Tricky Questions and Well Control Equipment
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This interactive well control quiz contains 25 questions related to Tricky Questions and Well Control Equipment. Additionally, this content is based on both IWCF and IADC well control. Each question contains 3 possible answers and there is full explanation for each one.
Please take your time and think carefully before checking each answer in order to maximize your learning.
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Question 1 of 25
1. Question
What will be happened to bottom hole pressure if you let SCIP increase while you are bringing to a pump to speed?
Correct
Casing pressure must be maintained constant while bringing the pump to speed. If the pressure increases more than SICP, the bottom hole pressure will increase.
Incorrect
Casing pressure must be maintained constant while bringing the pump to speed. If the pressure increases more than SICP, the bottom hole pressure will increase.
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Question 2 of 25
2. Question
After the first circulation of the driller’s method is completed, the pressure readings are as follows; SIDPP = 500 psi and SICP = 500 psi.
Is the first circulation successful?
Correct
If the first circulation of the driller’s method is successful, SIDPP and SICP must be the same.
Incorrect
If the first circulation of the driller’s method is successful, SIDPP and SICP must be the same.
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Question 3 of 25
3. Question
Why SICP is usually more than SIDPP?
Correct
Because of lighter fluid density in the annulus, casing pressure is usually higher than drill pipe pressure.
Incorrect
Because of lighter fluid density in the annulus, casing pressure is usually higher than drill pipe pressure.
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Question 4 of 25
4. Question
Why will 25 bbl of influx in a small hole have more effect than 25 bbl kick in a large hole?
Correct
The influx will be longer in a small hole therefore it will result in higher casing pressure.
Incorrect
The influx will be longer in a small hole therefore it will result in higher casing pressure.
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Question 5 of 25
5. Question
Well depth is at 8,200’MD/7,500’TVD and current mud weight is 10.0 ppg.
Drilling parameters: 280 GPM, SPP 3,000 psi, drilling torque = 20,000 ft-lb.
Pressure loss in the drill string is 250 psi and pressure loss in the annulus is 300 psi.
What is the Equivalent Circulating Density (ECD)?
Correct
Equivalent Circulating Density (ECD), ppg = Current Mud Weight + (Annular Pressure loss ÷ 0.052 ÷ TVD)
Equivalent Circulating Density (ECD), ppg = 10 + (300 ÷ 0.052 ÷7500) = 10.8 ppgIncorrect
Equivalent Circulating Density (ECD), ppg = Current Mud Weight + (Annular Pressure loss ÷ 0.052 ÷ TVD)
Equivalent Circulating Density (ECD), ppg = 10 + (300 ÷ 0.052 ÷7500) = 10.8 ppg -
Question 6 of 25
6. Question
For a surface stack (3,000 psi system), what are BOP components controlled by manifold pressure (1500 psi)?
Correct
HCR and Rams Preventer ( Pipe Rams, VBR’s, Shear Rams, Blind/Shear Rams) are operated by manifold pressure.
Incorrect
HCR and Rams Preventer ( Pipe Rams, VBR’s, Shear Rams, Blind/Shear Rams) are operated by manifold pressure.
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Question 7 of 25
7. Question
What is the recommended reservoir capacity for BOP closing unit according to API RP53?
Correct
API RP53 recommends 2 times usable accumulator volume.
Incorrect
API RP53 recommends 2 times usable accumulator volume.
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Question 8 of 25
8. Question
For 3,000 psi system, what are the normal operating pressure on the following gauges: rig air, manifold, accumulator and annular?
Correct
With normal 3000 psi system, you should see the following figures on pressure gauges:
Rig air gauge = 100 psi
Manifold gauge = 1,500 psi
Accumulator gauge = 3,000 psi
Annular gauge = 500- 1,500 psiIncorrect
With normal 3000 psi system, you should see the following figures on pressure gauges:
Rig air gauge = 100 psi
Manifold gauge = 1,500 psi
Accumulator gauge = 3,000 psi
Annular gauge = 500- 1,500 psi -
Question 9 of 25
9. Question
If the air pressure gauge is 0 psi, what will be the problem?
Correct
When the air pressure is o psi, you will not be able to operate the BOP from the remote panel.
Incorrect
When the air pressure is o psi, you will not be able to operate the BOP from the remote panel.
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Question 10 of 25
10. Question
After blow through happens with a mud gas separator, what should you do to to re-gain capability of the mud gas separator?
Correct
The mud leg column must be re-established before the gas will stop blowing through.
Incorrect
The mud leg column must be re-established before the gas will stop blowing through.
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Question 11 of 25
11. Question
What is the main function of weep holes in a BOP rams?
Correct
Weep holes have the primary function to tell people that the mud seal on the piston rod is leaking or not.
Incorrect
Weep holes have the primary function to tell people that the mud seal on the piston rod is leaking or not.
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Question 12 of 25
12. Question
The well is shut in with SIDPP = 600 psi and SICP = 800 psi.
