Choke Line Friction 0 Choke Line Friction SCR-(number) 1 / 14 What is the reason for flushing the choke and kill lines with drilling fluid? To lubricate the failsafes To measure the slow pump pressure (SPP) To allow the failsafes to remain open during drilling operations To prevent blockages due to settling of mud solids 2 / 14 After the well was shut-in, a decision was made to measure the choke line friction by closing the annular and the lower pipe ram, pumping down the kill line, across the BOP, up the choke line and through a wide-open remote choke. The pump pressure during this operation was 175 psi and choke pressure was 25 psi. Calculate the choke line friction through 1 line. 175 psi 75 psi 100 psi 150 psi 3 / 14 The well kill plan asks that the subsea kill operation is initiated by bringing the pumps to the reduced pump rate by holding the casing pressure (CP) constant. What would happen to the bottom hole pressure (BHP)? BHP would increase by the choke line friction (CLF) BHP would decrease by the choke line friction (CLF) BHP would stay the same There is no way to know 4 / 14 Considering the options below, what is the best method of reducing choke line friction by 75 % during a well kill operation on a subsea stack rig? By taking returns simultaneously up the choke and kill lines. By reducing the pump speed by 25 % (example: reduce pump speed from 40 to 30 spm). By reducing the pump rate by 75 % (example: reduce pump speed from 40 spm to 10 spm). By displacing the choke line with a heavier fluid. 5 / 14 Considering the options below, what is the best method of reducing choke line friction by 75 % during a well kill operation on a subsea stack rig? By reducing the pump rate by 50 % (example: reduce pump speed from 40 to 20 spm). By reducing the pump speed by 25 % (example: reduce pump speed from 40 to 30 spm). By reducing the pump rate by 75 % (example: reduce pump speed from 40 spm to 10 spm). By displacing the choke line with a heavier fluid. 6 / 14 Use the provided data to answer the question below: SIDPP = 300 psi SICP = 800 psi KLP = 800 psi MACP = 1500 psi SPP at 30 SPM = 500 psi CLF at 30 SPM = 150 psi Mud Weight = 11 ppg 7 / 14 What would be the Kill Line Pressure (KLP) after the pump is running at the desired kill rate of 30 SPM? 650 psi 950 psi 800 psi 400 psi 8 / 14 What would be the Casing Pressure (CP) after the pump is running at the desired kill rate of 30 SPM? Also called the Dynamic Adjusted Casing Pressure. 650 psi 950 psi 800 psi 400 psi 9 / 14 Considering the options below, what method of obtaining the Choke Line Friction will cause the most increase in Bottom Hole Pressure? By pumping down the choke or kill line up the marine riser By pumping down the kill line, across the BOP with both lower rams and annular closed and up the choke line By pumping down the drill string, up the annulus and up the choke line with BOP closed All of the above methods will cause the same increase in BHP 10 / 14 What would be the Maximum Allowable Casing Pressure (MACP) after the pump is running at the desired kill rate of 30 SPM? Also called the Dynamic MACP. 1350 psi 1500 psi 1650 psi 800 psi 11 / 14 Calculate the choke line friction (CLF) using the information below: Line-up: pumping down the choke or kill line up the marine riser Pump pressure = 250 psi BOP stack pressure = 1500 psi Mud Weight = 10 ppg Well Depth = 10000 ft TVD / 12000 ft MD 250 psi 1500 psi 5200 psi 6240 psi 12 / 14 Calculate the choke line friction (CLF) using the information below: Line-up: pumping down the kill line, across the BOP with both lower rams and annular closed and up the choke line Pump pressure = 300 psi Casing or Choke Pressure (CP) = 50 psi BOP stack pressure = 2000 psi Mud Weight = 10 ppg Well Depth = 10000 ft TVD / 12000 ft MD 300 psi 250 psi 125 psi 350 psi 13 / 14 Calculate the choke line friction (CLF) using the information below: Line-up: pumping down the drill string, up the annulus and up the choke line with BOP closed Pump pressure = 800 psi Slow pump pressure = 300 psi Casing or Choke Pressure (CP) = 50 psi BOP stack pressure = 2000 psi Mud Weight = 10 ppg Well Depth = 10000 ft TVD / 12000 ft MD 800 psi 450 psi 350 psi 1150 psi 14 / 14 Consider the information below to answer the following question: Well Depth = 11000 ft TVD / 13000 ft MD Mud Weight = 11.2 ppg Slow Pump Pressure (SPP) @ 40 SPM = 550 psi Choke Line Friction (CLF) @ 40 SPM = 425 psi Maximum Allowable Casing Pressure (MACP) = 1275 psi Kick Data: Pit Gain = 15 bbls SIDPP = 200 psi SICP = 400 psi What would be the problem if the decision was made to kill the well at a reduced pump rate of 40 SPM? CLF exceeds the SICP so a slower pump rate must be chosen CLF would bring the Casing Pressure (CP) too close to the MACP increasing the risk of losses CLF plus the SPP in addition to the mud hydrostatic pressure in well could potentially cause losses There is no problems associated with killing the well at 40 SPM Your score is LinkedIn Facebook Twitter VKontakte
