1.
Drilling ahead with only the diverter installed, the well kicked. What should the driller do?
Close the blind rams.
Raise the mud weight to 20.0 ppg.
Begin diverter operations.
2.
While tripping into the hole, the actual volume of mud displaced is less than the calculated amount. What could be the cause?
The well is flowing.
A kick may have been swabbed in during the trip out.
The formation is taking fluid.
3.
A 5000 psi BOP stack was installed after setting surface pipe. The MMS requires that the BOP stack be pressure tested. It must be tested to a low pressure of 200 to 300 psi. To what high pressure must the pipe rams be tested to?
70% of the internal yield pressure of the last casing.
5000 psi or as approved by the MMS district supervisor.
No high pressure test must be done on surface stack, it only needs to be tested on subsea stacks.
4.
Which one of the following is the first positive indicator of a well kick while drilling ahead?
Increase in flow out of the wellbore.
Pump pressure decrease and pump stroke increase.
Increase in drag and torque.
5.
Given the following information, according to the MMS regulations, how many gallons of usable hydraulic fluid must the accumulator provide with respect to the following BOP equipment?
Annular - Hydril GK 13-5/8” 5000 psi
5 gallons
52 gallons
152 gallons
6.
What is the correct procedure for determining the Initial Circulating Pressure if the slow pump pressure is not known?
Add SIDPP + SICP = ICP
Bring the pumps up to the desired kill speed holding casing pressure constant at the SICP value and then read the drillpipe pressure gauge as the correct ICP.
No excuse, you must know the slow pump pressure.
7.
Drilling ahead at 13,000 ft. the well kicked and the mud weight has to be increased from 14.5 ppg to 15.5 ppg. Total mud volume is 1700 bbls. How many 100 pound sacks of barite are required to weight up the entire mud volume?
587 sacks
1307 sacks
2525 sacks
8.
A well is currently being killed using the Wait and Weight method of well control. At what point during the operation is the Final Circulating Pressure held on the drill pipe pressure gauge?
When kill mud starts down the drill pipe.
When kill mud gets to the bit.
When kill mud first comes over the shale shaker.
9.
While logging, the well began flowing and was shut-in with 180 psi on the casing pressure gauge. An hour later, after calling the office, the casing pressure increased to 300 psi. How do we control this situation?
Strip to bottom holding 410 psi on the casing gauge.
Bullhead heavy mud.
Use the volumetric procedure of well control.
10.
According to the MMS regulations, when pulling the drillpipe out of the hole, how often does the hole have to be filled?
Every stand.
Every 5 stands or until the hydrostatic pressure is reduced by 75 psi (whichever yields the least reduction).
Every 10 stands.
11.
With the well shut in on a kick, the SIDPP plus the hydrostatic pressure of the mud in the drill string equals:
Casing pressure.
Degree of underbalance.
Bottomhole pressure.
12.
What would happen first if the bit partially plugged while circulating out a kick?
Drillpipe pressure would increase.
Drillpipe pressure would decrease.
Casing pressure would decrease.
13.
What choke response would be necessary if the choke was washing out while circulating out a kick?
The choke would have to close more.
The choke would have to open more.
No choke adjustment would be necessary.
14.
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 down time.
To minimize the amount of influx by keeping the annular pressure loss as long as possible.
To identify the type of influx as soon as possible.
15.
What mud weight is required to BALANCE a formation pressure of 2,930 psi at a depth of 5,420 ft. TVD?
10.6 ppg
10.4 ppg
10.2 ppg
16.
Given the following well data:
Shut-in Drill Pipe Pressure = 250 psi
What would the SIDPP have been with a 30 bbl gain?
The SIDPP would still be 250 psi.
The SIDPP would have been higher than before.
The SIDPP would have been lower than before.
17.
While drilling ahead a well kicks and is shut-in. Drill pipe and casing pressures start rising. However, before stabilizing both start to behave erratically (rising and then dropping). What has probably happened?
The drill string has parted.
The bottomhole assembly has packed off.
A weak formation has broken down.
18.
Swabbing reduces bottomhole pressure and is associated with pulling the pipe out of the hole and is related to well kicking.
True
False
19.
While tripping out of the hole the well is swabbed in. The mud weight in the well is 10.0 ppg and the well depth is 10,500 ft TVD. Formation pressure is 5,410 psi. If the swab pressure is 125 psi, with sufficient permeability, will the well flow?
Yes
No
20.
A vertical well is shut-in after a gas kick has been taken. The bit is 1,000 ft off bottom and the influx is totally beneath the bit. Shut-in drill pipe pressure is 500 psi. What will shut-in casing pressure be (most likely)?
The same as the shut-in drill pipe pressure.
Higher than the shut-in drill pipe pressure.
Lower than the shut-in drill pipe pressure.
IADC Well Control Practice Test
