1.
Prior to starting to pull out of the hole a heavy slug was pumped into the drill pipe followed by 15 barrels of 13.2 ppg mud.
Drill pipe capacity = 0.0174 bbl/ft
Use the data to calculate the distance between the drilling fluid level in the drill pipe and in the flowline after the slug has been pumped.
287 ft
270 ft
207 ft
2.
A heavy mud pill is circulated in the well. At what moment will the bottom hole pressure start to increase?
As soon as the pill starts to be displaced into the drill string.
Once all the pill has been displaced into the annulus.
Once the pill starts to be displaced into the annulus.
3.
A well is drilled to a TVD of 8,200 ft.
Casing shoe TVD = 4,500 ft
How many complete stands of drill pipe can the driller pull before the hole fluid level reduces the bottom hole pressure enough to cause the well to go underbalanced?
28.0 stands
28.3 stands
29.0 stands
4.
During normal drilling operations a 30 bbl slug of light fluid is pumped into the drill string followed by original drilling fluid.
DATA:
Calculate the bottom hole pressure once the light slug is inside the drill pipe.
158 psi
6,140 psi
5,982 psi
5.
Casing is being run into the hole with a conventional float valve. Due to a problem with the fill up line, the casing was not filled. Twelve 40 ft joints have been run into the hole. If the float valve and collar suddenly fail, how would this affect bottom hole pressure?
13-3/8” – 61 lb/ft casing
Bottom hole pressure decreases by 73 psi
Bottom hole pressure decreases by 158 psi
Bottom hole pressure decreases by 264 psi
6.
If the driller pulls all 400 ft of 8” OD x 2-13/16”ID drill collars out of the hole, including the bit, without filling the hole, what would be the reduction in bottom hole pressure?
DATA:
88.6 psi
134 psi
234 psi
.
Use the following data to answer questions 7 and 8:
Mud weight = 10.3 ppg
7.
What is the circulating drill pipe pressure?
1,600 psi
2,760 psi
2,850 psi
8.
What is the bottom hole pressure while circulating?
6,213 psi
6,463 psi
6,695 psi
6,945 psi
9.
While drilling ahead, a driller observes a warning sign for a kick. Why is it better to continue pumping while raising the pipe to the shut-in position?
To minimize downtime.
To minimize the influx by keeping the annular pressure loss as long as possible.
The driller should shut off the pump before picking up to identify the influx as soon as possible.
To prevent sticking the pipe.
10.
A vertical well with a surface BOP stack is shut in after a kick. The pressure readings are as follows:
What is the reason for the difference in the two pressure readings?
The influx is in the drill pipe.
The influx has a lower density than the drilling fluid.
The influx has a higher density than the drilling fluid.
11.
A kicking well has been shut in. The drill pipe pressure is “0” because there is a non-return valve (float) in the drill string. To establish the SIDPP, what action should be taken?
Pump at kill rate into the drill string with the well shut in. When casing pressure starts to rise, read the pump pressure. This is the SIDPP.
Bring the pump up to kill rate holding the casing pressure constant by opening the choke. The pressure shown when the pump is at kill rate is the SIDPP.
Pump very slowly into the drill pipe with the well shut in. When the pumping pressure stabilizes the float has opened. This pumping pressure is the SIDPP.
12.
An influx is being circulated out using the Driller’s method and using 1,100 psi at 30 spm. The driller decreases pump speed to 25 spm but the choke operator holds the drill pipe pressure constant by adjusting the choke. What happens to bottom hole pressure?
Increases
Decreases
Remains approximately the same.
13.
A kicking well has been shut in. If a salt water influx was being circulated out using the Driller’s method, when would the casing pressure be at its maximum?
At initial shut in.
When the top of the influx reaches the casing shoe.
When the influx is at the surface.
14.
Which one of the following statements is true?
There will be no difference between using the Drillers method or the Wait and Weight method.
If the kill mud is being circulated up the annulus before the kick has reached the shoe then the Wait and Weight method will reduce the risk of breaking down the formation compared to using the Drillers Method.
The Wait and Weight method should always be used because the pressure at the casing shoe will always be lower than when using the Drillers Method.
15.
Which of the following is a good operating practice in top hole (surface hole) that has a risk of a gas bearing formation being penetrated?
Use a high density mud to create maximum overbalance.
Pump out of the hole on trips.
Maintain a high rate of penetration to ensure mud viscosity level as high as possible.
