Basic Concept of Well Control
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This topic contains 25 questions related to basic concept of well control. Additionally, this content is based on both IWCF and IADC well control. Each question contains 3 possible answers. Learners can go to the list and select another question and each question will have the full explanations.
In order to maximize your learning, you need to carefully think through before selecting answer and in some questions, you must use a calculator to figure out the answer.
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Question 1 of 25
1. Question
What is the pressure gradient of 9.2 ppg mud?
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Question 2 of 25
2. Question
Large pit gain will create high Shut In Casing Pressure.
Is this statement true?
Correct
Large pit gain will create a lot of hydrostatic reduction in annulus. In order to balance formation pressure, casing pressure will be increased.
More pit gain = more hydrostatic reduction = more casing pressure.
Incorrect
Large pit gain will create a lot of hydrostatic reduction in annulus. In order to balance formation pressure, casing pressure will be increased.
More pit gain = more hydrostatic reduction = more casing pressure.
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Question 3 of 25
3. Question
When killing the well with driller’s method, what should you see to the pit volume during first circulation?
Correct
During first circulation of driller’s method, gas will naturally expand when it reaches surface. With gas expansion, pit volume will increase.
More details: How are pressure and pit volume doing during the first circulation of the driller’s method?
Incorrect
During first circulation of driller’s method, gas will naturally expand when it reaches surface. With gas expansion, pit volume will increase.
More details: How are pressure and pit volume doing during the first circulation of the driller’s method?
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Question 4 of 25
4. Question
What are the positive well control indicators while drilling?
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Question 5 of 25
5. Question
While circulating mud in the well, which part of pressure lost will act at the bottom of the wellbore ?
Correct
When the mud is flowing upward while circulating, the annular pressure loss will act in the opposite direction of the flow. Therefore, annular pressure loss will act at the bottom of the well.
Incorrect
When the mud is flowing upward while circulating, the annular pressure loss will act in the opposite direction of the flow. Therefore, annular pressure loss will act at the bottom of the well.
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Question 6 of 25
6. Question
What are two parameters affecting hydrostatic pressure calculation?
Correct
Hydrostatic pressure affects by True Vertical Depth (TVD) and mud weight.
Hydrostatic pressure = 0.052 x TVD x Mud Weight
Ref: Hydrostatic Pressure Calculation
Incorrect
Hydrostatic pressure affects by True Vertical Depth (TVD) and mud weight.
Hydrostatic pressure = 0.052 x TVD x Mud Weight
Ref: Hydrostatic Pressure Calculation
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Question 7 of 25
7. Question
Well information: 5500′ MD/ 4500′ TVD. Mud weight in the hole is 9.5 ppg.
What is the hydrostatic pressure at the bottom hole?
Incorrect
Hydrostatic pressure = 0.052 x 4500 x 9.5 = 2,223 psi
Ref: Hydrostatic Pressure Calculation
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Question 8 of 25
8. Question
What is the proper gauge when recording the slow circulating rate?
Correct
It is good practice to read the slow circulating pressure using the drill pipe gauge in remote choke panel because this gauge will be used while killing the well.
Incorrect
It is good practice to read the slow circulating pressure using the drill pipe gauge in remote choke panel because this gauge will be used while killing the well.
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Question 9 of 25
9. Question
What should you do when the positive well control indication is detected while drilling?
Correct
The correct procedure to shut the well in case of well control situation while drilling is called “3 S“
Space out – stop drilling and space out where the tool joint is not located at the BOP rams.
Shut down – stop pumping
Shut in – shut the well in using BOP ram
Ref: Positive Kick (Wellbore Influx) Indications
Incorrect
The correct procedure to shut the well in case of well control situation while drilling is called “3 S“
Space out – stop drilling and space out where the tool joint is not located at the BOP rams.
Shut down – stop pumping
Shut in – shut the well in using BOP ram
Ref: Positive Kick (Wellbore Influx) Indications
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Question 10 of 25
10. Question
What is the most important reaction when the well is flowing (well control situation)?
Correct
Minimize well bore influx will create less problem when you will try to kill the well. This is the most important reaction that people need to do when the well control is seen.
Incorrect
Minimize well bore influx will create less problem when you will try to kill the well. This is the most important reaction that people need to do when the well control is seen.
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Question 11 of 25
11. Question
Which method of well control has only one circulation to kill the well?
Correct
Wait and weight method or some people may call “Engineering Method” is one of the famous methods to kill the well. This method is to control the well by circulating kill weight mud at the start. Additionally, with this method, bottom hole pressure is maintained by using step down chart.
Ref: Wait and Weight Well Control Method (Engineer’s Method)
Incorrect
Wait and weight method or some people may call “Engineering Method” is one of the famous methods to kill the well. This method is to control the well by circulating kill weight mud at the start. Additionally, with this method, bottom hole pressure is maintained by using step down chart.
Ref: Wait and Weight Well Control Method (Engineer’s Method)
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Question 12 of 25
12. Question
Which well control method does need two circulations to kill the well?
Correct
Driller’s method requires two circulations to kill the well. The first circulation is to remove influx out of the wellbore and the second circulation is to kill the well with kill weight mud.
Incorrect
Driller’s method requires two circulations to kill the well. The first circulation is to remove influx out of the wellbore and the second circulation is to kill the well with kill weight mud.
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Question 13 of 25
13. Question
Which well control method will you use if you cannot circulate and gas continue migrating?
Correct
The best way to kill the well if pumps are not be able to use is to utilize “Volume Metric” and “Lubricate and Bleed” to kill the well.
Volumetric is the method to bring gas to surface while controlling the bottom hole pressure.
