1. Which of the following possible warning signs indicate that well may go under balance? (Select two answers) a. Increase in pump pressure. b. Reduction in rate of penetration. c. Change in cuttings size & shape. d. Increase in weight on bit. e. Increase in drilled gas percentage. 2. Which one of the following is the first reliable indication that well is flowing? a. Increase in torque. b. Gas cut mud. c. Decrease in pump pressure. d. Increase in return flow. 3. After recognizing a drilling break, what is the first action to be taken? a. Make a flow Check b. Circulate bottoms up c. Continue drilling d. Reduce pump speed 4. What is meant by Primary Well Control? a. The use of Blow out Preventers to close in a flowing well. b. The slow circulating rate pressure used in the kill process. c. The use of mud hydrostatic to balance fluid pressures in the formation. d. The use of pit volume and flow rate measuring devices to recognize a kick. 5. Will a kick always occur in the event of a loss of return? a. No, it depends on the mud level in the annulus and the formation pressure. b. No, it depends on the drill string weight reduction noted on the weight indicator. c. Yes, losses will always occur above any potential kick zone. 6. A well was flowing when in static condition (i.e. when not circulating) but was not flowing during the circulation. What could be the possible reason? a. Pressure loss in drill string caused over balance while circulating at the bottom b. Pressure loss across the bit caused over balance while circulating at the bottom c. Pressure loss in the annulus caused over balance while circulating at the bottom
7. Why the stand pipe pressure gauge shows little less pressure than pump pressure gauge? a. Because of the gauge error. b. Because of the hydrostatic head of the mud in stand pipe. c. Because position of stand pipe pressure gauge is lower than pump pressure gauge. d. Because of the dynamic pressure losses from pump to the stand pipe. 8. Which of the following contributes to Equivalent Circulating Density? a. Drill sting pressure losses b. Annulus pressure losses c. Drill bit pressure losses d. Pressure loss from pump to the string 9. Which of the following factors will increase the circulating pressure? (Select two answers) a. Use of bigger size of bit nozzle b. Increase in the length of BHA c. Increase in the drilled depth d. Decrease in the mud density during drilling 10. Which one of the following causes of well kick is totally avoidable and is due to lack of alertness of driller? a. Lost circulation b. Gas cut mud c. Abnormal pressure d. Not keeping hole full 11. Calculate the new slow circulating pressure at 30 spm if mud weight has been increased from 10 ppg to 13 ppg: Recorded data: SCR @ 30 spm : 400 psi Drilled depth : 9587 ft Mud density : 10 ppg a. 333 psi b. 520 psi c. 480 psi d. 525 psi
12. While drilling, pump pressure was 3000 psi at 80 SPM with 11 ppg mud. What will be the approximate pump pressure, if the pump speed is reduced to 60 SPM & mud weight increased to 13 ppg? a. 2,250 psi b. 1,828 psi c. 2,400 psi d. 1,888 psi e. 1,995 psi 13. Which of following practices are likely to increase the chances of swabbing? (Select three answers) a. Pulling pipe slowly. b. Maintaining high mud viscosity. c. Pulling through tight spots with pumps off. d. Pulling pipe fast. e. Pulling through tight spots with pump on. 14. A vertical well is drilled to a depth of 9,500 ft with 11.8 ppg mud, following are the recorded data: WELL DATA: Pump speed 70 spm. Pressure losses in surface equipment 140 psi Pressure losses in drill string 800 psi Pressure losses in annulus 100 psi Pressure losses at bit nozzles 1400 psi a. Calculate Bottom Hole Pressure when well is static ______ psi b. Calculate B H P when mud is circulated at 70 spm _____ psi c. Calculate pump pressure when mud is circulated at 70 spm ______ psi d. Calculate the equivalent circulating density ______ ppg 15. In a well, during trip out swabbing was suspected. The flow check was negative and it was decided to run back to bottom (30 stands) checking for flow after lowering every 5 stands. The flow checks after 5, 10, 15 &s 20 stands showed no flow. But with stand number 25 back in the hole, the well was found to be flowing. A What could be the most likely cause of the well flow? a. Abnormal formation fluid pressure. b. Derrick man mixed too light a slug prior to pulling out of the hole.
