73236775 3 Well Control Exercises
April 2, 2017 | Author: Luis Padilla Mendieta | Category: N/A
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WELL CONTROL
EXERCISE # 1 1. What mud weight is required to balance a formation pressure of 2930 psi at 5420 ft TVD? ___________ppg 2. If the fluid level dropped 550 ft in a 9600 deep hole containing 10.6 ppg mud, what would the hydrostatic at bottom be? ___________psi 3. Bottom hole pressure is reduced the most by gas cut drilling mud when: a. b. c. d.
The gas is near the surface The gas is at or near the bottom The gas is about halfway up the well bore All are about the same
4. After a round trip at 8960 ft with 10.9 ppg mud, we kick the pump in and start to circulate. An increase in flow was noticed and the well was shut in with 0 psi on the drill pipe and 300 psi on the casing. What kill mud is required? (no float in the drill string) ___________ppg
5. What was most probable in causing the influx or well kick in the last question? a. b. c. d.
Abnormal pressure was encountered The mud weight was not high enough to contain formation pressure It was swabbed in or the hole was not properly filled while pulling out It is impossible to tell
6. Which of the following circumstances would increase the chance of swabbing in a kick? a. b. c. d.
High pulling speed Mud properties with high viscosity and high gels Tight annulus BHA/hole clearance Mud density in use is close to formation pressure
7. In which of the following cases would you be most likely to swab in a kick? a. When the bit is pulled up into the casing b. When the first few stands are being pulled off bottom c. About half way up the well
WELL CONTROL
8. When drilling with 10.3 ppg mud at 11600 ft TVD the annular loss is estimated at 195 psi. What is the BHCP? _________psi
9. You are pulling out of hole. Two x 93 ft stands of 8" drill collars have been stood back in the derrick. The displacement is 0.0538 bbls. / ft. According to your Assistant Driller, 10 bbls should be pumped into the well. It only takes 10 bbls to fill the hole. (Answer yes or no to each question) a) Are the calculations correct? b) Have you taken a 5 bbls influx? c) All Ok, keep going
10. You have taken a kick and shut the well in. The active tank while drilling contained 250 bbls. And the mud return line to the pits contains 25 bbls. The tank now contains 300 bbls. How many barrels of mud have been displaced from the well? a) 0 bbls b) 25 bbls c) 50 bbls d) 275 bbls
11. The Fracture Gradient of an open hole formation at 3680 ft. is 0.618 psi/ft. The drilling mud currently in use is 9.8 ppg. Approximately how much Surface Casing Pressure can be applied to the well before this formation breaks down? a) 350 psi b) 2275 psi c) 630 psi d) 400 psi
12. A gas kick is being circulated out. At the time the gas reaches the casing shoe (4250 ft. TVD), the pressure at the top of the bubble is 3000 psi. If the original mud weight is 12 ppg, what is the casing pressure at the surface? (Hole TVD 7000ft) a) 348 psi b) 442 psi c) 1368 psi d) 2625 psi
WELL CONTROL
Questions 13-14 are based on the following information: 13 3/8” surface casing is set and cemented at 4250 ft. (TVD). The cement is drilled out together with 15 ft. of new hole, using a 11 ppg mud. A leak off test pressure of 800 psi is determined. (Hole TVD 7000ft) 13. What is the formation fracture gradient? a) 0.188 psi / ft b) 0.686 psi / ft c) 0.760 psi / ft d) 0.384 psi / ft 14. What is the maximum allowable annular surface pressure for 12.3 ppg mud in use at 7350ft. TVD : a) 373 psi b) 511 psi c) 884 psi d) 1982 psi 15. 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 16. Calculate the equivalent circulating density in the following circumstances: Circulating pressure = 3100 psi Pressure losses: Surface equipment = 20 psi Drill string = 930 psi Nozzles = 1800 psi Annulus = 350 psi Drilled depth: 12,300 ft. (11,500 ft. TVD) Mud weight: 11.4 ppg ECD is: a) 10.8 ppg b) 12.0 ppg c) 11.4 ppg d) 12.3 ppg
WELL CONTROL
17. Drill pipe capacity = 0.0178 bbls/ft Drill pipe metal displacement = 0.0082 bbls/ft Average stand length = 93 ft Calculate : a) Mud required to fill the hole per stand when pulled „dry‟ (bbls per stand)
b) Mud required to fill the hole per stand when pulled „wet‟ (bbls per stand)
18. You are determining your kill rate pressure and bringing your pump rate up to a predetermined 30 SPM by holding the shut in casing pressure constant. You have got a kick in the well of 220 psi shut in drill pipe pressure. At 30 SPM your drill pipe circulating pressure is 1060 psi. Calculate the slow circulating rate pressure loss. a) 700 psi b) 770 psi c) 800 psi d) 840 psi
19. Overburden pressure is: a. the pressure exerted at any given depth by the weight of the rocks and sediments. b. the pressure exerted at any given depth by the weight of the sediments, or rocks and the weight of the fluids that fill the pore spaces in the rock. c. the pressure exerted at any given depth by the weight of the rocks. d. the pressure exerted at any given depth by the weight of the fluid in the pore space of the rocks.
20. Of all the pressure losses in the circulating system, which one acts only on the borehole? A. B. C. D.
The pressure loss across the nozzles. The pressure loss in the surface lines. The pressure loss in the drill stem. The pressure loss in the annulus
WELL CONTROL
21. At the start of a trip out of the hole for a bit change, the first 20 x 93 ft stands of pipe are pulled from the hole wet with no fill up. Using the following data calculate the reduction in bottom hole pressure? DP. Metal Displacement DP. Capacity Casing Capacity Mud Weight A. B. C. D.
= .00764 bbls/ft = .01776 bbls/ft = .0758 bbls/ft = 10 ppg
48 psi 483 psi 600 psi 683 psi
22. At the start of a trip out of the hole for a bit change, the first 10 x 93 ft stands of pipe are pulled from the hole dry with no fill up. Using the following data calculate the reduction in bottom hole pressure? DP. Metal Displacement DP. Capacity Casing Capacity Mud Weight A. B. C. D.
= .00764 bbls/ft = .01776 bbls/ft = .0758 bbls/ft = 12 ppg
650 psi 6 psi 65 psi 130 psi
23. Select the two things that are needed to accurately determine an Initial Circulating Pressure? A. B. C. D.
drilling pump pressure and mud weight shut in drill pipe pressure and mud weight slow circulating rate pressure and final circulating pressure slow circulating rate pressure and shut in drill pipe pressure
24. Select the three things that are needed to accurately determine a Final Circulating Pressure? A. B. C. D.
drilling pump pressure, drilling mud weight and kill mud weight shut in drill pipe pressure, drilling mud and kill mud weight slow circulating rate pressure, drilling mud weight and kill mud weight slow circulating rate pressure, drilling mud weight and final circulating pressure
WELL CONTROL
25. The Drillers Method of Well Control normally requires how many circulations to kill a well? A. B. C. D.
one circulation two circulations three circulations four circulations
26. The Drillers Method of Well Control will normally result in: A. B. C. D.
a higher bottom hole pressure than the wait and weight method. a lower bottom hole pressure than the wait and weight method. a higher surface pressure than the wait and weight method a lower surface pressure than the wait and weight method.
27. During a well-killing operation, a common way to bring the pump up to kill rate without changing bottom hole pressure is to: A. keep SIDP constant at the original shut-in value by opening the choke. B. keep SIDP constant at the original shut-in value by opening the choke and bringing the pump up to kill-rate speed. C. keep SICP constant at the original shut-in value by opening the choke and bringing the pump up to kill-rate speed. ensure that casing pressure and standpipe pressure rise consistently together.
28. The usable accumulator fluid for a 10 gallon accumulator bottle on a 3,000 psi system with 1,000 psi precharge is approximately: A. B. C. D.
9 gallons. 7 gallons. 5 gallons. 3 gallons
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29. Use the following well data to calculate the different influx heights: Drill collar length: 700 ft DC - OH Capacity .0292 bbl/ft DP - OH Capacity .0459 bbl/ft Kick size (bbls)
Height (ft)
a. b. c. d.
________ ________ ________ ________
10 20 30 40
30. Using the following data, calculate the influx gradients:
SICP 800 950 680
SIDPP 720 600 550
Mud Wt 11.5 10.6 10.2
Height of Influx 400 840 350
Answer
31. Using the following well data calculate Kill mud weights: SICP (psi) 600 850 780 700
SIDPP (psi) 450 690 570 300
Mud Wt (ppg) 10 11 10.5 14
TVD (ft) 9500 12000 11200 13000
Answer
32. Using the following well data calculate the Annular Pressure Losses: BHCP (psi) 6000 2600 5700
Mud Wt (ppg) 11.6 9.8 10
Depth TVD (ft) 9450 5000 10000
Answer
33. Using the following data, calculate the new pump pressure: Old pump pressure 2500 1700
Old Mud weight 16 10
New mud Weight 17.5 14
Answer
WELL CONTROL
34. Using the following data, calculate the new pressure:
Old SPM Old pressure New SPM 40 200 80 20 400 55 35. Convert the following pressure gradient to mud weight:
Gradient (psi/ft) .56 .81
Answer
Mud Wt (ppg)
36. Change the ECD to BHCD:
ECD (ppg) 12.5 10.2 9.4
Depth TVD (ft) 8000 11400 12500
BHCD (psi)
37. What would be the annular velocity around the drill collars:
Pump output (bbl/min) 6
DC – OH capacity (bbl/ft) 0.3
Annular Velocity (ft/min)
38. What would be the annular velocity around the drill pipe if the pump output is 6 bbl/min and the DP – OH capacity is .0459 bbl/ft ?
Answer:
ft/min
WELL CONTROL
39. At the start of a trip out of the hole for a bit change, the first 10 x 93 ft stands of drill pipe are pulled from the hole wet. Using the following data, calculate the reduction in bottom hole pressure. Mud weight: Casing capacity: DP capacity: DP metal displacement: Answer:
12 ppg .0758 bbl/ft .01776 bbl/ft .00764 bbl/ft
psi
40. At the start of a trip out of the hole for a bit change, the first 20 x 93 ft stands of drill pipe are pulled from the hole dry. Using the following data, calculate the reduction in bottom hole pressure. Mud weight: Casing capacity: DP capacity: DP metal displacement: Answer:
12 ppg .0758 bbl/ft .01776 bbl/ft .00764 bbl/ft
psi
41. While tripping out of the hole, the trip tank is turned off and a flow check is made when the drill collars are at the rotary table. The last 400 feet of drill collar are pulled from the hole dry with no fill up. Using the following data answer the questions below:
DC metal displacement: DC capacity: Casing capacity: Mud weight:
.054 bbl/ft .00768 bbl/ft .0758 bbl/ft 12 ppg
a. What is the maximum level drop in the annulus? Answer:
ft
b. What is the reduction in bottom hole pressure? Answer:
psi
WELL CONTROL
42. Using the following data, calculate the loss in hydrostatic pressure if the casing was not kept full and the float failed while running casing in the hole.
Casing capacity .0754 bbl/ft .0754 bbl/ft
Formula :
Annular capacity .067 bbl/ft .067 bbl/ft
Differential height 1000 ft 800 ft
Mud Wt 10 12
Anwser (psi)
Mud gradient x Differencial Height x Casing capacity (Casing capacity + Annular capacity)
43. An influx in oil based mud is not possible to detect when it is first occurring because gas going into solution will cause no associated pit increase at the surface. TRUE or FALSE
44. When a kick is taken in oil based mud and the well pressure have stabilized, the SICP will be: a. Higher than the same kick in water – based mud b. Lower than the same kick in water – based mud c. The casing pressure would read the same in oil or water – based mud
45. Gas that is in solution will migrate in the annulus in a vertical well at the same rate as free gas. TRUE or FALSE 46. When drilling a deep high pressure high temperature well using oil base mud, a gas condensate influx enters the well bore undetected. If the critical bubble pressure was about 800 psi, how far from the surface would it be when it started to break out and become free gas if the mud weight in use is 12 ppg.
a. b. c. d.
800 ft 1282 ft 9600 ft 2182 ft
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EXERCISE # 2 1. Which gauge must be used to read drill pipe pressure while taking SCR‟s? a. b. c. d.
drill pipe gauge on driller‟s panel casing gauge on driller‟s panel drill pipe gauge at the choke panel casing gauge at the choke panel
2. A 13 3/8 casing is set at 3126 ft TVD, drilled out and tested with 10.2 ppg mud to 670 psi surface pressure. What is the formation fracture gradient calculated from the test? a. b. c. d.
0.564 psi/ft 0.678 psi/ft 0.74 psi/ft 0.841 psi/ft
3. What would be the MAASP with 11.4 ppg mud in the hole? (use data from Q-2) a. b. c. d.
400 psi 461 psi 500 psi 560 psi
4. What mud weight would have a MAASP of 250 psi? (use data from Q-2) a. b. c. d.
11.56 ppg 12.69 ppg 11.85 ppg 12.21 ppg
5. What happen to MAASP as MW increases? a. b. c. d.
increase decrease stay the same impossible to say
6. What do you consider as essential for an accurate formation test? (4 answers) a. b. c. d. e. f. g. h.
a list of mud additives a known mud yield point accurate TVD for the casing shoe Small volume, high pressure pump The same known mud weight in and out Cement recipe An accurate surface pressure gauge A long open hole section
WELL CONTROL
7. What is the mud weight that we would expect to use to balance normal formation pressure? a. b. c. d.
7.56 ppg 8.00 ppg 8.94 ppg 10.2 ppg
8. What is primary well control? a. b. c. d.
the use of drilling fluid to balance formation the use of BOP to secure the well the use of annular preventer to close the well the use of cement plug
9. Swabbing will cause the loss of primary well control? a. true b. false 10. When drilling top hole, which of the following are considered to be good drilling practices? (3 answers) a. b. c. d. e. f. g.
