Rev.5 – September 2004
1-2
PRINCIPLES AND PROCEDURES
CONTENTS Section 1
Causes of Kicks
Section 2
Warning Signs and Indicators
Section 3
Shut in Procedures
Section 4
Data to Collect
Section 5
Fractures and MAASP
Section 6
Kill Methods
Section 7
Kill Problems and Bad practices
Section 8
Kill Sheet and Gauge Problems
1-3
1-4
Section 1 Causes of Kicks
1-5
1-6
1.
What is the PRIMARY means of preventing kicks? a.
Closing in the well with the BOP’s.
b.
Monitoring pit levels and flow rate to recognise a kick.
c.
Taking regular slow circulating rate pressures.
d.
The use of mud hydrostatic to balance fluid pressure in the formation.
2. What is the PRIMARY means means used to prevent formation formation fluid entering entering the well well bore? a.
The BOP stack.
b.
The Annular Preventer.
c.
Hydrostatic pressure of the mud.
d.
Monitoring trips.
3. What is the correct definition definition of ‘Primary ‘Primary Well Control’ during during normal normal drilling operations? operations? a.
Preventing the flow of formation fluid into the well bore by using BOP equipment when the hydrostatic pressure in the well bore does not balance or exceed the formation pressure.
b.
Preventing the flow of formation fluid into the well bore by keeping the dynamic pressure loss in the annulus equal to or greater than formation pressure.
c.
Preventing a kick by maintaining drilling mud hydrostatic pressure equal to or greater than formation pressure.
d.
Preventing the flow of formation fluid into the well bore by maintaining maintaining the sum of drilling mud hydrostatic pressure and dynamic pressure loss in the annulus equal to or greater than formation pressure.
4. A well 9,850 feet (TVD) is filled with with 9.2 ppg ppg brine. brine. The plan is to run in the hole to 6,200 feet TVD (6,600 feet measured depth) and displace with drill water (8.4 ppg). What will the hydrostatic pressure be at 9,850 feet when the drill water has been circulated back to the surface? a.
4,815 psi
b.
4,303 psi.
c.
4,454 psi.
d.
5,164 psi.
5. In a well with gas cut cut mud, when is the reduction in bottom bottom hole pressure pressure greatest? a.
When the gas is at the casing shoe.
b.
When the gas is at bottom.
c.
When the gas reaches the surface.
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6. Gas cut mud may reduce reduce the bottom hole pressure enough enough to cause a well well kick; when is is bottom hole pressure reduced most? a.
When the gas is at the bottom.
b.
When the gas is near the surface.
c.
When the gas is halfway up the well bore.
7. Calculate the reduction reduction in bottom hole pressure when circulating circulating gas cut mud in in the following well: Vertical depth
= 7,000 feet
Surface to 800 feet
mud weight = 11.2 ppg
800 – 2,100 feet
mud weight = 11.8 ppg
2,100 feet to bottom
mud weight = 12.5 ppg
Original mud weight
= 12.5 ppg
a.
76 psi.
b.
101 psi.
c.
139 psi.
8. How will bottom hole pressure be affected by gas gas cut mud whilst drilling? drilling? a.
There will be a small drop.
b.
There will be a large drop.
c.
There will be no change.
9. Which of the following would be the immediate immediate effect of swabbing? swabbing? a.
Reduction in bottom hole pressure.
b.
A kick.
c.
Losses.
d.
Increase in bottom hole pressure.
10. Which of the following are likely t o increase the chance of swabbing? (THREE ANSWERS) a.
Pulling through tight hole with the pump off.
b.
Pulling pipe too quickly.
c.
Pulling pipe too slowly.
d.
Pumping out of the hole.
e.
Pulling through tight hole with the pump on.
f.
High mud viscosity.
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11. Which of the following increase the risk of swabbing? (THREE ANSWERS) a.
Low permeability formation.
b.
Viscous mud.
c.
Spiral drill collars in the BHA.
d.
Tripping out too fast.
e.
Balled up stabilisers.
12. Overpull while tripping out is a stuck pipe warning sign. What well control problem may be associated with overpull? a.
Swabbing.
b.
Losses
c.
Hydrogen Sulphide gas.
d.
Surging.