c. Running into the swabbed fluids caused hydrostatic pressure in annulus to drop. d. ln the hurry, it was forgotten to slug the pipe while preparing for running back. 16. While tripping out of the hole it is noticed that mud required to fill the hole is less than calculated. What action must be taken? a. Shut the well in and circulate to clean the hole. b. Flow check, if negative continue to pull out of the hole. c. Flow check, if negative run back to bottom and monitor returns. d. Flow check, if negative displace a heavy slug into annulus and continue pull out. 17. Calculate with following data: Drill Pipe Capacity = 0.0176 bbls/ft Drill Pipe Metal Displacement = 0.0082 bbls/ft Average Stand Length = 90 ft a. Mud required to fill the hole per stand when pulled `dry‘ ____ bbls. b. Mud required to fill the hole per stand when pulled `wet‘ ____ bbls. 18. With following well data, calculate the reduction in bottom hole pressure if a driller has pulled out 15 stands of 5″ drill pipe dry, without filling the hole. Drill pipe capacity – 0.0178 bbl/ft Drill pipe steel displacement – 0.0080 bbl/ft . Casing capacity – 0.0744 bbl/ft Length of one stand – 88 ft Mud weight – 13 ppg Reduction In BHP – _____ psi 19. What will be the reduction in bottom hole pressure if 5 stands of drill pipes are pulled out wet without filling the hole? (Mud bucket was not used) One stand length : 90 ft Casing Capacity C : 0.0836 bbls/ft Drill Pipe Capacity : 0.0177 bbls/ft Drill pipe steel displacement : 0.0080 bbls/ft Mud Weight · : 14 ppg a. 129 psi b. 412 psi c. 91 psi d. 145 psi
20. With following well data, calculate the no. of 92 ft length stands that can be pulled out dry before the well starts to flow. Well Depth : 9,750 ft TVD Casing Shoe Depth : 5,630 ft TVD Mud Gradient : 0.696 psi/ft Formation Pressure : 6,625 psi Casing Capacity : 0.1568 bbl/ft Open Hole Capacity : 0.1483 bbl/ft Drill pipe Metal Displacement ‘ : 0.0080 bbl/ft Drill Pipe Capacity : 0.01776 bbl/ft 21. In a well while tripping out the hole was filled durin pulling drill pipes. Thereafter the trip tank pump was stopped and the complete BHA was pulled out dry. Using following data, calculate approximate reduction in the bottom hole pressure. BHA length — 531 ft BHA capacity – 0.009 bbls/ft A BHA Steel Displacement – 0.068 bbls/ft Annular Capacity BHA to 13 3/8″ Casing – 0.07 bbls/ft Casing capacity – 0.147 bbls/ft Mud Density – 11 ppg a. 278 psi b. 141 psi c. 115 psi d. 211 psi 22. What does Abnormal Pressure mean with regard to fluid pressure in the formation? a. High Density mud used to create a large overbalance. b. Formation fluid pressure that exceeds saline water hydrostatic pressure. c. The excess pressure that needs to be applied to cause “Leak -off” in a normal pressured formation. 23. It was decided to reduce the mud weight from 11.4 ppg while tripping in the well of 9,780 ft TVD. String was run to 5,700 ft and original mud was displaced by 10.8 ppg mud.
