# Well Control: Activity 1

1) Normal formation pressure gradient for continuous depositional basins is generally assumed to be:

a. 0.495 psi/ft           b. 0.564 psi/ft           c. 0.376 psi/ft          d. 0.465 psi/ft

2) After shutting in on a kick the SIDPP and SICP have been stable for 15 minutes, they then both start slowly raising by the same amount. Which one of the following is the probable cause?

a. Another influx is entering the wellbore.
b. The influx is migrating up the wellbore.
c. The gauges are faulty.
d. The BOP stack is leaking.

3) What does the SIDPP indicate when the well is properly shut-in on an underbalanced kick.

a. The difference between formation pore pressure and leak-off pressure
b. The MAASP
c. The difference between formation pore pressure and the hydrostatic pressure of the mud in the            drillpipe
d. The trapped pressure caused by shutting in the well.

4) While drilling ahead a well kicks and is shut-in. Drill pipe and casing pressures start rising but             before stabilizing both start dropping quite rapidly. What has probably happened?

a. The drill string has parted.
b. The bottom hole assembly has packed off.
c. A weak formation has broken down.
d. The pressure gauges have both malfunctioned.
e. Gas has started to migrate up the drill string and the annulus.

Data for questions 5 and 6:

A vertical well is 8,020 ft deep and filled with 12.5 ppg drilling fluid. While circulating with 80 spm the friction losses in the well system are as follows:

Pressure loss through surface equipment = 200 psi
Pressure loss in the drill string = 800 psi
Pressure loss through the bit nozzles = 1,850 psi
Pressure loss in the annulus = 150 psi

5) What is the circulating pressure?

a. 2,200 psi       b.2,800 psi         c.2,850 psi         d.3,000 psi

6) What is the bottom hole pressure while circulating?

a.5,013 psi        b.5,213 psi         c.5,363 psi         d.6,013 psi

7) Which of the following best describes fracture pressure?

a. The pressure in excess of mud hydrostatic that, if exceeded, is likely to cause losses at the casing shoe.
b. The total pressure applied at the shoe that is likely to cause losses.
c. The maximum bottomhole pressure allowed during a kill operation.
d. The maximum pressure allowed on the drillpipe gauge during a kill operation.

8) A well control method in which fluid is pumped into the top of the wellbore and gas is vented off in a step-by-step manner is commonly called:

b. Volumetric Method.
c. Lubricate and Bleed Method.
d. Engineer’s Method.

9) A gas bearing formation is over-pressured by an artesian effect. Which of the following conditions has created the over pressure?

a. The formation water source is located at a higher level than the rig floor.
b. The difference in density between gas and formation fluid.
c. Compaction of the formation from the above laying formation.

10) We are about to bring the well “on choke”. Our kick sheet calculations tell us we should have 1200 psi Initial Circulating Pressure on the drill pipe when the pumps are up to the kill speed of 25 spm. What is the proper procedure for bringing the well on choke and establishing the Initial Circulating Pressure (Surface BOP stack)

a. As the driller slowly increases the pump speed, the choke operator adjusts the choke so that he will have 1200 psi on the drill pipe gauge when the driller reaches 25 spm.

b. As the driller slowly increases the pump speed, the choke operator adjusts the choke to maintain constant casing pressure. Once the pumps are up to speed and after the hydraulic delay, the correct ICP is shown on the drill pipe gauge.

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