Current mud weight is 12.5 ppg.
Well depth is 12,000’MD/10,000’TVD.
Driller observes that pressure increase 100 psi every half an hour.
What is the gas migration rate?
Correct
Gas migration rate (ft/hr) = Increase in pressure (psi/hr) ÷ mud gradient (psi/ft)
Increase in pressure = 200 psi/hr
Mud gradient = 0.052 x 12.5 = 0.65
Gas migration rate (ft/hr) = 200÷0.65 = 308 ft/hrIncorrect
Gas migration rate (ft/hr) = Increase in pressure (psi/hr) ÷ mud gradient (psi/ft)
Increase in pressure = 200 psi/hr
Mud gradient = 0.052 x 12.5 = 0.65
Gas migration rate (ft/hr) = 200÷0.65 = 308 ft/hr -
Question 13 of 25
13. Question
What should you concern when selecting BOP elastomer composition?
Correct
Two factors when selecting BOP elastomer composition are type of drilling mud and temperature rating of elastomer.
Incorrect
Two factors when selecting BOP elastomer composition are type of drilling mud and temperature rating of elastomer.
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Question 14 of 25
14. Question
While drilling observed total loss circulation, drilling is stopped and water is filled into the wellbore.
Total volume fill is 60 bbl. Current depth = 9,000’MD/9,000’TVD (vertical well).
Mud weight = 12.0 ppg and water weight = 8.6 ppg.
Annular capacity between casing and drill pipe = 0.0455 bbl/ft.What is the pressure exerted at the loss zone?
Correct
There are two fluid contributing in the hydrostatic pressure against the loss zone which are water and mud. Therefore, you need to determine hydrostatic pressure of each fluid and the summation is the pressure at the loss zone.
Height of 60 bbl water = 60 bbl ÷ 0.0455 = 1,319 ft.
Hydrostatic pressure of water = 0.052 x 8.6 x 1,319 = 590 psiHeight of mud = 9,000 – 1,319 =7,681 ft
Hydrostatic pressure of mud = 0.052 x 12.0 x 7,681 = 4,793 psiTotal hydrostatic pressure = 4,793 + 590 = 5,383 psi.
Incorrect
There are two fluid contributing in the hydrostatic pressure against the loss zone which are water and mud. Therefore, you need to determine hydrostatic pressure of each fluid and the summation is the pressure at the loss zone.
Height of 60 bbl water = 60 bbl ÷ 0.0455 = 1,319 ft.
Hydrostatic pressure of water = 0.052 x 8.6 x 1,319 = 590 psiHeight of mud = 9,000 – 1,319 =7,681 ft
Hydrostatic pressure of mud = 0.052 x 12.0 x 7,681 = 4,793 psiTotal hydrostatic pressure = 4,793 + 590 = 5,383 psi.
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Question 15 of 25
15. Question
What is the proper position of the safety valve (TIW valve) on the rig floor?
Correct
The safety valve must be in opened position.
Incorrect
The safety valve must be in opened position.
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Question 16 of 25
16. Question
During well control operation, you need to reduce choke size regularly because casing and drill pipe pressure keep dropping without any adjustment on the pump speed.
What is the cause of this issue?
Correct
Most likely from this case is choke wash out because the casing and drill pipe pressure keep decreasing without changing pump rate.
Incorrect
Most likely from this case is choke wash out because the casing and drill pipe pressure keep decreasing without changing pump rate.
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Question 17 of 25
17. Question
What types of ring gaskets are wellbore pressure assisted?
Correct
RX and BX gaskets are wellbore pressure assisted gaskets.
Incorrect
RX and BX gaskets are wellbore pressure assisted gaskets.
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Question 18 of 25
18. Question
What is the recommended fluid for BOP test?
Correct
Water is recommended fluid for BOP test because it has less compressibility.
Incorrect
Water is recommended fluid for BOP test because it has less compressibility.
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Question 19 of 25
19. Question
Most of oil companies have the policy that there must be a float installed in the drillstring.
Why they want to do that?
Correct
Two advantages of installing the float valve are prevent kick into the drill string and prevent bit plugging.
Incorrect
Two advantages of installing the float valve are prevent kick into the drill string and prevent bit plugging.
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Question 20 of 25
20. Question
Mud gas separator has the following specification:
Mud gas separator seal leg height = 15 ft
Mud density in the mud leg = 13.0 ppg
Vent line length = 210 ft
Height of mud gas separator = 25 ft
How much pressure will blow-through be occurred?Correct
The operating pressure depends of the leg height and mud weight in the mud gas seperator.
Pressure = 0.052 x leg height x MW
Pressure = 0.052 x 15 x 13 = 10 psiIncorrect
The operating pressure depends of the leg height and mud weight in the mud gas seperator.
Pressure = 0.052 x leg height x MW
Pressure = 0.052 x 15 x 13 = 10 psi -
Question 21 of 25
21. Question
What is the disadvantage of Inside Blow Out Preventer (IBOP)?