a. What will be the bottom hole pressure now ? ______ psi b. When string was run down to bottom the entire well was displaced by 10.6 ppg mud. Calculate the bottom hole pressure in static condition. ______psi 24. A gas bearing formation is over pressured by an artesian effect. Which of the, following condition has created the over pressure? a. Compaction of the formation from the over burden. b. Formation water source located at a higher level than the rig floor. c. The difference in length between gas & formation fluid. 25. Worldwide, what is the most common cause of abnormal formation pressure? a. Depleted sands b. Carbonate layers c. Under compaction of shales 26. At a depth of 1300 ft the formation pressure is 650 psi. This formation pressure is: a. Abnormal Pressure b. Normal Pressure c. Sub normal Pressure 27. What is the definition of MAASP? a. The maximum BHP that can be allowed during kill operation. b. The maximum drill pipe pressure that can be allowed during kill operation. c. The surface pressure in excess of mud hydrostatic that if exceeded is likely to cause, losses at shoe. d. The total pressure applied at casing shoe that can cause losses at shoe 28. While drilling, the mud weight was increased from 10 ppg to 11.2 ppg expecting little higher formation pressure below. How this increase of mud weight will affect MAASP (the casing shoe is at 4697 ft TVD)? a. Decrease by 250 psi b. Increase by 293 psi c. Decrease by 293 psi
29. How often should the MAASP be recalculated? a. After every bit change b. After a change in mud weight c. After every 500 ft. drilled 30. Which of the following parameters will affect the MAASP? (Select two answers) a. Casing capacity b. Mud density is use c. Casing shoe depth d. Formation pressure e. Fracture pressure at casing shoe 31. After lowering casing, which of the following operations are to be taken care of prior to conducting a leak—off test. (Select two answers) a. Drill casing shoe and about 10 ft In to new formation. b. Keep the bit close to bottom. c. Circulate and condition the mud to get uniform column of mud inthe well. d. Line up pump to conduct leak off at slow circulating rate. 32. Which one of the following would affect Leak-Off Test pressure? a. Hydrostatic Pressure at Casing Shoe. b. Mud Pump circulating rate c. Volume of the annulus from shoe to surface d. Pressure limit of the pump e. Inclination of the well at casing shoe. · 33. Which of the following are important for the calculation of formation strength at the shoe? (Select three answers) a. Accurate pump strokes counter. b. Accurate pressure gauge. c. Exact mud density. d. Exact vertical depth of casing shoe. e. Accurate hole capacity. 34. A casing is set at a depth of 7260 ft and true vertical depth of casing shoe is/6298 ft. After drilling shoe and new formation, leak off test was conducted with 11.2 ppg mud. It was found that the formation strength is 5400 psi.
Find out the maximum allowable annular surface pressure (MAASP). a. 1117 psi b. 1732 psi c. 5400 psi d. 592 psi 35. Calculate the following with the data given below: Well Depth = MD 15,150 ft / TVD 13,900 ft Casing Shoe Measured Depth = 11,100 ft Casing Shoe True Vertical Depth = 10,100 ft Casing Shoe leaked with 10 ppg mud at = 1800 psi a. Maximum allowable mud weight ______ ppg b. New MAASP with 11 ppg mud ______ psi c.New MAASP with 12.5 ppg mud at 13,900 ft TVD ______ psi d. Casing shoe fracture strength ______ psi 36. After detecting a kick, well was shut-in and stabilized shut-in pressures were: SICP – 700 psi SIDPP – 540 psi Pit gain – 20 bbls While calculating for kill mud , both pressures started rising. Tool-Pusher instructed driller to maintain casing pressure constant using choke. What will happen to bottom hole pressure? . a. Increase b. Decrease c. Remain same 37. Which of the following are considered to be good operating practices in Top Hole where there is a risk of shallow gas? (Select two answers) a. Circulating while pulling out of the hole on trips. b. Use high density mud to create maximum overbalance. c. DrilI a pilot hole. d. Maintain high rates of penetration to ensure mud viscosity level is high. e. Regularly pump fresh water pill to remove the cuttings from the hole.
38. Which ofthe following drilling practices would be considered when connection gas is noticed? (Select two answers) a. Pulling out of the hole to change the bit. b. Raising the mud yield point. c. Minimizing the time during a connection when the pumps are switched off. d. Controlling drilling rate so that only one slug of connection gas is in the hole at a time. e. Pumping a low viscosity pill around bit to reduce balling up of bit or stabilizers 39. While drilling on a land rig, shallow gas was detected and flow was diverted by closing diverter. What action should be taken? a. Increase the pump discharge. b. Decrease the pump discharge. c. Reduce pump speed. 40. Which of the following practices should be followed to prevent losses in top hole drilling? a. Use of high mud weight. b. DriIIing with low circulating rate to reduce circulating pressure loss. c. Drilling with controlled rate of penetration. d. Pump cement into the annulus. 41. While drilling a vertical well at a depth of 9,000 ft with 13 ppg/mud, gas cut mud was observed at shale shaker. Tool Pusher decided for bottoms—up monitoring of out coming mud .The following were the recorded data: Depth Interval Average MW 0 — 900 ft 12.2 ppg 900 -1500 ft 12.5 ppg 1500 — 9000 ft 13.0 ppg Due to the gas cut mud, how much was the reduction in bottom hole pressure? a. 38 psi b. 108 psi c. 54 psi
42. During slip & cut what is installed on the Drill Pipe? a. Fosv b. Inside BOP 43. How should the choke be set up for the soft shut-in procedure while drilling? a. BOP side outlet hydraulic choke line valve open Remote choke closed Valve upstream mud gas separator closed b. BOP side outlet hydraulic choke line valve closed Remote choke open Valve upstream mud gas separator open c. BOP side outlet hydraulic choke line valve closed Remote choke closed Valve upstream mud gas separator open d. BOP side outlet hydraulic choke line valve open Remote choke open Valve upstream mud gas separator closed 44. Which list below describes as to how the choke manifold will most likely be set up for soft shut-in while drilling? Choke line Auto choke MGS Hydraulic Valve Valve List A. Open Closed Closed List B. Open Open Closed List C. Closed Open Open List D. Closed Closed Open 45. What action should be taken if the choke line parts between the HCR valve and the remote choke while circulating out a kick? a. Stop pump and close the choke. b. Stop pump and close HCR. c. Stop pump and close the shear rams. 46. Which one of the following be the first action to be taken, if the mud pump safety valve pops—off or hose going to the drill string is parted while circulating out a kick? a. Drop the drill string, close blind/shear rams, close the choke. b. Stop the pump, close the choke. c. Stop the pump, close kelly cock, close choke.
