Well Servicing Operations 0 Well Servicing Operations 1 / 30 Using additional blind-shear rams in the well control stack requires increasing the available useable volume of the closing unit. This statement is true This statement is false It depends There is no way to know 2 / 30 Which method would typically place the highest stress on the wellbore? Lube and Bleed Forward Circulating Reverse Circulating Volumetric 3 / 30 Which of the following can be used as a barrier element in snubbing operations? Annular BOP Trip tank Mud gas separator Fluid pump 4 / 30 Which of the following criteria is used in the selection of barrier elements? Pump rates Lifting/snubbing unit capacity Pressure rating Choke size 5 / 30 What is the function of the stuffing box in a wireline barrier envelope? Lubricate the wire Guide the wire into the lubricator Bleed off pressure Provide pressure seal on the wire 6 / 30 What is considered an internal snubbing barrier? Stripper ram Fluid weight Stab-in/safety valve Annular 7 / 30 What is NOT a function of blind shear rams? Seal on open hole Seal on pipe without damaging pipe Shears pipe Test casing 8 / 30 Where could tubular buckling occur? Any tubular under compression with sufficient unsupported length In only highly deviated wells Only tubulars under compression with high internal pressure Any tubing within the jack 9 / 30 Calculate the buoyancy factor, for a 13 ppg fluid weight. 0.799 0.68 0.831 0.801 10 / 30 Calculate the bbl/in of a 10’W x 8’H x 12’L tank. 1.78 bbls/in 2.04 bbls/in 2.10 bbls/in 1.75 bbls/in 11 / 30 Which of the following is most true concerning ovality of coiled tubing? Ovality issues are very rare with coiled tubing because there are no connections in the string Can significantly decrease collapse pressure rating Not a major concern as long as pipe rams and stripper test ok Ovality does not need to be measured after start of job 12 / 30 What method can be used to mitigate the risk of collapsed tubing due to excessive tensile load in relation to differential pressure? Bleed off annulus pressure Increase tripping speed Increase annulus pressure Decrease tubular pressure 13 / 30 When coiled tubing is near surface, what action is to be taken when there is a stripper assembly failure? Shut pipe rams and pull out of the hole Shut pipe rams and replace stripper element Replace stripper elements and circulate at depth Replace stripper rams and continue operations 14 / 30 When on or off bottom, what action is to be taken when there is buckled coiled tubing between injector and stripper assembly? Strip out of the hole Pump down coiled tubing Prepare to kill the well Close shear rams 15 / 30 Why would Bullheading be chosen over circulation? Hole in the tubing No choke manifold on location Packer leaking Collapsed tubing 16 / 30 Which of the following best describes the effect on bottomhole pressure caused by downhole tools while forward circulating? Reduced clearance, higher friction loss, higher bottomhole pressure Reduced clearance, lower friction loss, lower bottomhole pressure Increased clearance, higher friction loss, higher bottomhole pressure Increased clearance, lower friction loss, lower bottomhole pressure 17 / 30 Which method is used to remove gas from the well when circulating or bullheading is not possible and gas is at surface? Volumetric Lube and Bleed Reverse Circulation Forward circulation 18 / 30 What parameter is used to determine size of flow tube for wireline operations? Pressure in well Fluid in well Grease injection rate OD of wireline 19 / 30 Which of the following could cause high bending stresses on the wellhead connection when running Wireline PCE? Vessel movement Pumping at high rates Wireline valves positioned directly on wellhead Large unsupported lengths of lubricator 20 / 30 Which of the following is an operating limit of BOP equipment? Fluid weight Hole angle Measured depth Rated Working Pressure of Equipment 21 / 30 What contributes to downward forces in a snubbing operation? Tubing weight Perforation depth Burst pressure of the tubing Tubing yield strength 22 / 30 What can happen when pulling a slickline back pressure valve (BPV)? Tubing can part Tool string and BPV can be dropped in the well Threads can become damaged Tool string becomes stuck across tree preventing closing in the well 23 / 30 For coiled tubing operations, which of the following is NOT true concerning slip rams? Are pressure sealing Used to support the tubing weight when realigning or shearing pipe Teeth should accommodate both pipe light and pipe heavy situations Will damage the coiled tubing when operated 24 / 30 A shut-in well at 10,000’ with a gas influx volume of 5 bbls, what is the gas bubble pressure as the influx migrates to 2,500’? Formation pressure is 4,000 psi. 2,000 psi 4,000 psi 16,000 psi 8,000 psi 25 / 30 Which of the following is NOT a potential well control problem during through-tubing well intervention operations? Snubbing stationary slips failing while in pipe light conditions Leak at the flange connection below the wireline valve Coiled tubing buckling between the stripper and injector chains preventing movement of the coiled tubing Breaking the casing shoe down when conducting a leak off test 26 / 30 Why is a guide ram used in snubbing operation? To centralize a large BHA To prevent well control problems To prevent pipe buckling within the BOP stack To seal on the pipe 27 / 30 What factor can impact the wear rate of the stripper element? Lack of lubrication of the coiled tubing Kill line pressure Coiled tubing circulation rate Outside air temperature 28 / 30 What action should be taken if there is a test failure of a mechanical well barrier/element? Proceed cautiously Retest at a lower pressure Record failure and retest at same pressure Small leaks are acceptable 29 / 30 What can cause the well to be swabbed in? Pulling a packer too fast Running in hole with a packer too fast Increase fluid weight Pumping above fracture pressurePumping above fracture pressure 30 / 30 What is needed to determine pump rates to circulate or kill the well? Gas migration speed Elevation of rig rotary table Size of influx Well plug back depth Your score is LinkedIn Facebook Twitter VKontakte