13. Which of the following increase surge pressures when running in the hole. (TWO ANSWERS) a.
Small annular clearance.
b.
Large bit nozzles.
c.
Running-in slowly.
d.
High gel strength mud.
e.
Large annular clearance.
f.
Low gel strength mud.
14. When pulling out of the hole from the top of the reservoir at 10,000 feet swab pressures are calculated to be 150psi. Mud Weight
= 10.2 ppg.
10.2 X .052 X 10000 = 5304
Formation Pressure
= 5200 psi.
104 < 150
Will the well flow? a.
No.
b.
Yes.
15. WELL DATA Drill Pipe Capacity
0.01776 bbls/ft
Drill Pipe Metal Displacement Displacement
0.0083 bbls/ft
Average Stand Length Length
93 feet
Calculate the mud required to fill the hole per stand when pulled ‘dry’. ………0.77………. ………. ………0.77
bbls
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16. WELL DATA Drill Pipe Capacity
0.01776 bbls/ft
Drill Pipe Metal Displacement Displacement
0.0083 bbls/ft
Average Stand Length Length
93 feet
Calculate the mud required to fill the hole per stand when pulled ‘wet’. ………2.42…………. …………. ………2.42
bbls
17. A vertical well has been drilled to a depth of 7,480 feet. Casing shoe depth
3,800 feet
Mud weight
12 ppg
4667
Pore pressure gradient (7,480 feet)
0.6 psi/ft
4488
Open hole capacity
0.1458 bbls/ft
Casing capacity
0.1571 bbls/ft
Drill pipe metal displaceme displacement nt
0.008 bbls/ft
How many complete stands can be pulled dry before the well flows? (Assume one stand equals 93 feet)
Overbalance = 179
………57…………. …………. stands. ………57
F-23
18. Two stands of drill collars are pulled from the well (dry) Drill collar capacity
0.0073 bbls/ft
Drill collar metal displacement displacement
0.0370 bbls/ft
How many barrels of drilling mud should be pumped into the well? (Assume one stand equals 90 feet) a.
5.5 bbls.
b.
6.6 bbls.
c.
1.3 bbls.
d.
7.9 bbls.
19. A vertical well has been drilled to a depth of 9,400 feet Casing shoe depth
5,100 ft
Mud weight
12 ppg
5865
Pore pressure gradient (9,400 feet)
0.6 psi/ft
5640
Open hole capacity
0.146 bbls/ft
Casing capacity
0.157 bbls/ft
Drill pipe metal displacement displacement
0.008 bbls/ft
How many complete stands can be pulled dry before the well flows? (Assume one stand equals 93 feet) ………72…………. …………. ………72
Overbalance = 225
stands
F-23 1-4
20. Which of the following causes of well kicks is totally avoidable and due to a lack of alertness by the Driller? a.
Lost circulation.
b.
Gas cut mud.
c.
Not keeping the hole full.
d.
Abnormal pressures
21. On pulling out of the well from 10,000 feet, the first 930 f eet of 5 inch drill pipe is pulled wet without filling the hole (no mud returning to the well). WELL DATA Casing capacity
0.074 bbls/ft
Drill pipe capacity
0.0178 bbls/ft
Drill pipe steel displacement displacement
0.0077 bbls/ft
Mud Weight
11.4 ppg
What is the drop in bottom hole pressure a.
84 psi.
b.
290 psi.
c.
220 psi.
d.
140 psi.
F-21
22. On a trip out of the hole the hole fill pump was stopped and the complete BHA was pulled dry. Hole size
81/2 inch
Length of BHA
600 feet
Internal capacity of BHA
0.006 bbls/ft
Steel displacement displacement of BHA
0.03 bbls/ft
Internal capacity of casing
0.072 bbls/ft
Capacity between BHA and casing
0.035 bbls/ft
Mud weight
12 ppg
Calculate the reduction in bottom hole pressure? a.
250 psi.
b.
208 psi.
c.
156 psi.
d.
127 psi.
F-22 X 12 X 0.052
1-5
23. (S) Whilst (S) Whilst running 9-5/8 inch casing, 15 joints are run without filling the string. Mud weight
10.8 ppg
Casing capacity
0.0719 bbls/ft
Annular capacity capacity
0.0558 bbls/ft
Casing joint
40 feet
If the float valve was to fail at this point, what would be the reduction in bottom hole pressure? ………190…………. …………. ………190
psi.