47. Listed below are the two shut-in procedures for handling a kick according to API RP 59 for surface BOP stack: a. With choke open, pick up off bottom, shut down pumps, open HCR, close BOP, close choke. b. With choke already closed, pick up off bottom, shut down pumps, close BOP open HCR. Match the two procedures. Titles Procedures 1. Soft shut in = ______ 2. Hard shut in = ______ 48. What is inside BOP? a. An equipment that can be installed in drill string to act as non return valve b. A ball valve installed immediately above the bit c. Small element inserted in to annular preventer to reduce inside diameter 49. lf a non return valve or inside BOP is installed in the drill string following a kick whilst tripping, which one of the following statements is false? a. The drill string can be stripped back to bottom. b. Wire line tools can be run to the bit. c. Kill mud can be pumped in the well. 50. Which of the following most correctly describes the procedures to be followed for a hard shut in during tripping as per API RP 59? a. Stab full opening safety valve. Close safety valve. Close BOP. Open HCR. b. Stab full opening safety valve. Close safety valve. Open HCR. Close BOP. c. Make up kelly. Open HCR.
Close BOP. Close choke. 51. While tripping into the hole, flow meter showed well flowing, which of following shut in procedure should be followed for soft shut-in on a surface stack? a. Stab a full opening safety valve. Close the safety valve. Open HCR. Close BOP. Close choke. b. Close the BOP. Stab full opening safety valve. Close the safety valve. Open choke. Close choke. c. Stab full opening safety valve. Open HCR and choke. Close BOP. Close choke. 52. On shutting a flowing well, the drill pipe pressure is `0’ because there is a float in the string. To determine the SIDPP, what action should be taken? a. Bring the pump up to kill rate holding the casing pressure constant by opening the choke. The pressure shown when the pump is at kill rate is SIDPP b. Pump very slowly into the drill pipe with the well shut in. When the pumping pressure stabilises the float has opened. This pumping pressure is the SIDPP c. Shearing the pipe and reading the SIDPP directly off the casing gauge 53. Which of the following are good practices for drilling top hole section ? ( Select 3 Answers ) a. Mud Wt. as low as possible to prevent formation fracture b. Continuous circulation while picking up for connection c. Controlled drilling rate d. As high overbalance as possible to avoid gain due to underbalance e. Maintain high penetration rate
54. A kick has been shut in with the bit 32 stands off bottom, A drill pipe safety valve (full opening type) is installed on the drill pipe. To strip back to bottom what additional equipment is required, what position should the valves be in, and how the equipment be made up onto the string in order to perform the stripping operation safely, assuming there is no float sub or dart sub in the string. a. The drill pipe safety valve in the open position with an inside BOP installed on top b. Only the drill pipe safety valve in open position c. Only the drill pipe safety valve in the closed position d. Only an inside BOP e. An inside BOP with a drill pipe safety valve installed on top in the closed position 55. (i) Which of the following situations require recording of a slow circulating rate pressure? (Select two answers) a. Only after drilling out casing shoe. b. At beginning of each shift. c. Every time mud density is changed. (ii) When should the slow circulating rate pressure be recorded? (Select three answers) a. With bit near the bottom. b. When bit nozzle size is changed. c. After installation of BOP. d. After liner size of pump is changed. 56. Which of the following should be considered while selecting kill rate SPM? (Select two answers) a. Formation pressure. b.Volume handling capacity of the choke. c. Capacity of kill mud preparation. 57. Which of the following should be considered for slow circulating rate ? (Select three answers) a. Rated working pressure of mud pump b. Rated working pressure of BOP c. Casing capacity d. Barite mixing capability e. Gas handling capacity of mud gas separator