ROP will be maximised MW must be with .5 ppg of plan Pump out of hole while tripping Drill a pilot hole Pump a slug before tripping Control ROP Minimise losses to 15 bbl/hr
11. If the level of 12.5 ppg mud fell by 560 ft in a 6543 ft TVD well, what would be the reduction in BHP? a. b. c. d.
364 psi 244 psi 448 psi 732 psi
12. What is the reduction in bottom hole pressure if a 5 bbl lightweight pill of 7.5 ppg is spotted around 4 ¾ drill collars (total length 460 ft) in a 6 1/8 hole containing OBM of 11.9 ppg? a. b. c. d.
50 psi 120 psi 95 psi 79 psi
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13. Every kick should be handled as a gas kick? a. true b. false 14. For a Soft shut-in, the choke is left closed while drilling a. true c. false 15. Calculate the rate of gas migration if SIDDP has increased by 50 psi in 15 minutes? MW: 10.5 ppg MD: 7500 ft TVD:7000 ft a. b. c. d.
366 ft/hr 455 ft/hr 244 ft/hr 575 ft/hr
16. What is the casing pressure when a 5 bbl gas bubble at 2200 psi in 11.6 ppg mud reaches the casing shoe at 3126 ft TVD? a. b. c. d.
569 psi 314 psi 456 psi 297 psi
17. A 9000 ft well is shut in with 200 psi SICP and 0 PSI SIDPP. What is the KMW if OMW is 11.6 ppg? a. b. c. d.
12.4 ppg 12.03 ppg 12.4 ppg 11.6 ppg
18. W&W method gives lower shoe pressure in all cases a. true b. false 19. W&W method results in a lower shoe pressure if drill string volume is less than the open hole volume minus the influx volume? a. true b. false
WELL CONTROL
20. Surface pressures are always lower if the W&W method is used compared to the Driller‟s method? a. true b. false Answer true or false for these statements on the W&W method: 21. Casing pressure must be kept constant during the second circulation a. true b. false 22. The pumps are brought up to speed keeping the drill pipe pressure constant a. true b. false 23. Surface annulus pressure is lower than with the driller‟s method a. true b. false 24. Bottom hole pressure is maintained constant a. true b. false 25. The well is dead when you have reached FCP a. true b. false 26. SIDPP should be zero once you have reached FCP a. true b. false 27. The W&W method is preferred if rapid gas migration is expected a. true b. false 28. The W&W is preferred as MAASP is critical and open capacity is greater than the drill string capacity a. true b. false
WELL CONTROL
29. The choke operator maintain drill pipe pressure constant while circulating KMW from surface to bit. What happen to BHP? a. increase b. decrease c. stay the same 30. What is the BHCP if the MW is 10 ppg, TVD: 12500ft and APL: 400 psi? a. b. c. d. 31.
6200 psi 6900 psi 7300 psi 7700 psi
The poorboy degasser (mud/gas separator) is identified by its design dimensions. Which two of the given dimensions determine the operating limit of the pressure build up in the separator? a b c d e f g
32.
Body height. Inlet line inside diameter. Vent pipe inside diameter. Height of the U-tube. Inside diameter of the U-tube. Vent pipe height. Body inside diameter.
You are using a cup type tester. The mandrel outside diameter is 6 3/4" and the casing inside diameter is 12.615". Calculate the tension force created on the drill pipe above the cup tester when a 3000 psi test pressure is applied. a b c
267,000 lbs 167,500 lbs 67,500 lbs
33. A larger pit gain will give a higher SIDPP, resulting in a higher kill mud weight. a. b. c. d. e.
True Maybe Sometimes False Always
WELL CONTROL
34. A larger pit gain will result in higher SIDPP and SICP. a. b. c. d. e.
True Maybe Sometimes False Always
35. A larger pit gain will result in a higher SICP, but theSIDPP will remain the same if the kick is big or small. a. b. c. d. e.
True Maybe Sometimes False Always
36. After circulating out a kick using the driller's method, is the SICP and SIDPP about the same? a. b. c. d. e.
Only if the influx is a fluid. Never Yes No Only if the influx was gas.
37. When killing a well using the wait and weight method, what will happen to the mud pit volume the moment the gas is passing through the choke? a. b. c. d. e.
The pit volume starts increasing. The pit volume starts to drop. The pit volume will stay the same from now on. The pit volume will rise and fall erratically. The pit volume should not be monitored when killing.
38. What is the value of the Maximum Allowable Annular Surface Pressure usually determined by? a. b. c. d. e.
The maximum bottom hole pressure that can be sustained. The slow circulating rate. The formation strength at the casing shoe. The temperature of the influx fluid. The annular pressure loss.
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39. When killing a well using the driller's method, what would happen to the mud pit volume during the second circulation? a. b. c. d. e.
The pit volume decreases. The pit volume stays the same. Increase only due to added weight material. Increase initially and decreases in the end. Decreases at first and increases in the end.
40. What action would you take if while circulating out a kick the choke line parted? a. b. c. d. e.
Stop pump and close the choke. Stop pump and close the HCR. Continue to kill if the influx is past the shoe. Stop the pump and close the shear rams. Start killing with the volumetric method.
41. Whilst circulating out a kick the mud pump fails. What is the first thing to do? a. b. c. d. e.
Fix the pump as soon as possible. Change over to the other pump. Shut the well in. Start diverting. Start bullheading.
42. If total losses occurred while drilling with water based mud, what would you do? a. b. c. d. e.
Continue drilling blind. Stop drilling, fill the hole with water. Stop drilling, shut the well in. Spot a hivis pill acroos the shoe. Set a barite plug.
43. On a surface stack; what would happen if when bringing the pump up to kill speed the casing pressure was allowed to increase above the shut in casing pressure? a. b. c. d. e.
BHP would possibly exceed formation fracture gradient. BHP would cause more influx to enter the well bore. It doesn't matter at all if SIDPP is constant. It is OK if SIDPP also rises the same amount. Only while using wait and weight method does it matter.
WELL CONTROL
44. Mud weight is 12.5 ppg. SIDPP=800 psi, SICP=1025 psi. The annulus capacity is .0292 bbl/ft. The influx volume is 12 bbl. What is the gradient of the influx? a. b. c. d. e.
.1520 psi/ft .1502 psi/ft .1205 psi/ft .1025 psi/ft .0521 psi/ft
45. TD=12000', MW in the hole=13.5 ppg, Pitgain 50 bbl, SIDPP=600 psi. Ann. cap. with 450' of DC= .0778 bbl/ft. DP/OH cap= .1215 bbl/ft. Influx gradient = .1 psi/ft What is the SICP? a. b. c. d. e.
642 psi 945 psi 573 psi 580 psi 752
46. SIDPP increases with the size of the kick. a. True b. False 47. A driller is circulating a kick out and has reached hisfinal circulating pressure of 850 psi with 30 SPM. If this driller speeds the pump up to 35 SPM, and the toolpusher keeps 850 psi on the drillpipe by adjusting the choke, the bottom hole pressure will: a. b. c. d. e.
Decrease by 307 psi Increase by 253 psi Stay constant at 850 psi Increase by 140 psi Decrease by 405 psi
48. Which of the following functions is activated by the manifold pressure of the accumulator unit? a. b. c. d. e.
Ram preventers only. Hydrauliccally operated choke and kill line valves. Rams and hydraulic operated choke and kill line valves. Annular preventers All stack functions.
WELL CONTROL
A deviated hole has a measured depth of 12,320 ft. (TVD 10429 ft). 9 5/8”, 47 lb/ft. casing in set at a measured depth of 9750 ft. (9200 ft. TVD). 11.4 ppg mud is in use when the well kicks and is closed in. Shut in Drill Pipe Pressure : Shut in Casing Pressure: Kick volume: Pre- recorded information is as follows : Fracture mud weight Capacity of 19.5 lbs. Drill pipe Capacity of 9 5/8” J55 casing Slow Circulating Rate Pressure
750 psi 1050 psi 15 bbls.
= 14.4 ppg = 0.01776 bbl/ft. = 0.0732 bbl/ft. = 850 psi
49. The maximum allowable annular surface pressure is rounded off to : a) 1370 psi b) 1480 psi c) 1435 psi d) 1415 psi 50. The kill mud weight required to balance the formation pressure is: a) 13.1 ppg b) 12.6 ppg c) 12.8 ppg d) 12.2 ppg 51. The kill mud weight with a Safety Margin of 100 psi is: a) 13.4 ppg b) 13.0 ppg c) 12.4 ppg d) 11.8 ppg 52. The initial circulating pressure is: a) 1400 psi b) 1600 psi c) 1900 psi 53. The final circulating pressure (using kill mud weight with a 100 psi Safety Margin is) : a) 850 psi b) 970 psi c) 920 psi d) 1050 psi
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54. The Fracture Gradient of an open hole formation at 3680 ft. is 0.618 psi/ft. The drilling mud currently in use is 9.8 ppg. Approximately how much Surface Casing Pressure can be applied to the well before this formation breaks down? a) 350 psi b) 2275 psi c) 630 psi d) 400 psi 55. In the area where local legislation requires that BOP equipment must be rated so that maximum anticipated formation pressures do not exceed 75% of BOP equipment pressure ratings, what is the Minimum Acceptable rating for equipment to be used in drilling Normally Pressured Formation to 16,000 ft. TVD? a) 2,000 psi BOP Equipment b) 3,000 psi BOP Equipment c) 5,000 psi BOP Equipment d) 10,000 psi BOP Equipment e) 15,000 psi BOP Equipment
WELL CONTROL
EXERCISE # 3 Use the Well Data to answer the questions. Each question has only one correct answer. WELL DATA Well Depth
10,000 ft TVD 10,000 ft MD 800 ft 820 ft capacity = 0.0087 bbls/ft 8.5” 5” OD. 19.5 lbs/ft Capacity = 0.01776 bbls/ft 5” OD. 50 lbs/ft x 850 ft Capacity = .0088 bbls/ft 61/2” x 213/16” x 750 ft Capacity = 0.00768 bbls/ft 95/8”, 47 lb/ft. P110 8.681” ID 100% Internal yield = 10,900 psi Set at 7,500 ft TVD 15 ppg. 0.119 bbls/stk
Marine riser Choke line Bit size Drill Pipe HWDP Drill Collars Casing
Mud weight in use Pump output
PUMP PRESSURE While Drilling Slow Pump Rate Up Riser Slow Pump Rate Up CL
2600 psi at 90 spm (APL = 310 psi) 270 psi at 30 spm (APL = 75 psi) 360 psi at 30 spm ANNULAR VOLUMES
Drill pipe - Casing Drill pipe - Casing Drill pipe - Open hole Drill collars - Open hole Drill pipe – riser Active surface volume
= 0.0505 bbls/ft = 0.0459 bbls/ft = 0.0292 bbls/ft = 0.336 bbls/ft = 320 bbls
WELL CONTROL DATA SIDPP SIDPP SICP GAIN FRACTURE GRADIENT AT SHOE
= 500 psi = 720 psi = 10 bbls = .91psi/ft
WELL CONTROL
1. What is the total capacity of the drill string? A. B. C. D.
150 bbls 162 bbls 197 bbls 180 bbls
2. Calculate the total annular capacity with the pipe on bottom while controling the well? A. B. C. D.
482.2 bbls 446.5 bbls 547.5 bbls 627.6 bbls
3. What is the surface to bit time with the pump running at 80 spm? A. B. C. D.
17 minutes 25 minutes 32 minutes 39 minutes
4. Calculate bit to surface time (bottoms up) at 80 spm? A. B. C. D.
58.5 minutes 46.8 minutes 60.3 minutes 51.5 minutes
5. What kill mud is required to balance formation pressure? A. B. C. D.
13.4 ppg 13.0 ppg 12.4 ppg 16.0 ppg
6. The ICP (initial circulating pressure) at 30 spm will be approximately? A. B. C. D.
270 psi 770 psi 990 psi 1200 psi
WELL CONTROL
7. The FCP (final circulating pressure) at 30 spm will be approximately? A. B. C. D.
approximately 800 psi approximately 390 psi approximately 500 psi approximately 290 psi
8. After reaching FCP it is decided to increase the pump speed to 40 spm. What would happen to BHP if the drill pipe pressure is held constant at the original FCP value? A. B. C. D.
increase by about 225 psi decrease by about 225 psi remain constant because drill pipe pressure was not changed increase by about 500 psi
9. What is the hydrostatic pressure at the bottom of the hole before the kick? A. B. C. D.
5800 psi 6800 psi 7800 psi 6240 psi
10. What is the ECD on bottom while drilling? A. B. C. D.
15.0 ppg 15.5 ppg 16.0 ppg 16.5 ppg
11. At 80 spm what is the annular velocity around the drill collars? A. B. C. D.
412 ft/min 210 ft/min 506 ft/min 321 ft/min
12. What is the maximum allowable mud weight? A. B. C. D.
17.5 ppg 16.5 ppg 18.0 ppg 19.0 ppg
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13. What is the approximate length of the influx? A. B. C. D.