Lubricate and Bleed is the method to displace the well with kill weight mud.
Both methods are used when the circulation cannot be performed.Incorrect
The best way to kill the well if pumps are not be able to use is to utilize “Volume Metric” and “Lubricate and Bleed” to kill the well.
Volumetric is the method to bring gas to surface while controlling the bottom hole pressure.
Lubricate and Bleed is the method to displace the well with kill weight mud.
Both methods are used when the circulation cannot be performed. -
Question 14 of 25
14. Question
What is the primary method to prevent well control situation?
Correct
The right mud weight will give sufficient hydrostatic pressure to control formation pressure resulting in preventing well control.
Incorrect
The right mud weight will give sufficient hydrostatic pressure to control formation pressure resulting in preventing well control.
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Question 15 of 25
15. Question
What is the secondary well control?
Correct
Blow Out Preventer (BOP) is the secondary well control.
Incorrect
Blow Out Preventer (BOP) is the secondary well control.
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Question 16 of 25
16. Question
If the gas migrates up during shut the well in, what will happen with casing pressure and drill pipe pressure?
Note: For this case, there is a float valve in the drill string
Correct
When the gas migrates up, the casing pressure will increase. However, the drill pipe pressure will stay the same because the float valve will not allow gas to migrate into the drill string.
Ref: Gas Behavior and Bottom Hole Pressure in a Shut in well
Incorrect
When the gas migrates up, the casing pressure will increase. However, the drill pipe pressure will stay the same because the float valve will not allow gas to migrate into the drill string.
Ref: Gas Behavior and Bottom Hole Pressure in a Shut in well
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Question 17 of 25
17. Question
Personnel fail to follow the drill pipe pressure schedule while killing the well with wait and weight method.
What could be happened?
Correct
The drill pipe schedule is used to maintain constant bottom hole pressure while killing the well using wait and weight method. Failing to follow the drill pipe pressure schedule will result in either reduction in hydrostatic pressure or increase in hydrostatic pressure.
If the bottom hole pressure is more than fracture gradient, the lost circulation will be occurred. On the other hand, if the bottom hole pressure is less than formation pressure, the influx will come into the wellbore.
Incorrect
The drill pipe schedule is used to maintain constant bottom hole pressure while killing the well using wait and weight method. Failing to follow the drill pipe pressure schedule will result in either reduction in hydrostatic pressure or increase in hydrostatic pressure.
If the bottom hole pressure is more than fracture gradient, the lost circulation will be occurred. On the other hand, if the bottom hole pressure is less than formation pressure, the influx will come into the wellbore.
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Question 18 of 25
18. Question
Reservoir is at 10,000 ft MD/9,000 ft TVD and reservoir pressure is 5,200 psi.
What is the formation pressure gradient (psi/ft)?
Correct
Pressure gradient = 5,200 psi ÷ 9,000 ft TVD = 0.578 psi/ft.
Ref: Calculate Pressure Gradient and Convert Pressure Gradient
Incorrect
Pressure gradient = 5,200 psi ÷ 9,000 ft TVD = 0.578 psi/ft.
Ref: Calculate Pressure Gradient and Convert Pressure Gradient
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Question 19 of 25
19. Question
What is the definition of blow out?
Correct
Incorrect
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Question 20 of 25
20. Question
What are the positive well control indicators?
Correct
The positive well control indicators are flow with pump off, increase flow show and volume pit increase.
Ref: What are differences between possible and positive well control indicators?
Incorrect
The positive well control indicators are flow with pump off, increase flow show and volume pit increase.
Ref: What are differences between possible and positive well control indicators?
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Question 21 of 25
21. Question
A formation is at 12,000 ft MD/9,500 ft TVD and reservoir pressure is 5,000 psi.
What is the formation pressure in ppg?
Correct
Formation pressure, ppg = 5,000 ÷ (0.052 x 9500) = 10.1 ppg
Incorrect
Formation pressure, ppg = 5,000 ÷ (0.052 x 9500) = 10.1 ppg
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Question 22 of 25
22. Question
What should you do if the current mud weight is less than planned weight up schedule while drilling?
Correct
If you are behind the weight up schedule, you must stop drilling and increase mud weight to planned weight up schedule. Do not try short cut by drilling and keeping the weight up at the same time.
Incorrect
If you are behind the weight up schedule, you must stop drilling and increase mud weight to planned weight up schedule. Do not try short cut by drilling and keeping the weight up at the same time.
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Question 23 of 25
23. Question
Which pressures are adjusted by a choke?
Correct
The choke is used to control both casing and drill pipe pressure in a well control situation.
Incorrect
The choke is used to control both casing and drill pipe pressure in a well control situation.
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Question 24 of 25
24. Question
What should you do first when you try to adjust kill rate?
Correct
When you are trying to adjust kill rate, the first thing you need to do is to hold casing pressure constant then adjust kill rate. By holding casing pressure constant, the bottom hole pressure will remain constant.
Incorrect
When you are trying to adjust kill rate, the first thing you need to do is to hold casing pressure constant then adjust kill rate. By holding casing pressure constant, the bottom hole pressure will remain constant.
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Question 25 of 25
25. Question
Will slug affect bottom hole pressure?
Correct
Slug is the heavier mud which is typically pumped into the drill string to push the mud down. Pumping the slug will not affect bottom pressure because the slug will push the mud in the annulus and leave air on top of slug.
Incorrect
Slug is the heavier mud which is typically pumped into the drill string to push the mud down. Pumping the slug will not affect bottom pressure because the slug will push the mud in the annulus and leave air on top of slug.
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