58. The influx is usually circulated out at a pump rate considerably slower than that used while drilling. Select the correct reasons for this from the list below:(Select four answers) a. To enable the choke operator to make the necessary choke adjustment. b. To reduce the pressure being exerted on the open hole. c. To get adequate time to dispose off the kick fluid at surface. d. To allow tool pusher to contact town. e. To reduce the chances of washing-out of the choke. f. To reduce the chance of gas migration. 59. A gas kick is easier to detect in water based mud than in oil based mud. True Or False 60. Hydrocarbon gas is soluble in water based mud than in oil based mud. True Or False 61. Which of the following statements are true for oil base mud? (Select two answers) _ a. Initial pit gain will be less b. Flow check should be made for 15 – 30 minutes c. Initial pit gain will be more d. Flow check should be made for only 2 — 3 minutes 62. Which of the following statements are true? (Select three answers) a. SICP will be more in water based mud than oil based mud b. SICP will be less in water based mud than oil based mud c. Gas will reduce less hydrostatic pressure in oil base mud than water base mud d. Gas will reduce more hydrostatic pressure in oil base than water base mud e. Gas expansion will be at the same rate in oil base mud and water base mud f. lt is easy to detect gas kickin water based mud than oil based mud 63. Why shut in casing pressure is usually higher than shut-in drill pipe pressure? a. The cuttings inthe annulus are lighter. b. The influx is usually less dense than the existing mud weight.
c. SICP is not necessarily higher, it depends on offshore or land operation. d. The only difference is in the gauges used. 64. While drilling a horizontal section of a well, self flow was observed and well was shut-in. Influx is still in the horizontal section. Which of the following is true? a. SIDPP will be more than SICP. b. SICP & SIDPP will be approximately same. c. SICP will be more than SIDPP. 65. In an open well with gas cut mud when BHP reduces the most? a. When the gas is at the surface b. When the gas is at bottom c. When the gas is at the casing shoe d. No, it remains same through-out. 66. Calculate the shut-in casing pressure with the following data: SIDPP – 300 psi MW – 12 pps . Height of the influx – 365 ft Influx weight – 8.4 ppg a. 300 psi b. 368 psi c. 394 psi 67. Which of the following will increase the risk of exceeding the MAASP during a well kill operation? (Select three answers) a. Small difference between formation breakdown and mud hydrostatic pressure. b. Short open hole section c. Large influx d. Small influx · e. Large difference between formation breakdown and mud hydrostatic pressure f. Long open hole section 68. Which of the following equipment may warn of increase in formation pressure while drilling overbalance? (Select three answers) a. ROP meter
b. Pump pressure gauge c. Flow line Temperature gauge d. SPM counter e. Gas detector f. Return flow meter 69. Which of the following parameters will affect the SICP? (Select three answers) a. Formation pressure b. Drill string capacity c. Annulus capacity d. Bottom hole temperature e. Volume of influx 70. One manual valve and one hydraulically operated valve are normally fitted between drilling spool & choke manifold. Which of the following alternative option is preferred regarding the position of the above valves ? (Inside means near BOP and outside means away from BOP) . a. Inside manual valve , check valve and outside hydraulically operated valve. b. Inside hydraulically operated valve and ouside manual valve c. Inside manual valve and outside hydraulically operated valve 71. Which of the following situation make kick detection more difficult with PVT while drilling ? a. By passing solid control equipment b. Minimum mud transfer to active system c. Allowing mud loss by over flowing the shakers d. Reducing the range of high low alarm setting of PVT 72. A well was shut -in and the following readings were recorded: TIME SIDPP SICP 1000 hrs 250 psi 310 psi 1005 hrs 300 psi 370 psi 1010 hrs 350 psi 430 psi 1015 hrs 400 psi 500 psi 1020 hrs 410 psi 510 psi 1025 hrs 420 psi 520 psi 1030 hrs 430 psi 530 psi