1027 ft 850 ft 653 ft 342 ft
14. The gradient of the influx is about? A. B. C. D.
.137 psi/ft .320 psi/ft .465 psi/ft .433 psi/ft
15. How many strokes to go from ICP to FCP? A. B. C. D.
1282 stks 1363 stks 1680 stks 1538 stks
16. How many strokes will it require to go from bit to shoe? A. B. C. D.
5364 stks 4122 stks 1658 stks 858 stks
17. How long will it take to go from bit to shoe at a pump speed of 30 spm? A. B. C. D.
about 214 minutes about 29 minutes about 157 minutes about 55 minutes
18. At 30 spm what is shoe to surface travel time? A. B. C. D.
about 96 minutes about 34 minutes about 214 minutes about 76 minutes
WELL CONTROL
19. If the casing shoe is tested with 12.5 ppg mud in the hole, how much pressure is applied at the surface to give a fracture gradient of .91 psi/ft? A. B. C. D.
1250 psi 1500 psi 2000 psi 1950 psi
20. What would be the new MAASP once the well has been killed? A. B. C. D.
685 psi 1638 psi 700 psi 585 psi
21. At 30 spm how long will it take to pump kill mud to the bit? A. B. C. D.
157 mins 214 mins 45 mins 76 mins
22. If a 100 psi safety margin is included in the kill mud weight, what would the new kill weight be? A. B. C. D.
15.5 ppg 16.0 ppg 15.4 ppg 16.2 ppg
23. What would be the approximate pressure step down from ICP to FCP in psi/100 strokes. A. B. C. D.
30 psi/100 stks 35 psi/100 stks 50 psi/100 stks 66 psi/100 stks
WELL CONTROL
Answer the following gauge questions as the well is killed using the Drillers method. TO TA L S TR O K E S 90 0 1000 1 100 80 0 70 0
900 10 00 1100
50
1200
800
600
PSI
160 0
200
1600 1 700
300 200
1 800 1 00
14 00 1 500
4 00
1700
3 00
PSI
5 00
15 00
400
13 00
6 00
1400
5 00
1 200
700
1300
1900
30
D R ILLP IP E P R E S S U R E
18 00 10 0
PUMP SPEED
1 900
C A S IN G P R E S S U R E
770
630 O P EN
C H O KE P O S IT IO N
C LO S E
24. The kill operation has started. This is what the choke control console shows. What should you do? A. B. C. D. E. F. G. H.
open the choke a little close the choke a little increase the pump speed decrease the pump speed nothing everything looks alright Possible plugged nozzle Possible choke wash out Possible choke plugging TO T A L S TR O K E S 900 100 0 1 100 800 70 0
900 100 0 11 00
580
120 0
800
60 0
PSI
16 00
2 00
160 0 170 0
300 2 00
1800 1 00
1400 1 500
40 0
170 0
300
PSI
5 00
1500
40 0
130 0
60 0
140 0
5 00
120 0
70 0
130 0
1 900
PUMP SPEED
D R ILLP IP E P R E S S U R E
30
1 800 100
1 900
C A S IN G P R E S S U R E
600
600 O PE N
CH O KE P O S ITIO N
C LO S E
25. Pit room calls up to confirm a .5 bbl rise in the level. What should you do? A. open the choke a little B. close the choke a little C. increase the pump speed D. decrease the pump speed E. nothing everything looks alright
WELL CONTROL
TO TA L STR O KES 900 1000 1100 8 00 700
900 1000 1100
3250
1200
800
600 500
1600
200
1600 1700
300 200
1800 100
1500
400
1700
300
1400
PS I
500
1500
400
1300
600
1400
P SI
1200
700
1 300
1900
PU M P SPEED
D R ILLP IPE PR E SSU R E
30
1800 100
1900
CASIN G PR ESSU R E
770
1 0 20 O PEN
CH OK E PO SITIO N
C LOS E
26. The pit levels are still reported to be increasing slightly. This is what you see on the panel. A. B. C. D. E.
open the choke a little close the choke a little increase the pump speed decrease the pump speed nothing everything looks alright
WELL CONTROL
EXERCISE # 4 1. Most kicks have been caused by the failure of drilling crews to: a. Properly install and test BOP equipment b. Keep mud weight high enough c. Make sure that hole takes the proper amount of fluid during a trip 2. What is the correct action if the hole does not take the proper amount of fluid while tripping out of the hole? a. b. c. d.
Observe, watch for flow, and if there is none, pull out of hole Stop, spot a high viscosity pill, then pump out of hole Go back to bottom, circulate bottoms up and evaluate the problem Check for gas cut mud at the surface
3. The most important rule in well control is to: a. b. c. d.
Know how to take SIDPP with a float in the string Shut the well in quickly and properly with the least amount of gain Circulate the kick out using constant circulating pressure and pump strokes Hold 200 psi extra back pressure with the hydraulic choke while circulating out the kick
4. A large percentage of all kicks have been caused by: a. b. c. d.
Abnormally pressured formations People not reacting or handling situations properly BOP equipment failure Lost circulation
5. The mud weight required in the hole to balance normal formation pressure would have to be: a. b. c. d.
8.3 ppg 10.3 ppg 8.9 ppg 9.5 ppg
6. Mud monitoring equipment such as P.V.T. and pit alarm systems, trip tanks and trip records should be used: a. b. c. d.
Any time the well is open Any time fluid is circulated through the mud pit When abnormal formation is expected When drilling 12 ¼ hole
WELL CONTROL
7. Every kick should be handled as a gas kick a. True b. False 8. The first reliable indication that a kick is in progress is: a. b. c. d.
No warning An increase in pump pressure An increase in mud flow, mud volume and a decrease in pump pressure Reduced drilling rate
9. When a gas kick is being circulated up a well, the surface pit volume will: a. increase b. decrease c. stay the same 10. Final circulating pressure is reached when: a. b. c. d.
The influx is circulated out Kill mud has made a complete circulation Kill mud has made a bottom-up Kill mud reaches the bit
11. Mark the statements below "true" or "false" when drilling with a float valve in the string. a) Surge pressure is reduced.
True False
b) Reverse circulation is possible.
True False
c) Flow back through the drillstring often occurs after pumping a slug.
True False
d) Shut-in drillpipe pressure can be taken without starting the pumps.
True False
WELL CONTROL
12. What is the primary function of the choke in the overall BOP system? a) To divert contaminant to burning pit. b) To hold back pressure while circulating up kick. c) To divert fluid to the mud tank. d) To prevent the loss of mud due to expansion of gas. e) To close the well in softly. 13. While testing the BOP stack, it is noticed that hydraulic oil is leaking from the weep hole on the upper rams. Which one of the following best describes the proper action to be taken? a) Energize plastic seal and repair BOP at next scheduled maintenance. b) A primary seal is leaking, secure the well and repair the seal. c) The rams packer is leaking due to wear. Change the worn packer. d) Do nothing. The seal requires a slight leak for lubrication purpose. 14. Why should the side outlet below a test plug be kept in the open position while testing a surface BOP stack? a) Because of potential damage to casing/open hole. b) Because the test will create extreme hook load. c) Otherwise reverse circulation will be needed to release the plug 15. Which three of the following conditions in the well increase the risk of exceeding the MAASP during the well kill operation? a) Long open hole section. b) Large difference between formation breakdown pressure and mud hydrostatic pressure. c) Small influx. d) Short open hole section. e) Large influx. f) Small difference between formation breakdown pressure and mud hydrostatic pressure. Questions 16-18 are base on the following information: 13 3/8” surface casing is set and cemented at 3126 ft. (TVD) The cement is drilled out together with 15 ft. of new hole, using a 10.2 ppg. mud. A Leak Off Pressure of 670 psi is determined. 16. What is the formation fracture gradient? a) 0.619 psi/ft b) 0.837 psi/ft c) 0.745 psi/ft d) 0.530 psi/ft.
WELL CONTROL
17. What is the Maximum Allowable Annular Surface Pressure for 11.4 ppg mud used at 6500 ft TVD. a) 865 psi b) 474 psi c) 449 psi d) 563 psi 18. 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 19. A gas kick is being circulated out. At the time the gas reaches the casing shoe (3126 ft TVD) the pressure at the top of the bubble is 2200 psi. If the original mud weight is 11.6 ppg. What is the casing pressure at surface. a) 314 psi b) 442 psi c) 542 psi d) 506 psi 20. The Fracture Gradient of an open hole formation at 3680 ft. is 0.618 psi/ft. The drilling mud currently in use is 9.8 ppg. Approximately how much Surface Casing Pressure can be applied to the well before this formation breaks down? a) 350 psi b) 2275 psi c) 630 psi d) 400 psi 21. What is primary well control? a) The slow Circulating Rate Pressure used in the kill process. b) The used of Mud hydrostatic to balance fluid pressures in the formation. c) The use of Blow Out Preventers to close in a well that is flowing. d) The use of Pit Volume and Flow Rate measuring devices to recognize the kick. 22. What is meant by Abnormal High Pressure with regard to fluid pressure in the formation? a) The excess pressure due to circulating mud at high rates. b) The excess pressure that needs to be applied to cause „leak-off „ into a normally pressure formation. c) High density mud used to create a large overbalance. d) Formation fluid pressure that exceeds normal water hydrostatic pressure.
WELL CONTROL
23. Which factors most influence the rate at which shut in pressures stabilize after the well is shut in? a) Gas migration b) Friction losses c) Permeability d) Type of influx 24. While running pipe back into the hole, it is noticed that the normal displacement of mud into the trip tank is less than calculated. After reaching bottom and commencing circulation, the return flow meter is observed to reduce from 50% to 42%. A pit loss of 2 bbl. is noted. What is the most likely cause of these indications? a) Partial lost circulation has occurred. b) Total lost circulation has occurred. c) A kick has been taken. d) The well has been swabbed. 25. If total losses occurred while drilling with water based mud what would you do? a) Continue drilling blind. b) Stop drilling and fill the annulus up with water, from the top until stabilized. c) Stop drilling, shut the well in and see what happens. 26. Lost circulation during a well control operation is usually detected by: a) Monitoring the return flow with the flow show. b) Monitoring the mud volume in the mud tanks. c) Monitoring the weight indicator. 27. A kick has been taken and it is known that a potential lost circulation zone exists in the open hole. Select two correct actions which can be taken to minimize pressure in the annulus during the kill operation. a) Maintain extra back pressure on the choke for safety. b) Use the wait and weight method. c) Choose a lower circulating rate. d) Choose a higher circulating rate. 28. Which of the following causes of well kicks is totally avoidable and is due to a lack of alertness by the driller? a) Lost circulation. b) Gas cut mud. c) Not keeping hole full. d) Abnormal Pressures.
WELL CONTROL
29. Which two of the following cause swabbing? a) Pulling the pipe too fast. b) Insufficient trip margin. c) Improper circulating density. d) Going into the hole too fast. e) Failure to slug pipe prior to pulling out of hole.
30. Why is a 20 barrel kick in a small annulus more significant than a 20 barrel kick in a large annulus? a) The kill weight mud cannot be calculated as easily. b) It result in higher annulus pressures, due to the height of the kick. c) The kicks are usually gas d) The pipe usually get stuck.
31. Which one of the following is not an indication when a kick may be occurring? a) Flow rate increase. b) Increase torque. c) Pit gain. d) Gas cut mud.
32. What should the driller do at a drilling break? a) Circulate bottoms up. b) Flow check c) Reduce weight on bit. d) Increase pump speed.
33. Which two practices are used to maintain primary well control as a precaution when connection gas is noticed? a) Pumping a low viscosity pill around bit to assist in reduction of balled bit or stabilizers. b) Control drilling rate so that only one slug of connection gas is in the hole at any one time. c) Pulling out of the hole to change the bit. d) Raising Mud yield point. e) Minimizing the time during a connection when the pumps are off.
WELL CONTROL
34. Of all the following warning signs, which two signs would leave little room for doubt that the well is kicking? a) flow line temperature increase. b) increased rotary torque c) flow rate increase. d) decrease drill string weight e) pit volume gain f) increased rate of penetration
35. Which of the following statements best describes formation porosity. a) The ratio of the open spaces to the total volume of rock. b) The ability of fluid and gas to move within the rock. c) The presence of sufficient salt water volume to provide gas lift. d) All of the above
36. While drilling The active tank contained 200 bbls and the mud return line to the pits contains 20 bbls. After having a kick the tank contains 240 bbls. What is the size of the influx?. a) 260 bbls b) 20 bbls c) 40 bbls d) 240 bbls. 37. The driller is tripping pipe out of a 12 ¼” diameter hole. 25x92 ft. stand of 5” pipe have already been pulled. There are 85 more stands to pull. The calculated metal displacement of the 9 ½” collars is 0.08 bbls/ft. The capacity of the drill pipe is 0.01776 bbls/ft and the metal displacement 0.0075 bbls/ft. The trip tank volume has reduced from 27 barrels to 15 barrels. What action should be taken in this situation? a) Flow check, if negative continue to pull out of hole. b) Shut the well in and circulate hole clean. c) Flow check, if negative displace a 100 ft. heavy slug into annulus and continue to pull out of hole. d) Flow check, if negative run back to bottom and monitor returns. e) Pull remaining stands out of hole.
