Formation Integrity Tests /16 0 votes, 0 avg 3 Created on March 09, 2023 Formation Integrity Tests 1 / 16 Why is it important to circulate a bottoms-up before starting a cement job on a deviated well? To remove the cuttings that can plug the casing To ensure the cement will set up properly behind the casing To ensure the annulus has a clean column of fluid To ensure the cement will not set up too quickly 2 / 16 Please use the information below to answer the following question: The well drilling program requires a Formation Integrity Test to 16.0 ppg Equivalent Mud Weight (EMW) at the shoe. Casing shoe depth (TVD/MD): 5000 ft / 7500 ft Current Mud Weight (MW): 10.0 ppg What surface pressure shoud be applied to test the casing shoe to the 16.0 ppg EMW? 2340 psi 1560 psi 2600 psi 4160 psi 3 / 16 What happens to the Maximum Allowable Casing Pressure (MACP) as the Mud Weight (MW) is increased? MACP will stay the same MACP will decrease There is no way to know MACP will increase 4 / 16 Considering the options below, what is NOT considered a wellbore barrier verification? Monitoring the mud weight Pressure testing the BOP stack Leak Off Test Pressure testing the casing 5 / 16 Which one of the following will be the LEAST likely to cause losses while killing the well? Short open hole section Increase in mud weight Long open hole section Long waiting time to prepare kill fluid 6 / 16 What would indicate that the self-fill float is plugged while running casing? Returns would decresase Returns would stay the same Returns would increase There is no way to know 7 / 16 What would happen to the fluid returns if the self-fill float is plugged while running casing? Stay the same Decrease Increase Stay the same 8 / 16 When should a Leak-Off Test (LOT) be done? Before running casing After drilling out the shoe and 10 ft to 50 ft of new formation After tagging the cement Prior to pressure testing the casing 9 / 16 What would be the risks of pulling casing back up? There are no risks Risk of swabbing due to reduced wellbore clearance Risk of surging the well while pulling the casing up Pull up the casing as fast as possible to prevent any surging 10 / 16 What happens to Bottom Hole Pressure (BHP) if the non-return float fails while running casing and the fluid level drops in the annulus? BHP would increase BHP would stay the same BHP would decrease There is no way to know 11 / 16 What is the best definition of the Maximum Allowable Casing Pressure (MACP)? The total pressure at the casing shoe that will cause losses minus the hydrostatic pressure at the casing shoe The difference between formation pressure and the hydrostatic pressure in the annulus The total pressure necessary to kill the well The total pressure at the casing shoe that will cause losses 12 / 16 What would happen if a self-fill float failed to convert to a check valve? Assume the cement is heavier than the fluid used for displacement. It will be impossible to pup the cement into the casing The waiting on cement time would decrease The cement could u-tube back up the casing once pumps are stopped The cement would remain in the liquid state 13 / 16 In an exploratory field, how is the strengh of the formation below the shoe usually measured? To 70% of the casing burst pressure Negative Test Leak-Off Test Formation Integrity 14 / 16 Please use the information below to answer the following question: The well drilling program requires a Formation Integrity Test to 15.8 ppg Equivalent Mud Weight (EMW) at the shoe. Casing shoe depth (TVD/MD): 4500 ft / 6000 ft Current Mud Weight (MW): 10.8 ppg What surface pressure shoud be applied to test the casing shoe to the 16.0 ppg EMW? 1560 psi 2527 psi 1170 psi 3697 psi 15 / 16 What happens to the Maximum Allowable Casing Pressure (MACP) as the Mud Weight (MW) is reduced? MACP will increase MACP will decrease MACP will stay the same There is no way to know 16 / 16 If a self-fill float in the casing is pluggled, how does that represent a well control risk? The the plug clears the fluid level behind the casing would fall Increasing chance of swabbing the well as we run casing in It will not be able to reverse circulate to kill the well The waiting on cement time would increase Your score is LinkedIn Facebook Twitter VKontakte 0% Restart quiz Please rate this quiz Send feedback
