1) Of all the following warning signs, which two signs would leave little room for doubt that the well is kicking?
a. Flow line temperature increase
b. Increased rotary torque
c. Flow rate increase
d. Decreased drill string weight
e. Pit volume gain
f . Increased rate of penetration
2) Which one of the following is NOT a warning sign of when a kick may be occurring?
a. Flow rate increase.
b. Increased torque.
c. Pit gain.
d. Well flowing with the mud pumps off.
3) It can be said that closing in the well promptly is one of the most important duties of a driller. Any delay may make the well potentially more difficult to kill. From the list of practices shown below, choose the six most likely to lead to an increase in the size of the influx.
a. Switching off the flow meter alarms.
b. Regular briefing for the derrickman on his duties regarding the monitoring of pit levels.
c. Drilling a further 20 ft. after a drilling break, before flow checking.
d. Running regular pit drills for drill crew.
e. Maintaining stab-in valves.
f. Testing stab-in valves during BOP tests.
g. Excluding the drawworks from the SCR assignment.
h. Keeping air pressure on choke control console at 10 psi.
I. Calling tool pusher to floor prior to shutting in the well.
j. Not holding down master air valve on remote BOP control panel while functioning a preventer.
4) Which two of the following drilling practices should be considered when connection gas is noticed? (Choose two answers)
a. Pumping a low viscosity pill around bit to assist in reduction of balled bit or stabilizers.
b. Control drilling rate so that only one slug of connection gas is in the hole at any one time.
c. Pulling out of the hole to change the bit.
d. Raising the mud yield point.
e. Minimizing the time during a connection when the pumps are switched off.
5) Which one of the following would not be a warning sign that the bottom hole pressure is approaching formation pressure?
a. Large crescent shaped cuttings.
b. Well flows with pumps off.
c. Increase in chloride content.
d. Increase in connection gas.
6) While drilling along at a steady rate the derrickman asks to slow the mud pumps down so that the shakers can handle the increase in cuttings coming back in the returns. Which one of the following would be the safest course of action.
a. Continue at the same rate allowing the excess to bypass the shakers and get caught in the sand traps which can be dumped later.
b. Pick up off bottom and check for flow, if there is not any then circulate bottoms up to a reduced rate so shakers can handle cuttings volume, flow-check periodically during circulation.
c. Slow down the mud pump until the shakers can handle the volume of cuttings in the returns as requested by derrickman.
d. Slow down the drilling rate and the pump rate until the shakers clear up then go back to the original drilling parameters.
7) In which situation would a pit gain be noticed?
a. Gas kick in an oil based mud. True False
b. Gas kick in a water based mud. True False
8) While tripping in, the actual volume of mud displaced is less than the calculated volume. What could be the cause of this?
a. The hole is flowing.
b. A kick may have been swabbed in during the trip out.
c. The formation is taking fluid.
9) If flow through the drill pipe occurs while tripping, what should the first action be?
a. Pick up and stab the top drive.
b. Run back to bottom.
c. Close the annular preventer.
d. Stab a full opening safety valve.
10) What is the correct meaning of the terminology “Secondary Well Control”?
a. Preventing flow of formation fluid into the well bore by maintaining drilling fluid hydrostatic pressure equal to or greater than formation pressure.
b. Preventing flow of formation fluid into the well bore by maintaining the sum of drilling fluid hydrostatic pressure and dynamic pressure loss in the annulus equal to or greater than formation pressure.
c. Preventing flow of formation fluid into the well bore by maintaining the dynamic pressure loss in the annulus equal to or greater than formation pressure.
d. Preventing flow of formation fluid into the well bore by using BOP equipment in combination with hydrostatic pressure in the well bore to balance the formation pressure.
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