WELL CONTROL
38. Prior to pulling out of the hole from 10485 ft. TVD, the pipe is full of 10.4 ppg. mud. The pipe capacity is 0.01776 bbls/ft. A 25 bbls slug weighting 12.0 ppg is pumped into the drill pipe causing the level to drop some 216 ft. inside the drill pipe. What is the drop in bottom hole pressure due to pumping the slug into position? a) 25 psi b) 0 psi. c) 117 psi d) 135 psi. 39. Which of the following possible indications suggest that mud hydrostatic pressure and formation pressure are almost equal? a) A drilling break. b) Connection gas. c) Large, splintery cuttings. d) Trip gas. e) All of above. 40. While pulling out of the hole it is noticed that mud required to fill the hole is less than calculated. What action must be taken? a) Flow check, if negative displace a 100 ft. heavy slug into annulus and continue to pull out of the hole. b) Flow check, if negative run back to bottom circulate bottoms up and monitor returns. c) Pull remaining stands out of the hole. d) Flow check, if negative continue to pull out of the hole. e) Shut the well in and circulate the hole clean. 41. You are pulling out of hole. Two 93 ft. stands of 8” drill collars have been stood back in the derrick. The displacement is 0.0549 bbls/ft. According to your Assistant driller - 5.1 bbls should be pump into the well. It only takes 5 bbls to fill the hole. (Answer “Yes” or “No” to each question.) a) Are the calculations correct? Yes
No
b) Have you taken a 5 bbls influx? Yes
No
c) All OK, keeps going? Yes
No
WELL CONTROL
42. While tripping out of the hole a kick was taken and a full bore kelly cock was stabbed and closed. A non return type safety valve was made up on top of the kelly cock prior to stripping in. (Answer “Yes” or “No” to each question.) a) Should the kelly cock be closed? Yes
No
b) If the kelly cock is left in the open position, can a wire line be run inside the drill string? Yes
No
43. From the list of practices shown below, choose the six most likely to lead to an increase in the size of the influx. a) Switch off the flow meter alarms. b) Regular briefing for the derrickman on his duties regarding the monitoring of pit levels. c) Drilling 20 ft further after a drilling brake, before flow checking. d) Running regular pit drills for drill crew. e) Maintaining stab in valves. f) Testing stab in valves during BOP tests. g) Excluding the drawworks from the SCR assignment. h) Keeping air pressure on choke control console at 10 psi. i) Calling toolpusher to floor prior to shutting in the well. j) Not holding down master air valve on remote BOP control panel while functioning a preventer. 44. If flow through the drillpipe occurs while tripping, what should the first action be? a. Pick up and stab kelly. b. Run back into bottom. c. Close the annular preventer. d. Stab a full opening safety valve, close the valve. 45. Which list below (a, b, c or d) describes how the choke manifold will most likely be set up for Hard Shut-in while drilling?
A B C D
BOP Side Outlet open open closed closed
HydraulicValve(HCR) closed open open closed
Auto Choke closed closed open open
WELL CONTROL
46. While drilling along at a steady rate the derrickman asks to slow the mud pumps down so that the shakers can handle the increase in cuttings coming back in the returns. Which one of the following would be the safest course of action. a) Continue at the same rate allowing the excess to bypass the shakers and get caught in sand traps which can be dumped later. b) Pick up off bottom and check for flow, if there is not any then circulate bottoms up to reduce rate so shakers can handle cutting volume, flow check periodically during circulation. c) Slow down the mud pump until the shakers can handle the volume of cuttings in the returns as requested by derrickman. d) Slow down the drilling rate and the pump rate until the shakers clear up then go back to the original parameters.
WELL CONTROL
EXERCISE # 5 1. When a kick occurs, why is it important to get the well shut in as soon as possible a) A larger pit gain will result in a higher SIDPP resulting in a heavier kill mud weight True or False. b) A larger pit gain will result in higher SIDPP and SICP True or False. c) A larger pit gain will result in higher SICP but SIDPP will stay the same True or False.
2. A flowing well is closed in. Which two pressure gauge readings might be used to determine formation pressure? a) BOP manifold pressure gauge b) Choke console drill pipe pressure gauge c) Driller‟s console drill pipe pressure gauge d) Choke console casing pressure gauge 3. A kick is being circulated out at 30 SPM. The drill pipe pressure reads 550 psi, and casing pressure 970 psi. It is decided to slow the pumps to 20 SPM while maintaining 970 psi on the casing gauge. How will this affect bottom hole pressure (exclude any Equivalent Circulating Density [ECD] effect)? Pick one answer. a) Increase b) Decrease c) Stay the same d) No way of knowing 4. While killing a well, as pump speed is increased, what should happen to casing pressure in order to keep bottom hole pressure steady? a) Casing pressure should be held steady during SPM change b) Casing pressure should be allowed to rise during SPM change c) Casing pressure should be allowed to fall during SPM change 5. The principle involved in Constant Bottom Hole Pressure methods of well control is to maintain a bottom hole pressure that is : a) Equal to the slow circulating rate pressure b) At least equal to the formation pressure c) Equal to the shut in drill pipe pressure d) At least equal to the shut in casing pressure
WELL CONTROL
6. At what point while correctly circulating out a gas kick is it likely that the pressure at the casing shoe to be at its maximum?
a) At initial shut in b) When kill mud reaches the bit c) When kill mud reaches the shoe d) When top of gas reaches the shoe 7. If Drill pipe Pressure is held constant while displacing the string with kill mud, what will happen to Bottom Hole Pressure?
a) Increases b) Remains the same c) Decreases 8. How is a choke wash-out recognized? a) Rapid rise in casing pressure with no change in drill pipe pressure b) Increase in drill pipe pressure with no change in casing pressure c) Continually having to open choke to maintain drill pipe and casing pressure d) Continually having to close choke to maintain drill pipe and casing pressure 9. The choke has to be gradually closed due to a string washout. What effect does the gradual closing of the choke have on the bottom hole pressure?
a) Decreases b) Increases c) Stays the same 10. If Bottom Hole Pressure is held constant while circulating the influx out, the pressure on at the casing shoe will not increase after the influx passes, even though surface pressure on the annulus continues to rise. a) True b) False Questions 10-18 are based upon the following information : A well is closed in having taken a 30 bbl gas kick, while drilling 8 ½” hole at 11,000 ft. (TVD) with 5” drill pipe and 750 ft. of 6 ½” drill collars Annular capacities 5" DP / 8 ½" Hole, = 0.0459 bbls / ft. DC /8 ½" Hole, =0.0292 bbls / ft
WELL CONTROL
11. The mud weight is 12.3 ppg and the Shut in Drill Pipe Pressure is 350 psi. Assuming the gas Pressure Gradient to be 0.115 psi/ft, what will be the approximate Shut in Casing Pressure: a) 835 psi b) 650 psi c) 975 psi d) 888 psi 12. While preparing to circulate Kill Mud, the gas bubble begins to migrate. If no action is taken, what will happen to the pressure in the gas bubble as it rises: a) Increase b) Decrease c) Remain approximately the same 13. What will happen to Bottom hole Pressure? a) Increase b) Decrease c) Remain approximately the same 14. What will happen to Shut in Casing Pressure? a) Increase b) Decrease c) Remain approximately the same 15. What will happen to the pressure on the Casing Seat? a) Increase b) Decrease c) Remain approximately the same 16. If you decide to bleed enough mud to keep the Drill Pipe Pressure constant at 350 psi, what would the pressure in the bubble do as the gas rises? a) Increase b) Decrease c) Remain approximately the same 17. What would happen to Bottom Hole Pressure? a) Increase b) Decrease c) Remain approximately the same
WELL CONTROL
18. What would happen to the Shut in Casing Pressure? a) Increase b) Decrease c) Remain approximately the same 19. What would happen to the Pressure on the Casing Seat while the bubble is below the Casing Shoe? a) Increase b) Decrease c) Remain approximately the same 20. What would happen to the Pressure on the Casing Seat when the bubble is above the Casing Shoe? a) Increase b) Decrease c) Remain approximately the same 21. A kick is being circulated from a well using the Driller‟s Method; Pumping pressure having been established as 1000 psi at 30 SPM. During the operation, pressure suddenly increases to 1350. You are reasonably sure that a Nozzle of the Bit is plugged. What should you do? a) Reduce pump pressure to 1000 psi by adjusting the choke b) Shut the well in and re-establish the pumping pressure c) Hold casing pressure constant at the value recorded just before the bit plugged d) (a) and (b) are acceptable courses of action 22. During the well kill operation, slowly but regularly you have had to reduce choke size because the drill pipe and casing pressures keep dropping with constant pump strokes. What is the likely cause of this? a) A bit nozzle is washing out b) The choke is washing out c) You have a washed out pump swab 23. An influx is being circulated out using the Driller‟s Method and using 1100 psi at 30 SPM. The operator increases pump speed to 35 SPM, while holding pump pressure constant. What happens to Bottom Hole Pressure? a) Increases b) Decreases c) Remains approximately the same
WELL CONTROL
24. Which of the following parameters can be affected by a drill string washout during a well kill operation? a) Bottom hole pressure b) Kick tolerance c) Formation fracture pressure d) Slow circulating rate pressure
25. You are killing a well using the Drillers Method, maintaining constant Drill pipe pressure. The drill pipe pressure begins to drift down, but the casing pressure remains unchanged. The pump strokes remain constant. You close up your choke slightly, the drill pipe pressure remains unchanged but the casing pressure goes up. What is the probable cause for this? a) Choke is plugging off b) Bit is plugging off c) Hole in drill pipe d) Choke is washing out 26. If regularly and rather slowly, you have to pinch in the choke to maintain drill pipe and choke pressures while the pump strokes remain constant, you may have: a) a washed out bit nozzle b) a washed out choke c) a pump failure 27. How can a washout at the adjustable choke be recognized? a) Drill pipe and casing pressures both falling b) Drill pipe and casing pressures both rising c) Rapid rise in casing pressure with no change to drill pipe pressure d) Increase in drill pipe pressure with no change to casing pressure 28. The reason shut in casing pressure is usually higher than the shut in drill pipe pressure is: a) The cuttings in the annulus are lighter, therefore creating a lighter hydrostatic in the annulus. b) The influx fluid is usually less dense than the existing mud weight. c) The casing pressure is not necessarily higher, it depends on whether it is an offshore or land operation. d) The only difference is in the type of gauges used.
