well Control c. Begin to Lubricate and Bleed d. Kill the well with Reverse Circulation 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? a. Drill string washout b. Plugged bit nozzle c. Choke was out d. Choke plugging 55 / 80 55. What is the correct definition of Porosity? a. The percentage of solid rock in the formation b. The amount of void space in the rock expressed as a percent c. The ability of formation fluids to move through the rock d. The pressure of the fluid in the pore space 56 / 80 56. The Mud Engineer starts the degasser and the desilter. What will happen to flow rate from the well? a. Flow Rate will stay the same b. Flow rate will increase after two to three minutes c. Flow rate will decrease after two to three minutes 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? a. Volumetric Method b. Driller’s Method c. Wait and Weigh Method d. Bullheading Method 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? a. SICP and SIDPP gauges will both read 0 psi b. SICP and SIDPP will be equal to the well's original SIDPP c. SICP will be higher than the SIDPP d. SICP will be lower than the SIDPP 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? a. Pickup off bottom, shut down the pumps, and close the annular preventer b. If you have shear rams, close them. c. Increase pressure on the head and continue drilling. d. Reduce pressure on the head and continue drilling. 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? a. The 3-position Ram valve on the accumulator has not moved b. Master valve not held down for 5seconds c. Possible blockage in the line between the accumulator unit and BOP stack d. No air pressure at the panel 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? a. Make up a safety valve in string and close the annular b. Circulate to create an ECD effect on the bottom of the hole c. Continue running in hole and use surging effect to stop the kick d. Close the Diverter and pump kill mud 62 / 80 62. What is the only function of a diverter? a. To direct formation fluids away from the rig floor b. To act as a backup system if the annular preventer fails. c. To shut in a shallow kick. d. To create a back pressure sufficient to stop formation fluids entering the wellbore. 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? a. 22 bbls b. 19 bbls c. 14 bbls d. 25 bbls 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? a. Connect Kelly or Top Drive and circulate bottoms-up b. Close the diverter and line up to the degasser c. Pull five more stands and re-evaluate the situation d. Perform a flow check immediately and shut in if required 65 / 80 65. Which are not main components of an RCD system? a. Bearing assembly b. Pipe sealing elements c. Flow line and the orbit valve in the flow line d. Bowl/bogy 66 / 80 66. What are the key elements of Bullheading? a. Circulating formation fluids out of a well using a choke and circulating system b. Pumping into a shut-in well to force formation fluids back into the formation c. Pumping fluid into the top of a well and bleeding gas in a step by step fashion d. Forcing pipe into a hole under pressure using hydraulic jacks 67 / 80 67. Why is the Mud Weight measured at the Shakers at regular intervals? a. To record on the Mud Engineer daily report b. To measure the gas content in the mud c. To weigh the volume of cuttings in the mud d. To check for contamination of the mud returns 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? a. The well is not completely full of mud and there is more bottom hole pressure on the drill pipe side of the well b. The well is balanced; pressures at the bottom are balanced on both sides of the well c. The well is not balanced; bottom hole pressure on the annulus side is lower due to contamination by formation fluids d. The well is not balanced; bottom hole pressure (BHP) on the annular side is higher than on the drill pipe side of the U-tube 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? a. Line up to trip tank and set Trip Tank alarm b. Shut in well and record pressure every 15 minutes c. Install a safety valve in the drill string. Line up to the Trip Tank and set the alarm d. Lines up to mud pits and inform Mud Logger to monitor for gains 70 / 80 70. Reduced mud weight causes kick, how could mud weight be accidentally reduced? a. Running Degasser while drilling b. Running Centrifuges while drilling c. Isolating water and base oil from the mud tanks d. Adding barite to the mud 71 / 80 71. What is the main function of the Trip Tank? a. To dump mud into the well for a Pit drill. b. To keep the hole full when tripping in the hole. c. To monitor for gains when circulating bottoms-up. d. To detect swabbing or surging. 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? a. 154 bbl’s b. 148 bbl’s c. 205 bbl’s d. 137 bbl’s 73 / 80 73. After successfully shutting-in on a kick, which of the following is a crucial responsibility of the Supervisor? a. Mix Kill Weight Mud b. Communicate plan to crew c. Measure Mud Weight in and out d. Check Pit Levels and lineups 74 / 80 74. When should you recalculate the Maximum Allowable Annular Surface Pressure (MAASP)? a. After every 300 to 500 feet drilled b. After a bit change c. After a mud weight change d. Every tour 75 / 80 75. What is the correct definition of Permeability? a. The pressure of the fluid in the pore space b. The density of the formation fluids c. The amount of solid rock in the formation d. The ability of formation fluids to move through the rock 76 / 80 76. What is the definition of fracture pressure? a. The maximum BHP during a kill operation b. The maximum pressure on drill pipe during a kill operation c. The pressure at which the formation will fail d. The surface pressure that will cause mud losses 77 / 80 77. Why do we pressure test a cement job? a. To make sure casing does not collapse b. To increase the hardness of the cement c. To test the integrity of the cement d. To reduce the effect of wet cement on the drill Bit 78 / 80 78. Where is the best place to put a heavy pill? a. At the beginning of the h Horizontal section. b. At the end of the horizontal section. c. In the vertical part of the well. d. In the reserve pit. 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? a. SICP and SIDPP gauges will both read 0 psi b. SICP will be higher than the SIDPP c. SICP and SIDPP will be equal to the well's original SIDPP d. SICP will be lower than the SIDPP 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? a. Volumetric Method b. Bullheading Method c. Driller’s Method d. Wait and Weigh Method Your score is 0% Restart quiz Rate it! Send feedback