16.
An influx is being circulated out using the Drillers method. During the first circulation, what would happen to the pressure at the casing seat as the bubble is passing from the open hole into the casing? (Note: some influx is in the open hole and some is in the casing).
Increase
Decrease
Remain approximately the same.
17.
While drilling, a gas kick is taken and the well is shut in.
SICP = 0 PSI
The well has been swabbed in.
The hole has packed off around the bottom hole assembly.
The formation at the casing shoe has fractured.
18.
During a kill, while displacing the drill string with kill fluid, a sudden loss in drill pipe pressure is noticed. The driller continues to pump at the same pump rate. There is no significant change in casing pressure. The supervisor adjusts the choke and continues to follow the drill pipe pressure graph as originally planned. How is bottom hole pressure affected?
The bottom hole pressure decreased.
The bottom hole pressure increased then decreased.
The bottom hole pressure decreased then increased.
The bottom hole pressure increased with the choke adjustment.
19.
When running pipe back into the hole, it is noticed that the normal displacement of mud into the trip tank is less than calculated. After reaching bottom and commencing circulation the return flow meter is observed to reduce from 50% to 42 %. A pit loss of 2 barrels is noted. What is the most likely cause of these indications?
Partial loss of circulation has occurred.
The well has been swabbed in.
A kick has been taken.
20.
On the BOP Closing Unit (accumulator unit) on a jack-up rig, what pressure gauge would be affected if the pipe rams were functioned?
Annular pressure.
Manifold pressure.
Air pressure.
21.
According to API RP 53, how often does API recommend BOP pressure tests?
No less than once every 7 days
No less than once every 14 days
No less than once every 21 days
No less than once every 28 days
22.
You have one inside BOP with an NC50 (4-1/2”) lower connection on your rig but the drill string consists of 5” HWDP, and 8” drill collars. Which one of the following crossovers would you have on the drill floor in case of a kick while tripping?
NC50 (4-1/2”IF) pin x 6-5/8” reg. pin.
NC50 (4-1/2”IF) box x 7-5/8” reg. pin.
NC50 (4-1/2”IF) box x 6-5/8” reg. pin.
23.
When drilling, the 3 position/4 way valves on the BOP accumulator unit should be in which position?
Open
Neutral
Open or closed depending on BOP stack function.
24.
What is the normal precharge pressure for the accumulator bottles on a 3000 psi accumulator unit?
1000 psi
1200 psi
3000 psi
25.
A gas bearing formation is over pressured by an artesian affect. Which of the following conditions has created the overpressure?
Compaction of the formation from the above laying formation.
The difference in density between gas and formation fluid.
A formation water source located at a higher level than the rig floor.
26.
A driller needs to close in a flowing well with drill pipe in a subsea BOP stack. He pushes the “Annular Close” button and the pilot light changes, but all gauges and the flo-meter remain static. What is his best option?
Change pods and try again.
Call and wait for the subsea engineer.
Send the assistant driller to manually operate the 4-way valve on the hydraulic Control Manifold to close the annular.
27.
When a function is operated on a subsea control panel, which of the following is true?
SPM valves will operate in both pods.
SPM valves will operate only on the active pod.
28.
While drilling a well on a semi submersible drilling rig, what three factors may affect the accuracy of drilling fluid flow readings (flo-sho) and drilling fluid volume readings (PVT)?
Vessel heave, crane operations, rig pitch and roll.
Water depth, number of generators on line, riser tension.
Vessel heave, crane operations, riser tension.
Water depth, rig pitch and roll, number of generators on line.
29.
After a gas kick has been killed on a subsea stack 8 bbls of gas remain trapped in the BOP stack between the annular preventer and the choke line side outlet.
Vertical distance between BOP and rig floor = 1465 ft
Calculate the expanded volume of gas produced at the rig if the annular preventer is opened and the gas is allowed to migrate through the marine riser to the rig floor.
563 bbls
572 bbls
530 bbls
522 bbls
30.
On a semi submersible a kick is taken and the following data has been recorded after shut-in pressures have stabilized:
Well Depth (RKB) = 15,327 ft TVD
Calculate the margin between the initial dynamic MAASP and the initial casing pressure if a 100 psi overbalance is to be maintained above the formation pressure at the start of the well kill operation.
560 psi
380 psi
580 psi
660 psi
IWCF Well Control Practice Test