WELL CONTROL
29. After shutting in on a kick, the SIDPP and SICP are observed to be stable for fifteen minutes. Both, then, start rising slowly by the same amount. Which one of the following is the probable cause? a) A further influx is occurring b) The influx is migrating up the well bore c) The gauges are faulty d) The BOP stack is leaking 30. After a round trip at 9854 ft with 10.3 ppg mud, we kick the pump in and start to circulate. The well kicks and is closed in with 0 psi on the SIDPP and 150 psi on the SICP. There is no float in the drill string. What kill mud weight is required? a) 10.3 ppg b) 11.3 ppg c) 10.7 ppg d) No way of knowing 31. Shut in casing pressure is used to calculate a) Kill weight mud b) Influx gradient and type when influx volume and well geometry are known c) Maximum Allowable Annular Surface Pressure d) Initial circulating pressure 32. A kicking well has been shut in. The drill pipe pressure is „0‟ because there is a nonreturn valve (float) in the string. To establish the SIDPP, what action should be taken? a) Shearing the pipe and reading the SIDPP directly off the casing gauge b) Pump at kill rate into the drill string with the well shut in. When casing pressure starts to rise, read the pump pressure. This is the SIDPP. c) Pump very slowly into the drill pipe with the well shut in. When the pumping pressure stabilizes, the float has opened. This pumping pressure is the SIDPP. d) Bring the pump up to the kill rate holding the casing pressure constant by opening the choke. The pressure shown when the pump is at kill rate is the SIDPP. 33. After circulating out a kick using the driller‟s method (no weight up), are the SICP and SIDPP about the same? a. yes b. no 34. A gas kick is being circulated up the well. What is the surface pit volume most likely to do? a) Increase b) Stay the same c) Decrease
WELL CONTROL
35. On a surface stack, what would happen if when bringing the pumps up to kill speed, the casing pressure was allowed to fall below shut in casing pressure? a) Formation would most probably break down b) More influx would be let into the well bore c) It would have no effect on anything 36. For each of the following statements, note whether it relates to the Drillers Method or the Wait and Weight Method. a) Minimize pressures generated in the annulus due to gas migration. Driller
W&W
b) Remove influx from well before pumping kill mud Driller
W&W
c) Pump kill mud while circulating influx up the annulus Driller
W&W
d) Maintain Drill Pipe pressure constant for 1 st circulation Driller
W&W
37. Which one of the following actions taken while stripping into the hole will help to maintain an acceptable bottom hole pressure? a) Pumping a volume of mud into the well, equal to the drill pipe closed end displacement at regular intervals b) Bleeding off the drill pipe steel displacement at regular intervals c) Pumping a volume of mud into the well, equal to the drill pipe steel displacement, at regular intervals d) Bleeding off the drill pipe closed end displacement at regular intervals 38. Which of the following statements is true? a) There is no difference between using the Drillers method and the Wait and Weight method b) If the kill mud is being circulated up the annulus before the kick has reached the shoe then Wait and Weight method will reduce the risk of breaking down the formation compared to using the Drillers method c) The Wait and Weight method should always be used because the pressure against the open hole will always be lower when using the Drillers method
WELL CONTROL
39. Mud weight increase required to kill a kick should be based upon : a) shut in drill pipe pressure b) shut in casing pressure c) original mud weight plus slow circulation rate pressure losses d) shut in casing pressure minus shut in drill pipe pressure
40. How is the Initial Circulating Pressure found on a land rig or a jack-up, when the slow pump rate circulating pressure is not known but a kick has been taken? a) Circulate at desired strokes per minute to circulate out the kick, but hold 200 psi back pressure on drill pipe side with choke b) Add 400 psi to casing pressure and bring pump up to kill rate while using the choke to keep the casing pressure +400 constant c) Bring pump strokes up to kill rate while keeping casing pressure constant by manipulating the choke, observed pump pressure is ICP d) Add 1000 psi to shut in drill pipe pressure and circulate out the kick 41. Having completed the first circulation of the Driller‟s Method, the well is shut in. Should casing pressure be: a) Less than Shut in Drill Pipe Pressure b) Equal to Shut in Drill Pipe Pressure c) Greater than Shut in Drill Pipe Pressure 42. On the second circulation of the Driller‟s method, if the casing pressure was held constant until the kill mud reached Surface, what would happen to the bottom hole pressure? a) Increase b) Decrease c) Stay the same
43. Using Wait and Weight method, if the drill pipe pressure drops below the line of the graph as the kill mud goes down, what happens to the bottom hole pressure? a) Increases b) Decreases c) Stays the same
WELL CONTROL
44. You have taken a kick with a non-return valve (float) in the drill string. After shutting the well in properly, it is best to : a) Use the annulus pressure to calculate the kill weight mud b) Start raising the mud weight 1 ppg per circulation until the well is dead c) Use either the rig pump or cementing unit pump to increase pressure in 100 psi increments until a change is seen on casing gauge d) Pump slowly into the drill pipe. When the pump pressure stabilizes, the float is open. The pumping pressure is the SIDPP used to calculate kill mud 45. A well is being killed using the Driller‟s Method. Original shut-in drill pipe pressure = 500 psi Original shut-in casing pressure = 900 psi After the first circulation, the well is shut in and pressures allowed to stabilize. They then read : Shut-in drill pipe pressure = 500 psi Shut-in casing pressure = 650 psi It is decided not to spend any more time cleaning the hole Which one of the following actions should be taken a) Prepare to use the Wait and Weight method b) Bull-head the annulus until shut-in casing pressure is reduced to 500 psi c) Reverse circulate until shut-in casing pressure is reduced to 500 psi d) Continue with second circulation of Drillers Method (holding casing pressure constant until mud reaches the bit) 46. If the slow pump circulating pressure was not known, and a kick has been taken with the well closed in, how would you find the ICP? a) Bring pump up to the desired rate, while holding the casing pressure 150 psi above the original SICP b) Bring pump up to desired rate, but hold 200 psi back pressure on the drill pipe c) Bring pump up to the desired rate holding casing pressure constant by manipulating the hydraulic choke d) Circulate at desired kill rate but hold casing pressure 100 psi below MAASP 47. The correct gauge to use for calculating the kill weight mud is : a) the gauge on the choke and kill manifold b) the drill pipe pressure gauge on the drillers console c) the casing gauge on the drillers console d) the drill pipe gauge on the remote auto choke panel e) the casing gauge on the remote auto choke panel
WELL CONTROL
EXERCISE # 6 1. What is the primary function of the weep hole (drain hole, vent hole) on a ram type BOP? a) To show that ram body rubber is leaking. b) To show that the primary mud seal on the piston rod is leaking. c) To show that the Bonnet seals are leaking. d) To show that the closing chamber operating pressure is too high. 2. You only have one inside BOP with an NC 50 (4”1/2 IF) lower pin connection on your rig but the drill string consist of 5” HWDP, and 8” collars. Which one of the following crossovers would you have on the drill floor in case of kick while tripping? a) 6-5/8” reg. Box X 7-5/8” reg. Pin b) NC50 (4-1/2” IF) Pin X 6-5/8” reg. Pin c) NC50 (4-1/2” IF) Box X 7-5/8” reg. Pin d) NC50 (4-1/2” IF) Box X 6-5/8” reg. Pin 3. Two types of valves may be used in the drill string: Type 1 Non return, stab in safety valve or inside BOP Type 2 Fully opening stab in Kelly cock valve or fully opening safety valve Indicate in the table which statement describes the valves. Type 1
Type 2
Requires the use of key to close Must not run in the hole in the close position Has to be pumped to read “shut-in drill pipe pressure” Will not allow wireline to be run inside the drill string Has potential to leak through the open/close key Easier to stab if strong flow is encountered up the string 4. A BOP stack is configured: Pipe ram / Blind-Shear ram / Pipe ram / Annular, kill and choke lines are connected under the blind-shear rams. Is it possible to kill a well using the Driller's method if; a) The upper pipe rams are closed? b) The blind shear rams are closed? c) The lower pipe rams are closed? 5. A BOP stack is configured: Pipe ram / pipe ram / Blind-Shear ram / Annular, kill and choke lines are connected under the blind-shear rams. a) Can you repair the side outlets with pipe in the hole? b) Can you repair the outlets with no pipe in the hole? c) Is it possible to shut in with drill pipe in the hole and circulate through the drill pipe? d) Can you change blind rams to pipe rams and kill the well? 6. A BOP stack is configured: Drilling spool / Pipe ram / Blind-Shear ram / Annular, kill and choke lines are connected to the drilling spool. a) With drill pipe in hole, can we repair the side outlets? b) With no drill pipe in the hole, can you shut in and repair the Drilling spool? c) With drill pipe in hole, can you circulate through the Drilling spool?
WELL CONTROL
7. The kill line should enter a stack so that a) The well can be circulated if the blind rams are in use. b) The well can be circulated if the pipe rams are being used. c) Both the above. 8. Which of the following statements are true concerning Ram Packing Elements? a) Reciprocating motion of the pipe increases the wear on seals. b) Closing pipe rams on open hole may damage the elements. c) The ram packer should normally be checked, and if worn, changed whenever the bonnet is opened. d) All of above. 9. What do the term “6BX” stamped on a flange represent? a) serial number b) pressure rating c) type d) size 10. What is meant by the closing ratio for a ram type BOP? a) Ratio between closing & opening volume. b) Ratio between closing & opening time. c) Ratio of the wellhead pressure to the pressure required to close the BOP. 11. Study the two tables below which contain markings stamped on API flanges and ring gaskets. Each flange (1,2,3 and 4) mates with one of the ring gaskets (A,B,C or D). Write the appropriate flange number in the blanks. Ring Gasket Marking Flange A -CI API BX154 S304-4 B -OES API R57 D-4 C- OES API RX66 S-4 D -CI API BX153 S316-4 Flange Marking 1. 2. 3. 4.
OES API 16-3/4 3M RX66 6A 89 300F PSL3 05/91 CI API 3-1/16 15M BX154 CRA 6A 89 250F PSL2 PRL2 08/92 OES API 2-9/16 20M BX153 CRA 6A 89 350F PSL4 PRL4 01/94 OES API 13-5/8 2M R57 6A 89 250F PSL1 PRL1 11/93 Gasket A B C D
Flange
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12. From the list below, identify the ring gaskets that are pressure energized. (Pick four answers) a) Type RX b) Type BX c) Type AX d) Type R oval e) Type R octagonal f) Type CX 13. Which dimension from the list below is used to identify the “Nominal Flange Size” a) Throughbore I.D. b) Flange O.D. c) Diameter of raised face. d) O.D. of ring groove. e) Bolt circle diameter. 14. What is the main function of a diverter? a) To shut in a shallow kick. b) To direct fluid a safe distance away from the rig floor. c) To create a back pressure sufficient to stop formation fluids entering the wellbore. d) To act as a back up system if the annular preventer fails. 15. In an area where local legislation requires that BOP equipment must be rated so that maximum anticipated formation pressures do not exceed 75% of BOP equipment pressure ratings, what is the minimum acceptable rating for equipment to be used in drilling normally pressure formation to 16000 ft TVD? a) 2000 psi BOP equipment b) 3000 psi BOP equipment c) 5000 psi BOP equipment d) 10000 psi BOP equipment e) 15000 psi BOP equipment
16. A BOP stack is configured Pipe Ram / Blind-Shear ram / Pipe Ram / Annular. Use the table below to calculate the required accumulator volume if company policy is to provide sufficient volume to close, open and close again all rams and the annular. Component Annular BOP Ram BOP
Volume to Open 27 13
Volume to close 29 15
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17. The following statements relate to the driller‟s remote control BOP control panel located on the rig floor. Decide if the statements are true or false. a) If you operate a function without operating the master control valve that function will not work. True or False b) The master control valve on an air operated panel allows air pressure to go to each function in preparation for you operating the function. True or False c) The master control valve must be held depressed while BOP functions are operated. True or False d) The master control valve must be depressed for five seconds then released before operating a BOP function. True or False 18. The API RP53 states that closing time should not exceed X seconds for annular BOPs smaller than 18-3/4". What is the value of X? a) 30 sec. b) 60 sec. c) 2 min. d) 45 sec.
19. Which is the correct definition of the HPU reservoir volume according to API RP53? a) 2 times usable accumulator volume. b) 2 times accumulator volume. b) 5 times total accumulator volume . 20. Which two pressure readings decrease during normal operation of the pipe rams? a) Manifold pressure b) Annular pressure c) Accumulator pressure c) Precharge pressure 21. When closing the annular preventer from the remote panel, which two gauges show a reduction in pressure? a) Manifold pressure b) Annular pressure c) Accumulator pressure d) Air pressure
WELL CONTROL
22. In the case below, identify the most likely problem from the gauge readings observed on the remote control panel. The annular setting is 900 psi, the manifold setting is 1,500 psi. a) Everything is OK. b) Malfunction pressure regulating valve. c) Malfunction hydro-electric switch d) Leaking in hydraulic circuit e) Precharge pressure is to low 23. A BOP operating unit has 8 accumulator bottles, each with a capacity of 10 gallons. Operating pressure is 3000 psi. Precharge pressure is 1000 psi. What is the total usable fluid volume when the minimum BOP operating pressure is 1,200 psi? Answer: gal 24. On a 3000 psi accumulator system, what are the normal operating pressures seen on the following gauges on the drillers remote control panel?
Air pressure Accumulator pressure, Manifold pressure, Annular pressure
= = = =
psi psi psi psi
25. On which two gauges on the remote panel would you expect to see reduction in pressure when the annular preventer is being closed?
26. If the air pressure on the drillers panel reads 0 psi, which of the following statements is true? a) No stack function can be operated from the remote panel. b) All stack function can be operated from the remote panel. c) Choke and kill lines can still be operated from the remote panel. d) The annular preventer can still be operated from the remote panel.
27. Which of the problems below would not stop the BOP from closing? a) Master control valve was not held down. b) Four-way valve did not shift position. c) Closing line in the BOP was blocked. d) Leak in the hydraulic line to the BOP or in the BOP closing chamber. e) Air pressure to the panel was lost. f) A bulb has blown on the remote panel.
WELL CONTROL
28. When drilling, which may be the correct position of the 4-way valves on the BOP accumulator unit? a) open b) close c) neutral d) open or closed depending on BOP stack function
29. What is the normal precharge for the accumulator bottles on a 3000 psi accumulator unit? a) 1000 psi b) 3000 psi c) 1200 psi d) 200 psi
WELL CONTROL
EXERCISE # 7 Use the Well Data to answer the questions. WELL DATA Well Depth Kick Off Point End Of Build Bit size Drill Pipe Heviwate Drill Collars Casing
Formation strength test Mud weight in use Surface Volume Pumps
8,554 ft TVD 10,500 ft MD 4,000 TVD / 4,000 MD 5,447 TVD / 5,667 MD 8.5” 5” OD. 19.5 lbs/ft Capacity = 0.01776 bbls/ft 5” OD x 3” ID x 720 ft Capacity = .00874 bbls/ft 61/2” x 213/16” x 820 ft Capacity = 0.0077 bbls/ft 95/8”, 47 lb/ft. P110 8.681” ID 100% Internal yield = 10,900 psi Set at 6,175 ft TVD / 6,800 MD 1,270 psi w/ 10.4 ppg 11.5 ppg. 320 bbls National triplex 12-P-160 With 61/2” Liners Capacity = 0.117 bbls/stk PUMP PRESSURE
Slow Pump Rate
520 psi at 40 spm
ANNULAR VOLUMES Drill pipe/HW - Casing Drill pipe/HW - Open hole Drill collars - Open hole
= 0.0478 bbls/ft = 0.0447 bbls/ft = 0.0292 bbls/ft WELL CONTROL DATA
SIDPP SICP GAIN
= 750 psi = 900 psi = 22 bbls
You are recommended to complete a kick sheet to answer the following questions:
WELL CONTROL
1. How many strokes to pump from surface to bit:
2. What is the Initial Circulating Pressure?
3. What is the Final Circulating Pressure?
4. How many strokes to pump from surface to KOP?
5. What is the circulating pressure when kill mud reaches the KOP?
6. How many strokes to pump from surface to the EOB?
7. What is the circulating pressure when kill mud reaches the EOB?
8. Calculate the pressure drop per 100 strokes of kill mud pumped inside the string from the EOB to the bit?
WELL CONTROL
9. Calculate MAASP after circulation of kill mud?
10. What is the approximate time needed to kill the well?
WELL CONTROL
EXERCISE # 8 Use the Well Data to answer the questions. Each question has only one correct answer. WELL DATA Well Depth
15,700 ft TVD 16,500 ft MD 1700 ft capacity = 0.360 bbls/ft 1724 ft capacity = 0.0087 bbls/ft 8.5” 5” OD. 19.5 lbs/ft Capacity = 0.01776 bbls/ft 61/2” x 213/16” x 540 ft Capacity = 0.008 bbls/ft 95/8”, 47 lb/ft. P110 8.681” ID 100% Internal yield = 10,900 psi Set at 14,000 ft TVD – 14,200 ft MD RKB 12.4 ppg. 0.117 bbls/stk
Marine riser Choke line Bit size Drill Pipe Drill Collars Casing
Mud weight in use Pump output
PUMP PRESSURE While Drilling Slow Pump Rate Up Riser CLFL with 11 ppg mud
3500 psi at 75 spm (APL = 270 psi) 980 psi at 40 spm (APL = 75 psi) 250 psi at 20 spm (APL = 20 psi) 125 psi at 20 spm 500 psi at 40 spm ANNULAR VOLUMES
Drill pipe - Casing Drill pipe - Open hole Drill collars - Open hole Drill pipe – Riser
= 0.0489 bbls/ft = 0.0459 bbls/ft = 0.0292 bbls/ft = 0.336 bbls/ft
WELL CONTROL DATA SIDPP SICP GAIN
= 700 psi = 1150 psi = 30 bbls LEAK OFF TEST DATA
3650 PSI with 11 ppg mud
WELL CONTROL
1. What is the total capacity of the drill string? a) b) c) d)
288 bbls 162 bbls 335 bbls 456 bbls
2. Calculate the total annular capacity with the pipe on bottom? a) b) c) d)
722 bbls 443 bbls 987 bbls 323 bbls
3. What is the surface to bit time with the pump running at 40 spm? a) b) c) d)
61 minutes 25 minutes 87 minutes 54 minutes
4. Calculate bit to surface time (bottoms up) at 40 spm? a) b) c) d)
155 minutes 234 minutes 60.3 minutes 123 minutes
5. What kill mud is required to balance formation pressure? a) b) c) d)
13.3 ppg 13.0 ppg 12.4 ppg 16.0 ppg
6. The ICP (initial circulating pressure) at 40 spm will be approximately? a) b) c) d)
1680 psi 770 psi 2130 psi 1200 psi
7. The FCP (final circulating pressure) at 40 spm will be approximately? a) b) c) d)
approximately 1800 psi approximately 1050 psi approximately 1500 psi approximately 1290 psi
WELL CONTROL
8. After reaching FCP it is decided to increase the pump speed to 50 spm. What would happen to BHP if the drill pipe pressure is held constant at the original FCP value? a) b) c) d)
increase by about 590 psi decrease by about 590 psi remain constant because drill pipe pressure was not changed increase by about 500 psi
9. What is formation pressure based on the shut in data? a) b) c) d)
10,823 psi 6800 psi 7800 psi 6240 psi
10. What is the ECD on bottom while drilling? a) b) c) d)
12.73 ppg 15.54 ppg 16.03 ppg 16.52 ppg
11. What would be the circulating pressure while drilling if the pump was decreased to 60 spm? a) b) c) d)
2240 psi 2800 psi 2100 psi 1860 psi
12. At 75 spm what is the annular velocity around the drill collars? a) b) c) d)
412 ft/min 210 ft/min 506 ft/min 300 ft/min
13. What is the maximum allowable mud weight? a) b) c) d)
17.5 ppg 16.0 ppg 18.0 ppg 19.0 ppg
WELL CONTROL
14. What is the approximate length of the influx? a) b) c) d)
1027 ft 850 ft 653 ft 342 ft
15. The gradient of the influx is about? a) b) c) d)
0.115 psi/ft 0.320 psi/ft 0.465 psi/ft 0.433 psi/ft
16. How many strokes to go from ICP to FCP? a) b) c) d)
1282 stks 1363 stks 1680 stks 2461 stks
17. Calculate the MAASP? a) b) c) d)
2620 psi 2524 psi 2368 psi 1356 psi
18. Not following the the correct pressure schedule, the BHP could be high or low causing losses or another influx. a) True b) False 19. What is the capacity of the choke line: a) b) c) d)
15 bbls 12 bbls 23 bbls 28 bbls
20. How many strokes are required to displace the riser – annulus a) b) c) d)
7034 strokes 4882 strokes 3453 strokes 1234 strokes
WELL CONTROL
21. If the well had been shut in with 0 psi on the drill pipe pressure and no float in the string and a SICP of 300 psi, what mud weight would have required to kill the well? a) b) c) d)
12.9 ppg 12.4 ppg 14.5 ppg 15.5 ppg Answer the following gauge questions as the well is killed using the Drillers method. TO TA L STR O KES 90 0 1000 1 100 80 0 70 0
900 10 00 1100
1 20
1200
800
600
PSI
160 0
200
1600 1 700
300 200
1 800 1 00
14 00 1 500
4 00
1700
3 00
PSI
5 00
15 00
400
13 00
6 00
1400
5 00
1 200
700
1300
1900
40
D R ILLPIPE PR E SSU R E
18 00 10 0
PU M P SPEED
1 900
C AS IN G P R ESSU R E
1 6 80
590 C H O KE P O S IT IO N
O P EN
C LO S E
22. The kill operation has started. This is what the choke control console shows. What should you do? a) b) c) d) e)
open the choke a little close the choke a little nothing everything looks alright Possible plugged nozzle Possible choke plugging
TO T A L S TR O K E S 900 100 0 1 100 800 70 0
900 100 0 11 00
500
120 0
800
60 0
PSI
16 00
2 00
160 0 170 0
300 2 00
1800 1 00
1400 1 500
40 0
170 0
300
PSI
5 00
1500
40 0
130 0
60 0
140 0
5 00
120 0
70 0
130 0
1 900
PUMP SPEED
D R ILLP IP E P R E S S U R E
40
1 800 100
C A S IN G P R E S S U R E
1620
700 O PE N
CH O KE P O S ITIO N
1 900
C LO S E
WELL CONTROL
23. Pit room calls up to confirm a .5 bbl rise in the level. What should you do? a) b) c) d) e)
open the choke a little close the choke a little increase the pump speed decrease the pump speed nothing everything looks alright TO TA L STR O KES 900 1000 1100 8 00 700
900 1000 1100
4550
1200
800
600 500
1600
200
1500
400
1700
300
1600 1700
300 200
1800 100
1400
PS I
500
1500
400
1300
600
1400
P SI
1200
700
1 300
1900
40
D R ILLP IPE PR E SSU R E
1800 100
PU M P SPEED
1900
CASIN G PR ESSU R E
1 6 80
1 4 80 CH OK E PO SITIO N
O PEN
C LOS E
24. The pit levels are still reported to be increasing slightly. This is what you see on the panel. a) b) c) d) e)
open the choke a little close the choke a little possible choke washout possible choke plugging nothing everything looks alright
TOTAL STROK ES 90 0 1000 11 00 8 00 70 0
900 1000 1100
5600
1200
800
600
PSI
1600
200
1600 1700
300 200
1800 100
1400 15 00
400
1 70 0
300
PSI
50 0
1500
400
1300
600
140 0
500
12 00
700
1 300
1 900
P UM P SPE ED
DR ILLPIPE PRE SSU RE
40
180 0 100
1900
CASIN G PRESS UR E
1400
1720 OP EN
CHO KE PO SITION
CL OSE
WELL CONTROL
25. Experienced a sudden increase in casing pressure over the last 100 strokes. Gas is venting and pit levels are reported to be falling. What are you going to do now? a) b) c) d) e)
open the choke a little close the choke a little possible nozzle plugging possible choke plugging nothing everything looks alright TO TAL STRO KES 900 1000 1100 800 700
900 1000 1100
6220
1200
800
600
PSI
1600
200
1600 1700
300 200
1800 100
1400 1500
400
1700
300
PSI
500
1500
400
1300
600
1400
500
1200
700
1300
1900
40
D R IL L P IP E P R E S S U R E
1800 100
PUMP SPEED
1900
C A S IN G P R E S S U R E
1680
1 40 OPEN
CHOKE POSITION
CLOSE
26. Not hearing anymore gas. How are things going? a) b) c) d) e)
open the choke a little close the choke a little casing pressure should be 0 possible choke wash out good everything looks alright
TO TA L S TR O K E S 90 0 1000 1 100 80 0 70 0
900 10 00 110 0
6300
120 0
80 0
600
PSI
160 0
200
150 0
400
1700
3 00
1600 1 700
30 0 200
1 800 1 00
1900
PUMP SPEED
D R ILLP IP E P R E S S U R E
00
18 00 1 00
1 900
C A S IN G P R E S S U R E
700
700 O P EN
14 00
PSI
5 00
1 500
400
13 00
600
1400
500
1 200
700
1300
C H O KE P O S IT IO N
C LO S E
WELL CONTROL
27. Shut back in. What should you do? a) b) c) d) e)
Check MW = 13.3 ppg Check MW = 16 ppg Reset stroke counter Bleed off pressure to 0 nothing everything looks alright TO TA L S TR O K ES 900 1000 1100 800 70 0
900 1000 1100
0000
1 200
800
600 500
16 00
200
1500
400
1700
300
1600 170 0
300 200
1800 100
1400
P SI
500
1500
400
1 300
600
1400
PSI
120 0
700
1300
1900
40
D R ILLP IPE PRES SU R E
1800 100
PU M P SPEED
1900
C AS IN G PR ESSU R E
1 7 80
236 O P EN
CH O K E PO SITIO N
C LOS E
28. Got the pump to kill speed and have just reset the stroke counters having pumped the surface line. What should you do? a) b) c) d) e)
open the choke a little close the choke a little increase the pump speed decrease the pump speed nothing everything looks alright TOTAL STROK ES 90 0 1000 11 00 8 00 70 0
900 1000 1100
250
1200
800
600
PSI
1600
200
1600 1700
300 200
1800 100
1400 15 00
400
1 70 0
300
PSI
50 0
1500
400
1300
600
140 0
500
12 00
700
1 300
1 900
P UM P SPE ED
DR ILLPIPE PRE SSU RE
40
180 0 100
1900
CASIN G PRESS UR E
1620
140 OP EN
CHO KE PO SITION
CL OSE
WELL CONTROL
29. Pump room is on the phone saying pit levels are OK. What are you going to do now? a) b) c) d) e)
open the choke a little close the choke a little possible nozzle plugged possible choke plugged nothing everything looks alright TO TAL STRO KES 900 1000 1100 800 700
900 1000 1100
980
1200
800
600
PSI
1600
200
1600 1700
300 200
1800 100
1400 1500
400
1700
300
PSI
500
1500
400
1300
600
1400
500
1200
700
1300
1900
40
D R IL L P IP E P R E S S U R E
1800 100
PUMP SPEED
1900
C A S IN G P R E S S U R E
1430
1 40 OPEN
CHOKE POSITION
CLOSE
30. Drill pipe pressure is falling but casing pressure stay constant. How are things going? a) b) c) d) e)
open the choke a little close the choke a little increase the pump speed possible choke wash out good everything looks alright T O TA L S TR O K E S 90 0 1000 1 100 80 0 70 0
900 10 00 1100
1720
1200
800
600 5 00
160 0
200
1600 1 700
300 200
1 800 1 00
1 500
4 00
1700
3 00
14 00
PSI
5 00
15 00
400
13 00
6 00
1400
PSI
1 200
700
1300
1900
PUMP SPEED
D R ILLP IP E P R E S S U R E
00
18 00 10 0
C A S IN G P R E S S U R E
220
700 O P EN
C H O KE P O S IT IO N
1 900
C LO S E
WELL CONTROL
31. Had to shut in because of a pump. What do you thing? a) b) c) d) e)
Drill pipe pressure is too low Casing pressure is too high Drill pipe pressure is too high Casing pressure is too low Everything looks alright TO TA L S TR O K ES 900 1000 1100 800 70 0
900 1000 1100
2480
1 200
800
600
PSI
16 00
200
1500
400
1700
300
1600 170 0
300 200
1800 100
1400
P SI
500
1500
400
1 300
600
1400
500
120 0
700
1300
1900
D R ILLP IPE PRES SU R E
40
1800 100
PU M P SPEED
1900
C AS IN G PR ESSU R E
1 0 50
130 O P EN
CH O K E PO SITIO N
C LOS E
32. Back up to kill speed. Company man wants to know how things are going. What do you tell him? a) b) c) d) e)
open the choke a little close the choke a little possible choke plugging possible nozzle plugging nothing everything looks alright
WELL CONTROL
EXERCISE # 9 1. A driller needs to close in a flowing well with drill pipe in a subsea BOP stack. He Pushes the “Annular Close” button and the pilot light changes, but all gauges and the flow meter remain static. What is his best option? a) Change pod and try again. b) Call and wait for the subsea engineer. c) Send assistant driller to manually operate the 4-ways valve on the Hydraulic Control Manifold to close the annular. d) Close the lower annular preventer. 2. While drilling, an alarm goes off indicating low accumulator pressure and the flow meter Indicates a rapid loss of fluid. The best course of action is: a) Stop drilling and shut the well in. b) Stop drilling and call subsea engineer. c) Stop drilling and put all function in block one at a time until the flow stops. d) None of the above. 3. When a function is operated, which of the following is true? a) SPM valve will operate in both pods. b) SPM valve will operate only on the active pod. c) The SPM valve will operate after the function is complete. 4. How much time is allowed for subsea ram type preventer to close in API RP53? a) b) c) d)
30 seconds 45 seconds 60 seconds 50 seconds
5. From which position in the hydraulic circuit is readback pressure taken? a) Upstream of the regulator in the pod? b) The regulator itself? c) Down stream of the regulator in the pod? 6. What is the principal reason for fitting ram locking devices such as wedgelocks or Poslocks to a subsea stack? a) To give additional force when closing in, thus reducing delay times. b) To lock the ram in the closed position and maintain the shear rams locked during disconnect. c) To lock the BOP stack to the well head and lock the lower Marine Riser Package to the BOP stack.