F-28
24. A 20 bbl heavy slug with a weight of 13 ppg is pumped before pulling out of the hole. TVD = 9,750 feet. The level in the pipe falls by 180 feet. What is the change in bottom hole pressure if the original mud weight was 10.7 ppg? a.
1,200 psi
b.
100 psi.
c.
0 psi.
d.
180 psi.
25. Before pulling out of the hole a 20 bbl heavy slug is pumped and followed by 15 bbls of regular mud. WELL DATA Depth of hole (RKB)
10,400 feet
Drilling mud weight
11.0 ppg
Heavy slug weight
13.0 ppg
Drill pipe capacity
0.01776 bbl/ft
Surface line volume
10 bbls
How far will the mud level in the string drop when the well has equalised? a.
62 feet.
b.
180 feet.
c.
205 feet.
d.
307 feet.
F-27
26. With the pumps running running continuously continuously a heavy mud pill is circulated. circulated. When will bottom hole pressure start to increase (ignore dynamic pressure losses in the well)? a. Once all all the pill is is in the annulus. annulus. b. Once the pill starts to be displaced into the annulus. c. As soon as the pill is pumped into the drillstring. d. Once all the pill is inside inside the drillstring drillstring and and is about about to exit the bit. bit.
1-6
27. Before a trip out of the well, a slug was pumped and chased by mud with returns to the pit. The pumps pumps were stopped. The trip tank was lined up on the well. The top-drive top-drive was then disconnected and the slug allowed to fall. WELL DATA Well depth
8,000 feet
Drill pipe internal capacity
0.0176 bbls/ft
Mud weight
9.8 ppg
Slug weight
11.3 ppg
Slug volume in the string
20 bbls
Calculate the mud volume increase in the trip tank. a.
3 bbls.
F-26
b.
15 bbls.
c.
20 bbls.
28. Prior to starting a trip out of the well, a heavy slug was pumped. WELL DATA Drill pipe capacity
0.0177 bbls/ft
Annulus capacity capacity DP/Casing DP/Casing
0.0514 bbls/ft
Mud weight
10.8 ppg
Slug weight
13.3 ppg
Slug volume inside the drill pipe
15 bbls
Well depth
10,200 feet
How far will the mud level drop when the well has equalised? a.
197 feet.
b.
247 feet.
c.
597 feet.
d.
847 feet.
F-27
29. During normal drilling operations operations 30 bbls of light mud is pumped into the string followed by original mud. The Driller shuts dow down n with the light mud still inside the drill drill pipe and observes the well. WELL DATA Well depth (TVD)
9,000 feet
Drill pipe capacity
0.0176 bbls/ft
Original mud weight
12 ppg
Light mud weight
10 ppg
Which of the following is correct? a.
Bottom hole pressure will remain the same, but a back pressure of 177 177 psi will be seen on the drill pipe pressure gauge. (12-10) x .052 x (30/.0176)
b.
Bottom hole pressure will increase 177 psi.
c.
Bottom hole pressure will drop by 177 psi. 1-7
30. With the pumps running running continuously continuously a light mud pill is circulated. circulated. When will bottom hole pressure start to decrease (ignore dynamic pressure losses in the well)? a. As soon as the pill starts starts to be pumped pumped down down the drillstring. drillstring. b. Once all the pill is pumped pumped inside inside the drill string and is about to exit the bit. c. Once the pill starts to be displaced into the annulus. d. Once all all the pill is is in the annulus. annulus.
31. Does a kick always occur after a total loss of circulation? a. No, it depends depends on the mud level in the annulus annulus and the formation pressure. b. Yes, losses losses will always occur occur above any potential potential kick zone. c. No, it depends on the reduction in drill string weight.
32. While drilling ahead through a faulted formation, the flow meter drops from 60% to 35%. What is the most likely cause of this? a. There is a washout in the the string. string. b. Partial lost circulation has occurred. c. A kick has been swabbed in. d. Total lost circulation has occurred.
