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Maximum temperature limit of annular preventer is 180 correct. The mud hydrostatic pressure is more than formation fluid pressure. A kick has been swabbed on the last connection. What will happen to the casing pressure when the bit is on bottom? Nevertheless, it is important to properly read the answer before discounting any inappropriate activity. 1 psi/ft After 30 minutes both pressures have risen by 150 psi due to gas migration. No, it depends on the mud level in the annulus and the formation pressure. Fill the annulus with water (or lightest mud available) and record volume. Well control questions and answers pdf download. Worked Questions And Answers Iwcf.... filetype: PDF Download - Read Online. 0 of 25 questions answered correctly. Cell phones may not be used during the test. While pulling out of the hole the weight indicator fluctuates due to tight spots what will be its effect? IWCF WELL CONTROL KILL SHEET. Ability of rock to allow formation fluids to flow through it.

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Have slow circulating rate pressure losses to hand at all times. While drilling, which of the following situations make kick detection with a P. V. (Pit Volume Totalizer) more difficult for the driller? Know how to get SIDPP with a float in the string. From A well control point of view, what is the primary reason for performing a check trip followed by bottoms up circulation? Well Control Questions. TWO stands of drill collars are pulled from the well (dry) Drill collar capacity. Circulation cannot start due to mechanical problems. WELL DATA Well depth 9-5/8 inch casing shoe 8-1/2 inch hole capacity Mud density. WELL DATA Casing capacity Drill pipe capacity Drill pipe steel displacement Mud density. 'a ctions' The first indication that more than one answer is required. IWCF WELL INTERVENTION EXAM. Weep holes have the primary function to tell people that the mud seal on the piston rod is leaking or not. C. Spot a viscous LCM pill on bottom.

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It takes 100 strokes to displace surface lines. Vent line length = 210 ft. SCR's should be read on the drill pipe pressure gauge at the remote choke panel. The mixing pump used to fill the casing malfunctioned for 40 minutes, however the Driller continued to run 12 joints of casing into the well without filling up the casing. Well control questions and answers pdf document. What is the proper position of the safety valve (TIW valve) on the rig floor? 5700 ft 6315 ft. 15 ft. ft Gas Oil Communication. 1570 psi pressure loss through bit nozzles.

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Perhaps you remember the Macondo Blowout (Deep Water Horizon Rig) disaster. Drilling a mere 3 ft (1 m) out of the casing shoe is usually not sufficient to get into new formation. What will happen to the casing pressure? With the bit on bottom, no non-return valve in the string. 13-3/8 in casing is run into the well. A- Nozzle plugged b- Hole pack-off c- Choke plugged d- Washout in the drill string 89. Data: True vertical depth 8320 ft Drilling fluid 12. The trip tank was lined up on the well. Well Control Exercises - PDFCOFFEE.COM. A- Turn on the pump at a slow speed with moving and rotating the pipe, Records the pressure readings from the remote choke panel. What should he do next? If you want to ask a new question then there is a question entry box further down. C- Preventing the flow of formation fluid into the well bore by keeping the dynamic pressure loss in the annulus equal to or greater than formation pressure.

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Pump remaining stands out of the hole. This figure shows that: - blind rams isolate both the pipe and the annular space by crushing the pipe and it pinching-off when closed; - shear rams isolate both the pipe and the annular space by shearing-off the pipe when closed; - blind shear rams isolate both the pipe and the annular space by shearing-off and crushing the pipe when closed; - pipe rams isolate the annular space by wrapping around the pipe when closed. Quiz is loading... You must sign in or sign up to start the quiz. When kill mud reaches the bit. Tricky Questions and Well Control Equipment. 03 bbl/ft Internal capacity of casing 0.

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When starting to kill the well, keep the choke pressure as close as possible to the Shut In Casing Pressure. Highly trained drillers. Well Shut-in Procedures 53. Volumetric Method/Stripping 56. The total time to kill the well will be longer than calculated. Some questions require more than one answer – the candidate must select the requested number of answers. 442 psi/ft c. 42 psi/ft d. 465 psi/ft. Required answer 1 A……………………… psi 16. This would be a complex situation without a simple answer. A partial lost circulation has occurred. When the influx is above the casing shoe. There's no difference between using the driller's method or the wait and the weight method kill operation is ready to start. Surface pressure psi 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 400 200 0 1 0 2. Well control questions and answers pdf free. bbl pumped. A- 4580 psi b- 3260 psi c- 2980 psi d- 3780 psi.

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The drillpipe gauge on the remote choke panel. You have reached 0 of 0 points, (0). 1 psi/ft which together with the influx volume will be used to determine the formation pressure and kill mud weight c- Start pumping very slowly in to the drill pipe with the well shut in. Slow circulating rate. When the influx reaches the BOP stack. 0758 bbl/ft Stand length: 93 ft Calculate the drop in mud hydrostatic pressure if ten stand of pipe are pulled 'wet' from the well (no returns from inside of pipe back to the well) ………………………………psi 43. Kicks that lead to blowouts are such an uncommon occurrence that there is no need to make provision for them when planning a well a- True b- False. Water is recommended fluid for BOP test because it has less compressibility. Calculate the speed of gas migration in feet per hour. Drill string pressure loss. Pump a cement plug into the annulus using the kill line.

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Below the question and in. C- Start pumping high density drilling mud in to the annulus. Control drilling rate so that only one slug of connection gas is in the hole at any one time. 13-3/8 in casing steel displacement 13-3/8 in casing average joint length Annulus capacity. Drill pipe capacity. Total volume fill is 60 bbl. 2 b- There is no way of knowing c- 11. After mud weight change. The wait and weight method is to be used the kill mud is ready to be pumped. You have to finish following quiz, to start this quiz: Results. The formation fluid pressure that exceeds formation water hydrostatic pressure. A- Decrease pump rate b- Open choke more c- Continue, everything is OK. 70. Current mud weight is 12.

C A B B A-B C-D B C A-E A B A C B B A D A-C-E A-C-F B C D B-C-D-E B-C-D-E B C-D-E A-D-E B B C B A D-E C B B B. The plan is to run in the hole to 6200 feet TVD (6600 feet MD) and displace with drill water (8. During the well planning, do we need to plan for BOP? D- Preventing the flow of formation fluid into the well bore by using BOP equipment when the hydrostatic pressure in the well bore does not balance or exceed the formation pressure.

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