WELL CONTROL
7. The subsea hydraulic BOP control system is divided into a Control System and a Pilot System. Which two statements are true with respect to the Pilot System? a) The fluid in the Pilot System flows continuously while a function on the BOP takes place. b) The Pilot System dumps fluid to the sea at every operation of BOP functions. c) The Pilot System controls the position of all shuttle valves on the BOP stack directly. d) The Pilot system is a closed dead-end system. e) Pilot fluid consists of potable water, water-soluble concentrate and glycol. 8. Which two statements are true with respect to shuttle valves on a subsea stack? a) The shuttle valves automatically seal any hydraulic leaks in the selected pod. b) The shuttle valves prevent communication between the selected system and the redundant system. c) The shuttle valves are pilots operated. d) The shuttle valves allow the retrieval of a malfunctioning pod without losing hydraulic BOP control. 9. What is the purpose of the "Memory Function" on electric control panels? a) Memory Function indicates a malfunction by giving permanent light on the alarm panel after an alarm has been acknowledged and the audible alarm has stopped. b) Memory Function reminds the driller to add anti-freeze fluid when the temperature drops below a set level. c) Memory Function indicates the previous position before “Block position” of three position functions. d) Memory Function reminds the driller to engage Wedge Locks before hanging off. 10. Which of the following statements is true regarding to the use of “manipulator” type 4Ways valve used in subsea hydraulic BOP control systems. a) If the valve is shifted to the center or “block” position, pressure will be vented from the line previously pressurised. b) If the valve is shifted to the center or “block” position, pressure will be trapped in the line previously pressurised.
11. Name 3 potential causes of riser collapse:
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12. What is the purpose of sub-sea stack mounted bottles? a) b) c) d)
to minimize the time to operate any BOP function to maximize the time to operate any BOP function to minimize the time to operate annular type preventer to optimize the time to operate ram type preventer
The drillers BOP panel has gauges for pilot and readback pressure for the manifold and annular pressure. Answer true or false to the following statements: 13. Pilot pressure and readback pressure should normally be the same. a) true b) false 14. Read back pressure is mesured at the output from the sub sea regulator a) true b) false 15. Pilot pressure is measured at the out put of the surface regulator a) true b) false Answer true or false in each case to measure Choke Line Friction Loss (CLFL): 16. You can pump down the choke line taking return up the riser. a) true b) false 17. You need to know the length of the choke line. a) true b) false 18. You can pump down the drill string taking returns through the riser and then close the annular and take returns through the choke line. a) true b) false 19. While pumping down the choke line at 150 gpm taking returns through the riser with 9 ppg mud in 750 feet water with 60 feet air gap, a stand pipe pressure of 65 psi was recorded. Estimate CLFL: a) b) c) d)
30 psi 65 psi 351 psi 143 psi
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20. What would be the new CLFL if the mud weight is increased to 13.5 ppg (use data from Q-19) a) b) c) d)
65 psi 97.5 psi 132 psi 234 psi
21. While pumping down the drill string and up the riser, a circulating pressure of 375 psi was recorded. The annular was closed and returns taken through a wide open choke, circulating pressure was now 600 psi. What are the CLFL? a) b) c) d)
375 psi 975 psi 600 psi 225 psi
22. Calculate the Maximum Allowable Mud Weight with the following data: Hole size 17 ½”, Air gap is 80 ft, Water depth is 220 ft, Casing shoe is 600 ft RKB, Sea water is .455 psi/ft, Overburden is .65 psi/‟ft, APL is 10 psi a) b) c) d)
8.77 ppg 9.45 ppg 10.7 ppg 11.7 ppg
Air gap
Water depth
23. A semi is in 650 ft of water (.445 psi/ft) drilling without a riser. Air gap is 60 ft and TD / TVD is 1350 ft RKB. What is the BHP during connections? a) b) c) d)
450 psi 474 psi 550 psi 574 psi
Well depth
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24. What surface volume would 2 bbl of gas trapped in a sub sea BOP at 1900 ft water depth have if released and allowed to migrate through the riser filled with 12.9 ppg mud? a) b) c) d)
45 bbls 93 bbls 157 bbls 173 bbls
Air gap
Water depth
Well depth
25. A semi is drilling top hole with a riser and diverter installed connected to 30” casing. Air gap is 70 ft, water depth is 1523 ft, sea water is .465 psi/ft, TVD / TD is 2250 ft RKB and MW is 9.7 ppg. What would be the reduction in BHP if the riser were lost or removed? a) b) c) d)
30 psi 65 psi 95 psi no reduction
26. hat increase in mud weight is required to offset this? a) b) c) d)
1.34 ppg 1.67 ppg 2.23 ppg 2.78 ppg
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27. The recommended response time for sub sea BOP is: Rams to close in less than:
seconds
Annular should not exceed:
seconds
Time to unlatch LMRP should not exceed:
seconds
28. How can gas trapped in a subsea BOP be safely circulated out?
29. By how much would BHP change if a well was inadvertently opened before displacing riser to kill mud? MW=10.4 ppg KMW=10.9 ppg water depth=1342 ft a) b) c) d)
0 psi 35 psi 65 psi 90 psi
30. How many (.115bbl/st) strokes will it take to displace a 16” x 5” riser/drillpipe annulus (200 ft long)? a) b) c) d)
290 strokes 390 strokes 490 strokes 190 strokes
WELL CONTROL
31. The following drawing shows components of a subsea hydraulic control system. Each component has a number. Place the number next to the component in the list provided.
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Using the schematic diagram of a hydraulic valve, answer the following question:
32. How many positions can the valve be placed in: a. b. c. d.
2 3 4 8
33. How many active ports does the valve have? a. 2 b. 3 c. 4 d. 8 34. Can the valve be operated by: a. b. c. d.
manual function only remote function only air operated only manual or remote function
35. What is the name of this valve? a. Terminator b. Selector c. Manipulator 36. In the center or block position, the valve vents fluid lines to tank. a. True b. false
WELL CONTROL
WELL DATA: Well depth:
10,657 ft TVD RKB 12,000 ft MD
Air gap: Water depth: Sea water gradient: Mud weight:
60 ft 2150 ft .445 psi/ft 13.3 ppg
Air gap
Water depth
37. What mud weight increase is required to balance the well if the riser is to be removed? a. b. c. d.
2.4 ppg 5.1 ppg 1.3 ppg 13.3 ppg
38. A BOP drill was conducted and the well shut in on the upper annular preventer. If the choke line is filled with sea water and the fail safe valves are opened, what would be the the casing pressure read? a. b. c. d.
545 psi 945 psi 60 psi 245 psi
39. if the riser is lost in bad weather, what would be the bottom hole pressure reduce by? a. b. c. d.
350 psi 500 psi 480 psi 571 psi
40. If the riser had a collapse pressure of 500 psi, how far could the mud level fall before seawater collapses the riser? a. b. c. d.
1083 ft 1183 ft 1283 ft 1383 ft
Well depth
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41. If a function is made to close the hang off rams and your fluid counter continues to register fluid movement after the correct closing volume has gone passed, what would you consider doing? (1 answer) a. b. c. d.
Call the subsea engineer and let him sort it out Close another set of rams Put the operating unit into block position Everything is OK, continue
42. To find ICP, you must add the choke line friction to the slow circulating rate: a. True b. False 43. The hydraulic fluid system used to operate the subsea BOP‟s consist of potable water and additives. a. True b. False 44. The rig has an air gap of 80 ft. If the riser has a collapse pressure of 450 psi, how far would the mud level fall before it collapse if you are working in 1600 ft of .445 psi/ft of sea water? a. b. c. d.
1091 psi 1191 psi 1291 psi 1391 psi
45. Using the following data, calculate the expanded gas volume that would be at surface if 2 barrels of gas had remained trapped under the rams and was released into the riser when the well was opened back up after a successful operation? Well data: Choke line length: Riser length: Kill mud weight: Drilling mud: Atmospheric pressure: a. b. c. d.
113 bbls 123 bbls 133 bbls 143 bbls
1500 ft 1480 ft 12.5 ppg 11.2 ppg 14.7 psi
WELL CONTROL
46. Calculate the usable fluid in a 10 gallons bottle if the maximum pressure is 3000 psi, the mimimum is 1500 psi and the pre charge is 1000 psi? a. b. c. d.
5.00 gals 3.34 gals 6.63 gals 1.73 gals
47. If accumulator bottles were taken to the seabed with the same precharge as surface bottles, what effect would this have on the usable fluid? a. Increase b. Decrease c. Same volume as surface volume
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EXERCISE # 10 1. When using the choke to adjust pressure it is the Casing (Annulus) gauge that reacts to the adjustment before the Drill Pipe Gauge. a) True b) False 2. The choke is used to adjust Casing (Annulus) pressure, but to adjust the Drill Pipe pressure you have to change the pump rate. a) True b) False 3. The Casing (Annulus) gauge is always slower to react to any choke adjustment then the Drill Pipe Pressure. a) True b) False 4. The wait and weight method will always result in lower casing shoe pressures. a) True b) False 5. The wait and weight will result in lower casing shoe pressure if the open hole volume is less than the drill pipe capacity. a) True b) False 6. The Driller‟s method of well control will result in higher casing shoe pressures if the open hole volume is less than the drill pipe capacity. a) True b) False 7. The Driller‟s method of well control will result in the same pressure on the casing shoe if the open hole volume is less than the drill pipe capacity. a) True b) False
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8. Place the following statements in the correct order if you are using the Driller‟s Method. The well is already shut in.
NOTE : There are 3 INCORRECT statements in the list.
a) Bring pump up to kill speed holding casing pressure constant. b) Maintain casing pressure constant until kill mud is at the bit. c) Maintain pumping pressure constant until influx is out. d) Maintain drill pipe pressure constant until kill mud reaches surface. e) Shut-in the well and check both SICP and SIDPP are approximately equal. f) Bring pump up to kill speed holding casing pressure constant. g) Line up suction to kill mud. h) Maintain casing pressure constant until kill mud is pumped to surface. i) Maintain casing pressure constant for complete circulation. j)
Bring pump up to kill speed holding drill pipe pressure constant.
k) Shut in well and check for zero shut in pressure. Place your answers in order below : 1st __________
2nd ____________
3rd __________
4th ____________
5th __________
6th ____________
7th __________
8th ____________
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9. Place the following statements in the correct order if you are using the Wait and Weight to kill a well. The well is already shut in.
NOTE : There are 3 INCORRECT statements in the list.
a) Bring pump up to speed holding drill pipe pressure constant. b) Allow drill pipe pressure to fall from ICP to FCP as kill mud is pumped to bit. c) Bring pump up to speed holding casing pressure constant d) Maintain drill pipe pressure constant as kill mud pumped from bit to surface. e) Allow drill pipe pressure to fall gradually from ICP TO FCP as kill mud is pumped from suction pit to shaker. f) Shut down and check the well is dead.
1rst ________ 2nd _________ 3rd _________ 4th _________
10. Which of the following statements are True or False concerning the Wait and Weight method? a. In the Wait and Weight method the casing pressure should be kept constant during 2 nd circulation. a) True b) False b. In the Wait and Weight method , annulus pressures are kept lower than with the Driller‟s method. a) True b) False c. In the Wait and Weight method there are less calculations compared to the Driller‟s method. a) True b) False
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d. Only the Wait and Weight method the drill pipe pressure is held constant throughout. a) True b) False e. In the Wait and Weight method the drill pipe pressure is held constant throughout. a) True b) False f. In the Wait and Weight method the well is dead when you reach FCP. a) True b) False g. In the Wait and Weight method the drill pipe pressure should read zero, after surface to bit strokes have been pumped if you shut in the well. a) True b) False h. The wait and weight method must be used if insufficient barite is on board. a) True b) False i.
The Wait and Weight method does not require you draw a graph or step down chart. a) True b) False
j.
The Wait and Weight is the preferred method if MAASP is critical and the open hole capacity is greater the drill string capacity. a) True b) False
WELL CONTROL
11. Based on the following information : a. Will the Wait and Weight method give lower shoe pressures than the Driller‟s method? TVD Shoe Depth Surface to Bit Strokes Bit to Shoe strokes Bit to surface SIDPP SICP Present Mud Wt. Kill Mud Wt. MAASP Pit Gain
= = = = = = = = = = =
10,000 8,830 ft 1,629 1,304 stks 6,480 stks 500 psi 800 psi 10.3 11.3 1,300 30 bbls
ft stks
ppg ppg psi
Answer – Yes or No
b. Based upon same information above : Will the Wait and Weight Method give lower surface pressures than the Driller‟s Method? Answer – Yes or No 12. Company policy states “when killing a well you will always attempt to kill the well using a method that minimizes the pressure on the stack and upper casing”. Which method would you choose?