33. (S) Whilst (S) Whilst drilling ahead, ahead, partial losses are measure at 10 bbls/hour. bbls/hour. A total power loss occurs. Annular capacity capacity
0.1512 bbls/ft (with (with pipe).
Mud weight
10.2 ppg.
If the hole cannot be filled, what will be the reduction in bottom hole pressure after 4 hours? a. 250 psi. b. 560 psi. c. 175 psi. d. 140 psi.
34. When drilling with water based mud, a complete loss of returns occurs and no mud is visible when looking down the hole. What is the first action to take? a. Pump lost circulation material immediately. b. Pump a heavy heavy slug slug into into the annulus. c. Fill the annulus with water and record the volume added. d. Pump a cement plug plug into the annulus annulus using the kill line.
1-8
35. The flow sensor shows a total loss of returns and the mud level cannot be seen in the annulus. What immediate action should be taken? a. Shut the well in and pump pump lost circulation circulation material. b. Fill the annulus annulus with water (or lightest lightest mud available) available) and and record volume. volume. c. Pump at at reduced rate adding adding lost lost circulation circulation material. material. d. Continue drilling ahead cautiously.
36. (S) (S) Severe Severe losses occurred while drilling. The pumps were stopped and the mud in the well could not not be seen. The well was then then filled to the top with with water. Mud weight
12 ppg
Sea water weight
8.6 ppg
Equivalent height of water column
150 ft of annulus
What is the reduction in bottom hole pressure with the 150 ft of water? a. 94 psi. b. 26 psi. c. 67 psi. d. 30 psi. 37. At 171/2 inch surface hole is being drilled at 3750 feet The formation fluid pressure is 2000 psi at this depth. Is the formation fluid pressure? a. Above normal. b. Below normal. c. Normal.
38. What is meant by abnormal pressure? a. The excess excess pressure due to circulating mud at high rates. rates. b. The excess pressure that that needs to be be applied to cause ‘leak-off’. ‘leak-off’. c. Heavy weight mud used to give an overbalance. d. The formation fluid pressure pressure that exceeds exceeds formation water water hydrostatic hydrostatic pressure.
39. A formation is over-pressured by an artesian effect. What has created the over-pressure? a. Compaction of the formation by by the overburden overburden pressure. b. A formation water source located at a higher level than the rig floor. floor. c. The difference difference in density density between between oil and formation formation fluid. fluid.
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40. What is the most common cause of abnormally high formation pressures worldwide? a. Under-compa Under-compacted cted shales. b. Carbonate layers. c. Depleted sands.
41. When drilling top-hole with a risk of shallow gas, which of the following f ollowing statements are good practice? (TWO ANSWERS) a. Regularly pump fresh water pill to clean cuttings from from hole. b. Drill a pilot hole hole at a controlled controlled rate. rate. c. Drill at a high rate of penetration penetration and keep keep mud viscosity viscosity as high high as possible. possible. d. Use heavy weight mud to create maximum overbalance. e. Pump out of the hole on trips.
42. Is it true that shallow gas kicks are easier to handle than those taken t aken when drilling deeper? a. Yes. b. No.
43. Which of the following statements are good operating practices when drilling TOPHOLE formations where there is a risk of shallow gas? (TWO ANSWERS) a. Maintain high high rate of penetration penetration and and keep mud viscosity as high as as possible. b. Use a heavy weight weight mud to create maximum overbalance. overbalance. c. Pump out of the the hole hole on trips. d. Use oil-based mud. e. Drill a pilot hole hole at a controlled controlled rate. rate.
44. Formation strengths are generally weak when drilling top hole and total losses may occur. How can the risk of total losses be reduced when drilling top hole? a. By pumping pumping slowly to reduce the drillstring drillstring pressure pressure loss. b. Keeping a high overbalance. overbalance. c. By controlling controlling penetration penetration rate to prevent prevent loading loading the annulus annulus with cuttings. cuttings.
1 - 10
45. What is the SECONDARY means used to control formation fluid pressure. a. The Blow Out Preventers. b. Mud Viscosity c. Mud hydrostatic pressure. d. Cement Plugs
46. What is meant meant by Abnormal Abnormal Pressure. Pressure. a. High overbalance with heavy mud. b. Formation fluid fluid pressure that is greater greater than normal normal formation water hydrostatic hydrostatic pressure. c. Pressure required to exceed MAASP. d. The excess excess pressure pressure due due to Annular Pressure loss.