Correct
The disadvantage of the IBOP is that you cannot run wireline through because there is a check valve inside its body.
Incorrect
The disadvantage of the IBOP is that you cannot run wireline through because there is a check valve inside its body.
Hint
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Question 22 of 25
22. Question
How many times that you can re-use the BOP ring gaskets before they are out of specification?
Correct
The ring gaskets are only one time use. Do not re-use it.
Incorrect
The ring gaskets are only one time use. Do not re-use it.
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Question 23 of 25
23. Question
How often do you need to test the BOP as per API?
Correct
The BOP test must not exceed 21 days according to API.
Incorrect
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Question 24 of 25
24. Question
During the well control operation, a driller observes that drill pipe pressure goes up quickly from 1,200 psi to 1,600 psi and remains constant but the casing pressure remains constant at 800 psi.
What should he do next?
Correct
This indication shows that the bit nozzle is plugged because drill pipe pressure increases but there is no change in casing pressure. Driller does’t need to make any adjustments. He needs to keep circulating with new circulating pressure at 1,600 psi.
Incorrect
This indication shows that the bit nozzle is plugged because drill pipe pressure increases but there is no change in casing pressure. Driller does’t need to make any adjustments. He needs to keep circulating with new circulating pressure at 1,600 psi.
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Question 25 of 25
25. Question
What is the temperature limit for most of annular preventer?
Correct
Maximum temperature limit of annular preventer is 180 F.
Incorrect
Maximum temperature limit of annular preventer is 180 F.
Leaderboard: Tricky Questions and Well Control Equipment
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Thank you very much for this valuable information.
quest 1 ( !!!!)
i think that bhp decrease (we get less mud height in annulus) , because if we left chocke open so casing pressure increase ( gas evacuaed expasion ) and than formation is flowing ;because bhp less than formation pressure.
Adel,
Please see the explanation above.
Regards,
Shyne
quest 1 !!!!!
i think bhp decrease because formation flowing when you let SICP increase:
gas expansion result less mud height so reduce in annulus hydrostatic pressure and than bhp.
One of the question said TIW valve most be in open position on drill floor but u thick close, pls current the answer. Thanks.
Emma,
This issue is fixed. Thanks for information.
Regards,
Shyne.
good quiz ,very interesting
regards
Dear Team Support,
Thank you so much for the great website and valuable information.
I’m wondering if you can help me in downloading some great topics you provide via this website like: well control Quiz-basic & Tricky, well control equations e-book, red book of Halliburton .
Thanks in advance and wish you all the best
if perforation is done at two different pay zone in a well how is the production tubing connected
Typically, in a normal completion, the zones are perforated before running completion.
Thank you very much for this valuable information
Dear,
I am facing problem to solve question number 14 of Tricky Questions and Well Control Equipment
14. Question
While drilling observed total loss circulation, drilling is stopped and water is filled into the wellbore.
Total volume fill is 60 bbl. Current depth = 9,000′MD/9,000′TVD (vertical well).
Mud weight = 12.0 ppg and water weight = 8.6 ppg.
Annular capacity between casing and drill pipe = 0.0455 bbl/ft.
What is the pressure exerted at the loss zone?
Point 1 – There is total mud loss, it means there is no mud in annulus.(Is it necessary to consider?)
Point 2 – When we filled 60 bbls of water & we got returns.(Is it happened?)
If above points no 1 is correct, then answer will be 590 psi
(Height of 60 bbl water = 60 bbl ÷ 0.0455 = 1,319 ft. Hydrostatic pressure of water = 0.052 x 8.6 x 1,319 = 590 ps)
If above points no 2 is correct, then answer will be 5383 psi.
(Height of 60 bbl water = 60 bbl ÷ 0.0455 = 1,319 ft. Hydrostatic pressure of water = 0.052 x 8.6 x 1,319 = 590 psi
Height of mud = 9,000 – 1,319 =7,681 ft. Hydrostatic pressure of mud = 0.052 x 12.0 x 7,681 = 4,793 psi
Total hydrostatic pressure = 4,793 + 590 = 5,383 psi.)
If total loss happened, Is it necessary to consider the annulus is empty?
If it is not, then what would to the guaranty of mud height in hole is 7,681 ft.
Dear sir can you please elaborate the answer or any modification in question.
Padamsinha Bamane,
We assume the worst case that we fill the empty annulus until you see the return. Otherwise you will not be able to figure out the volume pumped. The question asks you about the total pressure exerting to the formation. Total pressure = summation of hydrostatic pressure of mud and water.
Regards,
Shyne
thanx
very good exersise
plaze send me supervisor iwcf question .
All questions are valid for both IADC and IWCF.
in the tricky questions ,specially in 16 exercise.when do you need to increase choke size regularly ,in what situation, operationally conditions and why.
I luv this