DRILLERS OR WAIT AND WEIGHT
13. Link the following by matching up the correct number to the correct letter. 1. One circulation lower annulus pressures. 2. Less calculations highest annulus pressures. 3. Most calculations moderate annulus pressures. A. Driller Method B. Concurrent Method C. Wait and Weight method
WELL CONTROL
14. Which of the following statements are true ? a. Surface line volume will affect the point at which kill mud will increase mud hydrostatic on bottom. b. Pump must be brought up to speed holding casing pressure constant c. Surface line volume does not need to be considered when starting to kill a well d. Maintain the drill pipe pressure constant when starting up the pump to kill speed.
TRUE STATEMENTS ARE____________________and ___________________________
15. Select one of the following statements that is TRUE concerning wellbore pressures when circulating a gas influx to surface. (Drillers Method) a. So long as the correct kill procedures are followed that part of the wellbore which is above a gas influx will have a constant pressure. b. So long as the correct kill procedures are followed that part of the wellbore which is below a gas influx will have a constant pressure.
c. So long as the correct kill procedures are followed that part of the wellbore which is below a gas influx will have an increasing pressure.
16. From the statements A to F below, place 3 of them correctly in the blanks provided : A
-
Drillers
B
-
Bring pump up to speed holding drill pipe pressure constant
C
-
Constant bottom hole pressure
D
-
Concurrent
E
-
Bring the pump up to speed holding the casing pressure constant
F
-
Drill pipe pressure constant
The main principle of well killing methods is to maintain _____________________
The most common methods are the Wait and Weight and ____________________ method
In both methods you must ______________________ when starting up.
WELL CONTROL
17. Which one of the following statements is true concerning wellbore pressure during the 1 st circulation of the Driller‟s method?
a. Pressure at any point above a gas influx is constant. b. Pressure at any point above a gas influx is decreasing. c. Pressure at any point above a gas influx is rising. d. Pressure at any point below a gas influx is decreasing. e. Pressure within a gas bubble remains constant. 18. A gas is being circulated up the hole during a kill operation what effect will this have on the pressures at the various locations listed. EFFECT IN PRESSURE LOCATIONS
Gas Bubble Surface Casing Gauge Casing shoe Bottom Hole At any point below gas bubble At any point above Gas bubble
Increase
Decrease
Stays the same
Increase at first Then remains constant
WELL CONTROL
19. While killing the well on the 1st Circulation of the Driller‟s method, the drill pipe pressure is 1,200 psi at 30 spm. Casing pressure is 1,000 psi. Very quickly the drill pressure increases to 1,500 psi but no change in casing pressures. Pump rate still holds at 30.
You decide to open the choke to bring the drill pipe pressure back to 1,200 psi with 30 spm.
What has happened to bottom hole pressure ?
a. Increase b. Decrease c. Stay in the same. 20. In the previous example you decided to stop the pump and close the choke before making a decision. You think that the nozzles may be blocking. What would you do?
a. Start pump up to 30 spm and manipulate choke to get 1,200 psi on drill pipe. b. Start pump up to 30 spm holding the choke pressure constant. Once pump is up to speed note the drill pipe pressure and hold that constant for rest of 1st circulation. c. Increase mud weight by an amount equal to 300 psi. d. By using the spm versus pump pressure equation the spm for 1,500 psi would be 34 spm. Therefore you bring pump up to 34 spm and adjust choke to obtain 1,500 psi drill pipe pressure. 21. During the second circulation of the Driller‟s method you hold drill pipe pressure constant until kill mud is at the bit. What would happen to bottom hole pressure ? a. Increase b. Decrease c. Stay the same 22. During the first circulation of the Driller‟s method you decided to hold casing pressure constant. What would happen to bottom hole pressure ? a. Increase b. Decrease c. Stay the same 23. During the second circulation of the Driller‟s method you decide to hold casing pressure constant until kill mud is at the bit. What would happen to bottom hole pressure ? a. Increase b. Decrease c. Stay the same
WELL CONTROL
24. Below is a list of problems. Match the cause to the problem. PROBLEM
CAUSE
a. Both gauges falling b. Both gauges rising c. D.P. gauges rising d. D.P. gauge falling
1. Choke plugging 2. Bit plugging 3. Choke washout 4. Nozzle / pipe washout
a. matches _____________________________ b. matches _____________________________ c. matches _____________________________ d. matches _____________________________
25. Which of the following pressures do not increase with gas migration ? a. b. c. d.
Bottom hole pressure Casing shoe pressure Shut in casing pressure Gas bubble pressure
WELL CONTROL
25. The following graphical diagrams show the approximate changes in pressure at certain points in the well during the Wait and Weight method. a. b. c. d.
Surface casing pressure Casing shoe pressure Bottom hole pressure Drill pipe pressure
NOTE / Pressure reading are not drawn to scale.
Answer:
Answer:
Answer:
WELL CONTROL
Answer;
WELL CONTROL
EXERCISE # 11 Well Data: Measured depth: TVD: Hole size: Air gap: Water depth: Drill collars 6 ½:
15,500 ft 15,000 ft 8½“ 70 ft 1,000 ft 1,000 ft Capacities:
Drill pipe capacity: Drill pipe metal displacement: Drill pipe closed end displacement: HWDP (1000 ft) Drill collar capacity: Choke line (1100 ft): Marine riser:
0.01776 bbl/ft 0.00650 bbl/ft 0.02426 bbl/ft 0.0088 bbl/ft 0.00768 bbl/ft 0.006 bbl/ft 0.39 bbl/ft
Annular capacities: Open hole / drill collar: Open hole / drill pipe: Casing / drill pipe:
0.0292 bbl/ft 0.0459 bbl/ft 0.0505 bbl/ft Pre-recorded data:
Current mud weight: Casing 9 5/8 – 47 ppf set at (MD/TVD): Fracture gradient at shoe: SCR @ 40 SPM ( riser) SCR @ 40 SPM ( choke line) Pump output: Surface lines:
16.0 ppg 9,000 ft 0.91 psi/ft 500 psi 750 psi 0.119 bbl/stk 17 bbls Kick data:
SIDPP: SICP: Pit gain:
100 psi 350 psi 10 bbls
WELL CONTROL
1. What is the MAASP? a. b. c. d.
402 psi 502 psi 602 psi 702 psi
2. What is the MAMW? a. b. c. d.
16.5 ppg 17.5 ppg 18.5 ppg 19.5 ppg
3. How many strokes does it take to pump from surface to bit? a. b. c. d.
1954 strokes 2054 strokes 2154 strokes 2254 strokes
4. How many strokes does it take to pump from bit to shoe? a. b. c. d.
2367 strokes 1384 strokes 2732 strokes 1199 strokes
5. How many strokes does it take to complete one circulation through the choke line? a. b. c. d.
7940 strokes 5234 strokes 9876 strokes 3576 strokes
6. How many strokes are required to displace the riser? a. b. c. d.
4382 strokes 6523 strokes 1363 strokes 3.506strokes
7. What kill mud weight is required? a. b. c. d.
16.13 ppg 17.13 ppg 18.13 ppg 19.13 ppg
WELL CONTROL
8. What is the ICP? a. b. c. d.
400 psi 500 psi 600 psi 700 psi
9. What is the FCP? a. b. c. d.
504 psi 604 psi 306 psi 806 psi
10. What is the MAASP after killing the well? a. b. c. d.
456 psi 756 psi 641 psi 985 psi
11. What is the initial dynamic pressure? a. b. c. d.
50 psi 100 psi 150 psi 200 psi
12. What informations are essential to calculate the fracture pressure of a leak off test? a. b. c. d. e. f. g. h. i.
The capacity of the drill string The TVD of the casing shoe The presence of a float in the string The pore pressure of the formation being tested The mud density The TVD of the well The Annular pressure losses The MD of the casing The accurate hole capacity
WELL CONTROL
EXERCISE # 14 Use the Well Data to answer the questions. WELL DATA Well Depth Kick Off Point End Of Build Bit size Drill Pipe Heviwate Drill Collars Casing
Choke Line Riser Formation strength test Mud weight in use Surface Volume Pumps
7,500 ft TVD 12,000 ft MD 4,000 TVD / 4,000 MD 5,500 TVD / 7,000 MD 8.5” 5” OD. 19.5 lbs/ft Capacity = 0.01776 bbls/ft 5” OD x 3” ID x 1500 ft Capacity = .009 bbls/ft 61/2” x 213/16” x 700 ft Capacity = 0.008 bbls/ft 95/8”, 47 lb/ft. P110 8.681” ID 100% Internal yield = 10,900 psi Set at 5,050 ft TVD / 5,500 MD 1,000 ft – Capacity: .008 bbls/ft 1,000 ft – Riser / DP: .335 bbls/ft 1,800 psi w/ 11.5 ppg 12.5 ppg. 1,000 bbls National triplex 12-P-160 With 51/2” Liners Capacity = 0.088 bbls/stk PUMP PRESSURE
Slow Pump Rate Riser CLFL
700 psi at 40 spm 250 psi at 40 spm
ANNULAR VOLUMES Drill pipe/HW - Casing Drill pipe/HW - Open hole Drill collars - Open hole
= 0.0505 bbls/ft = 0.0459 bbls/ft = 0.03 bbls/ft
WELL CONTROL DATA SIDPP SICP GAIN
= 800 psi = 900 psi = 20 bbls
You are recommended to complete a kick sheet to answer the following questions:
WELL CONTROL
1. What is the Initial Circulating Pressure at 40 spm?
2. What is the Final Circulating Pressure?
3. What Kill Mud weight is required?
4. What is the Maximum allowable fluid density?
5. What is the MAASP with the current mud weight?
6. How many strokes are required to pump kill mud from surface to KOP?
7. What is the pressure reduction per 100 strokes surface to KOP?
8. How many strokes are required to pump kill mud from KOP to EOB?
WELL CONTROL
9. What is the pressure reduction per 100 strokes KOP to EOB?
10. How many strokes are required to pump kill mud from EOB to bit?
11. What is the pressure reduction per 100 strokes EOB to bit?
12. When kill mud reaches the KOP, what is the circulating pressure?
13. When kill mud reaches the EOB, what is the circulating pressure?
14. If the well had to be shut in when kill mud reaches the KOP, what would be the SIDPP?
15. What is the drill string volume?
16. What is the total strokes to pump kill kud to the bit?
WELL CONTROL
17. What is the marine riser – DP capacity?
18. Approximately, how many strokes are required to fill the choke line?
19. What should be the approximate pressure on the casing gauges when the pump reaches 40 SPM?
20. What is the MAASP with the current mud weight (dynamic conditions)?
WELL CONTROL
EXERCISE # 15 Use the Well Data to answer the questions. WELL DATA Well Depth Kick Off Point End Of Build Bit size Drill Pipe Drill Collars Casing
Choke Line Riser Formation strength test Mud weight in use Surface Volume Pumps
10,000 ft TVD 14 ,000 ft MD 3,500 TVD / 3,500 MD 4,000 TVD / 4,500 MD 8.5” 5” OD. 19.5 lbs/ft Capacity = 0.01776 bbls/ft 61/2” x 213/16” x 500 ft Capacity = 0.007 bbls/ft 95/8”, 47 lb/ft. P110 8.681” ID 100% Internal yield = 10,900 psi Set at 6,000 ft TVD / 7,000 MD 580 ft – Capacity: .008 bbls/ft 580 ft – Riser / DP: .335 bbls/ft 1,500 psi w/ 9.8 ppg 10 ppg. 274 bbls National triplex 12-P-160 With 6” Liners Capacity = 0.099 bbls/stk PUMP PRESSURE
Slow Pump Rate Riser CLFL
520 psi at 40 spm 100 psi at 40 spm
ANNULAR VOLUMES Drill pipe/HW - Casing Drill pipe/HW - Open hole Drill collars - Open hole
= 0.0489 bbls/ft = 0.0459 bbls/ft = 0.03 bbls/ft WELL CONTROL DATA
SIDPP SICP GAIN
= 500 psi = 650 psi = 11 bbls
You are recommended to complete a kick sheet to answer the following questions:
WELL CONTROL
1. What is the Initial Circulating Pressure at 40 spm?
2. What is the Final Circulating Pressure?
3. What Kill Mud weight is required?
4. What is the Maximum allowable fluid density?
5. What is the MAASP with the current mud weight?
6. How many strokes are required to pump kill mud from surface to KOP?
7. What is the pressure reduction per 100 strokes surface to KOP?
8. How many strokes are required to pump kill mud from KOP to EOB?
WELL CONTROL
9. What is the pressure reduction per 100 strokes KOP to EOB?
10. How many strokes are required to pump kill mud from EOB to bit?
11. What is the pressure reduction per 100 strokes EOB to bit?
12. When kill mud reaches the KOP, what is the circulating pressure?
13. When kill mud reaches the EOB, what is the circulating pressure?
14. If the well had to be shut in when kill mud reaches the KOP, what would be the SIDPP?
15. What is the drill string volume?
16. What is the total strokes to pump kill kud to the bit?
17. What is the marine riser – DP capacity?
WELL CONTROL
18. Approximately, how many strokes are required to fill the choke line?
19. What should be the approximate pressure on the casing gauges when the pump reaches 40 SPM?
20. What is the MAASP with the current mud weight (dynamic conditions)?
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