47. Which of the following is good operating practice in TOP HOLE? (TWO ANSWERS). a. Maintain a high high safety safety margin margin (overbalance) (overbalance).. b. Pump out of the hole on trips. c. Drill a pilot hole. d. Drill section as fast as as possible. possible. e. Keep mud viscosity viscosit y high then pump fresh water pills to clean hole.
48. Which of the following are likely t o increase the chance of swabbing? (THREE ANSWERS). a. Pulling through tight hole hole with pump off. b. Pulling through tight hole hole with pump on. c. Pumping out of the hole. d. Pulling pipe too quickly. e. Maintaining high mud viscosity. f.
Pulling pipe slowly.
49. Which of the following drilling practices should be considered when connection gas is noticed? (TWO ANSWERS). a. Increase mud viscosity. b. Keep connection time to a minimum. c. Reduce mud weight by a small amount. d. Control ROP so that that only one slug of connection gas gas is in the hole at any one time. e. Change the bit.
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50. ROP remains steady. Cuttings volume at Shaker is increasing, increasing, causing overloading. overloading. Which of the following would be the safest course of action? a. By-pass the Shakers. b. Check for flow, flow, if negative, negative, circulate bottoms up at at a reduced rate so Shakers Shakers can handle cuttings cuttings volume. Monitor pit levels levels closely. c. Increase pump rate to improve hole cleaning. d. Reduce pump rate until Shakers Shakers can handle volume of cuttings.
51. A complete loss of returns occurs, there is no mud visible when looking down the hole. Which of the following is the first action to t ake? a. Pump a cement plug below the loss zone. b. Fill the Annulus Annulus with base fluid at the surface and record the volume. c. Pump LCM as soon as possible. d. Pump a heavy slug slug on top of the loss loss zone.
52. Using the following data: Drill pipe capacity
:
0.0178 bbls/ft
Drill pipe metal displacement displacement
:
0.008 bbls/ft
Stand length
:
92 ft
Calculate: a.
Mud required to fill the hole per stand when pulled ‘dry’ ………0.736……….bbls ……….bbls ………0.736
b.
Mud required to fill the hole per stand when pulled ‘wet’ ………2.37……….bbls ……….bbls ………2.37
53. If the mud is gas cut, when will the gas cause the greatest greatest reduction in bottom hole hole pressure. a. When the the gas is at bottom of the hole. b. When gas reaches the surface. c. When the gas gas is at the Casing Shoe.
54. Select the factors that can cause swabbing. (THREE ANSWERS). a. High viscosity mud. b. Keeping the hole full. c. Pumping out of the hole. d. Balled up bit or stabilisers. e. Pulling out of of hole hole too too fast. fast.
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55. Do kicks always occur following total losses. a. Yes, kicks will always always occur occur in this situation. situation. b. No, itit depends depends on on the mud viscosity. c. No, it depends on how much the mud level drops in the Annulus.
56. What is the most common cause of abnormal formation pressures. a. Trapped water in under-comp under-compacted acted shales/claystone shales/claystones. s. b. Thick layers of Limestone. c. Depleted reservoir sands. d. Lost circulation zones.
57. Which of the following statements are good practice when drilling TOP HOLE formations? (TWO ANSWERS). a. Drill a pilot hole. b. Use a high density mud to maintain maximum overbalance. c. Drill top hole hole sections with Oil-based muds. d. Control the rate of penetration. e. Maintain a high high rate of penetration. penetration.
58. If there are total losses and the mud cannot be seen in the Annulus, what action should should be taken? a. Increase pump rate by 30% and continue drilling. b. Slow down the pump and start mixing LCM. c. Try to fill the Annulus with with water (or (or lightest fluid fluid available) available) and record record volume pumped. d. Close the well in.
59. Swabbing is due to: a. An increase increase in bottom hole hole pressure while tripping. tripping. b. A reduction reduction in bottom hole hole pressure pressure while tripping. tripping. c. A kick. d. Lost circulation.