What will be SIDPP? a. 460 psi b. 400 psi c. 430 psi d. Well is not yet stabilised wait for more time to know the exact SIDPP 73. A well was shut -in after a kick and following pressures were recorded: TIME SIDPP SICP 0600 hrs 300 psi 480 psi 0605 hrs 350 psi 540 psi 0610 hrs 400 psi 600 psi 0620 hrs 350 psi 500 psi 0625 hrs 200 psi 350 psi 0630 hrs 100 psi 180 psi 0635 hrs 50 psi 120 psi What probably might have happened in the well? a. Influx is migrating up in the well b. Drill string has parted ‘ c. Hole is packed around drill collar d. Weak formation in the open hole got fractured 74. You are drilling at fast rate. The well is shut in immediately after detecting a kick. Which of the following statement is correct: a. SICP would be higher as compared to slow rate of drilling. b. SICP would be lower as compared to slow rate of drilling. c. SICP would be same whether rate of drilling is slow or fast 75. Which of the following do not increase with closed well gas migration? a. Bottom hole pressure b. Casing shoe pressure c. Shut-in casing pressure d. Gas bubble pressure 76. For a long logging operation what should be installed on the drill pipe/shooting nipple? a. FOSV with wire line BOP b. Inside BOP
77. A well was shut in on a gas kick, SIDPP & SICP had stabilized. After sometime both start rising slowly by the same amount. What is the probable cause? a. A further influx is entering the hole. b. The influx is migrating up the Well Bore. c. The gauges are faulty. d. The BOP stack is leaking. 78. After shut—in & stabilization of surface pressures, which pressure is to be maintained constant to keep Bottom hole Pressure constant? a. Shut-in Drill Pipe Pressure. b. Shut-in Casing Pressure. c. Casing Shoe Pressure. d. Formation Pressure. 79. What is the position of degasser with respect MGS ? a. Downstream of MGS b. Upstream of MGS c. In the vent line of MGS d. Inside MGS 80. During Well Control Operation how complete loss zone can be recognised? a. Monitoring the return flow with the flow meter b. Monitoring the weight indicator c. Monitoring the pump SPM d. Monitoring the active mud tank volume 81. How remote choke is operated from remote choke panel? a. By air b. By hydraulic fluid c. By wire rope 82. Where is Shale Shaker placed ? a. Upstream of MGS b. Downstream of MGS c. Between Drilling spool and choke manifold 83. What should be the diameter of vent/bleed/straight through line in choke manifold?
a. 3″ in diameter b. 5″ in diameter c. At-least equal to the diameter of choke line 84. What is the function of vent/bleed/straight through line in the choke manifold? a. To bleed high volume of formation fluid bypassing the choke b. To facilitate easy handling of choke c. To apply back pressure while controlling a kick 85. Match each of the following statements to one of the answers below: 1. Amount of space between the grains of rock 2. Rock ability to allow flow of formation fluid through it 3. The presence of formation fluids within the pore spaces 4. Momentary increase in BHP a. Porosity b. Formation Pore Pressure c. Permeability d. Surging 86. Well is shut in on a gas kick. After pressure stabilization, both the pressures are found to be rising 100 psi in every 10 min. Calculate the gas migration rate. TVD – 11,000 ft Mud weight – 12.3 ppg SIDPP – 350 psi Gas gradient – 0.115 psi/ft a. 824 ft/hr b. 938 ft/hr c. 600 ft/hr 87. Well is shut-in and following data are recorded: SIDPP – 400 psi SICP – 550 psi Mud in use – 12.0 ppg
What will be SIDPP & SICP if influx has migrated 400 ft up in the hole? . a. SIDPP-650 psi & SICP-550 psi b. SIDPP-650 psi & SICP-800 psi c. SIDPP-400 psi & SICP-800 psi d. SIDPP-400 psi & SICP-550 psi 88. After observing self flow the well is shut in. Killing could not be resumed due to power failure. The following data have been recorded TVD – 11,200 ft Mud weight – 12.3 ppg Kick size – 25 bbls SIDPP – 400 psi Gas gradient – 0.115 psi/ft It is observed that after 1 hour the drill pipe pressure has risen to 575 psi due to closed well migration. Calculate volume to bleed to keep the BHP constant. ______ bbls/hr
