So, we have discussed the role of drilling fluid to exert pressure on porous and permeable formations and to coat them with an impermeable filter cake to help prevent kicks from occurring. The SICP was higher than SIDPP. Iwcf Well Control Practice Test.... filetype: PDF Download - Read Online. Pressures during Killing 80. Each question contains 3 possible answers and there is full explanation for each one.
Pressure has built up between two casing strings in a well, a poor cement job has been performed on the inner casing string, what could the consequences of this pressure buildup be? 150 psi pressure loss through surface equipment. Drilling fluid density in the hole is 10 ppg.. Top of reservoir is at 9500 feet. Iwcf Well Control Practice Test. During the testing period, you may ask questions if you need clarification of a question. Use the given information: True vertical depth of well Open hole capacity Casing shoe MD Casing size 9-5/8" x 53.
Ask yourselves some technical questions: - What type of offshore drilling rig was the Deep Water Horizon? A well is being killed with a constant bottomhole pressure method. Drill pipe steel displacement. If a kick is shut in on a surface BOP stack and the slow circulating rate pressures is not known. Start the kill operation. Pump lost circulation material immediately. What is the most common cause of abnormally high formation pressures worldwide? A well has been drilled to depth 8200 ft TVD and the current density of drilling mud is 12. Calculate the maximum equivalent drilling fluid density at the casing shoe. International Well Control Forum.
During well control operation, you need to reduce choke size regularly because casing and drill pipe pressure keep dropping without any adjustment on the pump speed. The blowout preventer is a large system of valves each of which is capable of isolating the subsurface of the well from the rig to provide control over the well. Surface pressure psi 2800 2600 2400 2200 2000 1800 1600 1400 1200 1000 800 600 400 200 0 1 0 2. bbl pumped. Additional information: IWCF stands for The International Well Control Forum which is an oil industry Membership Organization established in Europe in 1992. This again may be an indication of a kick. This preview shows page 1 - 5 out of 53 pages. 2 b- There is no way of knowing c- 11. After drilling a large footage (up to 1000'). In addition, if it is a gas kick, due to the compressible nature of gas, as the gas bubble travels up-hole and hydrostatic pressures decrease, the volume of the bubble will increase due to expansion. The difference in density between oil and formation fluid. PDF file for free, Get many PDF Ebooks from our online library related with. Name||Entered on||Points||Result|. Subtract the 10 bbl (converted to pump strokes) from the total strokes to be pumped.
Most of oil companies have the policy that there must be a float installed in the drillstring. Annular gauge = 500- 1, 500 psi. Overbalance 200 psi Mud gradient 0. In the first objective re-quoted above, if we can keep the pressure exerted by the drilling mud greater than the pore pressure, then we know that fluids will flow in the direction of the mud to the formation. 13-3/8 in casing is run into the well. A. b. c. d. All Mechanical barrier. Pump remaining stands out of the hole. 0 x 7, 681 = 4, 793 psi. Calculate the MAASP using the following information: WELL DATA Casing Shoe Depth (TVD) 6000 ft Maximum Allowable Mud Density 15. Which of the following parameters could be affected by a string washout during a well kill operation (TWO ANSWERS) a- Slow circulating rate pressure b- Bottom hole pressure c- Formation fracture pressure d- Kick tolerance.
Drill out the casing shoe and in to the new formation. 0075 bbl/ft Pipe capacity: 0. A schematic diagram of a blowout preventer is shown in Figure 9. Re-Zero stroke counter after 100 strokes are pumped. After a round trip @9100 ft with 11. A- Nozzle plugged b- Hole pack-off c- Choke plugged d- Washout in the drill string 89.
Only in horizontal wells. 13 provides a schematic of the annular preventer. Which of the following need to be known for a leak-off test to be correct? 0061 bbl/ft BHA steel displacement 0. The choke has been adjusted to increase the drillpipe pressure by 200 psi while the pump speed is held constant at 35 SPM.
We have also discussed the role of the blowout preventer and company procedures to control a kick once one occurs. To verify that the pressure surge during the running in of the pipe will not lead to lost circulation b. 680 psi pressure loss in drill string. Test strength of shoe and formation to designed pressure by increasing surface pressure until it reaches the required pressure only. D- Formation break down. Which of the following statements about the formation of hydrates are correct?
………………………………….. psi. 157 bbl/ft Drill pipe metal displacement 0. Yes, losses will always occur above any potential kick zone. Drill pipe pressure and casing pressure are gradually rising. Most likely from this case is choke wash out because the casing and drill pipe pressure keep decreasing without changing pump rate.
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