Workover Operations 0 Workover Operations 1 / 24 What test provides a physical check of the performance of the BOP closing system to make sure the system has sufficient pressure and hydraulic fluid to satisfy API 53 requirements? Total system Check BOP Accumulator Drawdown Test Deadman Test BOP function Test 2 / 24 If the minimum pre-charge is a 1,000 psi, what is the minimum required system pressure after the accumulator drawdown test? 1,000 psi 200 psi above pre-charge 200 psi below pre-charge 3,000 psi 3 / 24 If the emergency closure fails, what action is to be taken? Resort to secondary barrier Resort to primary barrier Increase pump rate Initiate emergency evacuation plan 4 / 24 What is a limitation of a blind/shear ram? Shears pipe Test casing Seal on open hole Seal on pipe 5 / 24 Calculate the buoyancy factor, for a 9.2 ppg fluid weight. 0.848 0.801 0.867 0.859 6 / 24 What could occur when pulling tubing too fast? Swabbing Formation pressure increases Bullheading Surging 7 / 24 Which of the following helps mitigate a tubing mechanical issue (tubing collapse, tubing burst)? Place pressure on annuls to reduce tubing collapse Place pressure on the annulus to reduce chances of tubing burst Place pressure inside tubing to reduce tubing burst All of the above 8 / 24 Which of the following is an accurate effect caused by downhole tools while forward circulating? Reduced clearance, lower friction loss Increased clearance, lower friction loss Reduced clearance, higher friction loss Increased clearance, higher friction loss 9 / 24 Which of the following methods of well control is used to swap surface pressure with hydrostatic pressure without circulating? Reverse Wait & Weight Forward Circulating Lube & Bleed 10 / 24 What is the best way to confirm a primary fluid barrier failure? Check fluid viscosity Increase in fluid temperature Complete fluid losses to the well Test fluid density with a scale 11 / 24 What is NOT required for a fluid to be considered a barrier? Supplies sufficient hydrostatic pressure Sufficient fluid density Ability to observe fluid height with no flow High viscosity 12 / 24 What additive needs to be included in completion fluids to limit loss control? Diesel Highly viscous pill Antifreeze Zinc 13 / 24 What is a reason for de-rating the maximum safe working pressure of well control equipment? Leaking BOP Corrosion Incorrect elastomers Leaking seal 14 / 24 Identify a possible characteristic of fluids in workover/completion operations. Hydrate resistant High solids Forms a wall cake Hydrate sensitive 15 / 24 A non-shut-in well at 10,000’ with a gas influx volume of 5 bbls, what is the change in influx volume as the influx reaches 2,500’? 10 bbls 20 bbls 25 bbls 15 bbls 16 / 24 When considering the BOP equipment, which of the following is a non-sealable component? Drill pipe Blank pipe Gravel pack screen Tubing 17 / 24 Identify a way to reduce tubing movement (i.e., compression/elongation) during testing and stimulation. Reduce pump rate Increase pump rate Tubing won’t move because it is anchored by tubing hanger and production packer All of the above 18 / 24 What is shut-in pressure? Total pressure on the well Difference between hydrostatic pressure and formation pressure Difference between applied pump pressure and formation pressure All of above 19 / 24 What is the objective of testing a barrier? Increases life of the well Lowers maintenance costs Verifies barrier integrity Maintains barrier envelope seal integrity 20 / 24 Calculate the gradient for the density of 2 ppg natural gas. 0.106 psi/ft 0.102 psi/ft 0.104 psi/ft 0.060 psi/ft 21 / 24 How does an increase in well temperature affect a fluid barrier? Not enough information Increase hydrostatic pressure Decrease hydrostatic pressure Temperature has no effect on fluid barrier 22 / 24 Calculate the annular volume for 8,500’ of 2 7/8” tubing with 2.441” ID and 2.347” drift. Casing is 7”, 26 ppf, 6.276” ID. 256.98 bbls 268.34 bbls 276.04 bbls 336.35 bbls 23 / 24 Calculate the bbl/in of a 10’W x 8’H x 12’L tank. 1.78 bbls/in 1.75 bbls/in 2.04 bbls/in 2.10 bbls/in 24 / 24 Calculate the formation gradient with the surface pressure from the following information: Fluid weight = 6.5 ppg / SP = 250 psi / TVD = 6,000 ft / MD = 6,500 ft 0.38 psi/ft 0.41 psi/ft 0.052 psi/ft 0.58 psi/ft Your score is LinkedIn Facebook Twitter VKontakte