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60. When tripping: Slug Volume
=
20 bbls
Slug Weight
=
12 ppg
Mud Weight
=
10 ppg
If slug causes mud level in the pipe to drop by 200 ft, what will happen to bottom hole pressure? a. Decreases by 21 psi b. Increases by 1000 psi c. No change to bottom hole pressure d. Increases by 125 psi
61. During a trip, the Driller Driller decides that the well is swabbing. swabbing. A flow check is negative. What should the Driller do next? a. Because the well well is not flowing, flowing, continue pulling pulling pipe from the the hole. b. Shut the well well in and check for pressures. pressures. c. Run to bottom and and circulate bottoms up. up. d. Pull 5 stands and and carry out another another flow check.
62. Which of the following statements are true for drilling TOP HOLE? a. Reduce SPM to prevent breaking down formation. formation. b. Control ROP to prevent too many cuttings in the hole. hole. c. Maintain high high overbalance overbalance to prevent prevent shallow gas kick.
63. How will the drilling of a gas bearing formation affect Bottom Hole Pressure? a. Bottom Hole Hole Pressure will fall by a large amount. amount. b. Drilled gas in in the mud, as a result result of drilling through through a gas bearing bearing formation, will will normally cause a small reduction in the bottom hole pressure. c. There will will be no change change in the the bottom hole pressure. pressure.
64. If total losses occurred while drilling with Water based mud, what would you do? a. Drill blind. b. Stop drilling, drilling, shut the well in and see what what happens. happens. c. Stop drilling drilling and try to fill the hole up with water.
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65. If a light mud pill is circulated around the well, when will the bottom hole pressure start to decrease? a. Once all all the pill is is in the Annulus. Annulus. b. When all the pill has been been pumped pumped into the drillstring. drillstring. c. When the the pill starts to be pumped pumped into into the drillstring. d. When the pill starts to be pumped pumped into into the Annulus Annulus
66. When tripping in the hole, hole, mud returns to the the trip tank are less less than calculated. calculated. Once back drilling, the return flow is less less than expected. What is the most likely cause of this? a. Swabbing. b. A kick. c. Total losses. d. Partial losses.
67. (S) (S) In In a clean well:Vertical depth
:
8000 ft
Mud density
:
11.50 ppg
Due to gas cutting the mud in the Annulus has the following densities:Surface to 800 ft
:
mud density of 10.20 ppg
800-2000 ft
:
mud density of 11.0 ppg
2000 ft to bottom
:
mud density of 11.50 ppg
Calculate the reduction in bottom hole pressure due to the gas cut mud
68.
a.
20 psi
b.
70 psi
c.
85 psi
d.
108 psi
Measured Depth
=
9800 ft
Mud Weight
=
9.4 ppg
The mud from 3800 ft to surface is to be displaced with 8.5 ppg water. What will be the mud hydrostatic after displacement of the water. a. 1680 psi b. 2933 psi c. 4612 psi d. 4815 psi
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69. Five stands of drill collars are pulled from the well (dry). Drill collar capacity
:
0.0073 bbls/ft
Drill collar metal displacement displacement
:
0.0370 bbls/ft
How much fluid would be pumped into the well to maintain fluid level (one stand = 90’). a.
2
bbls
b.
8.20
bbls
c.
16.65 bbls
d.
12.23 bbls
70. If the BHA is pulled (dry) without filling the hole, calculate the reduction in bottom hole pressure? BHA length
:
580 ft
BHA capacity
:
0.0061 bbls/ft
BHA Steel Displacement Displacement
:
0.032 bbls/ft
:
0.0322 bbls/ft
Casing Capacity
:
0.0719 bbls/ft
Mud density
:
11 ppg
Annular Capacity Capacity BHA to 12
a. 148 psi
¼inch
Bore
F-22 + F-1
b. 188 psi c. 258 psi d. 100 psi
71. (S) What (S) What is the bottom hole hydrostatic pressure reduction reduction when pulling 600 ft of 5” drill pipe wet without filling the hole (no mud returning to the well). Well Data: Casing capacity
:
0.1522 bbls/ft
Drill pipe capacity
:
0.0178 bbls/ft
Drill pipe steel displacement displacement
:
0.0076 bbls/ft
Mud density
:
9.8 ppg
a. 51 psi b. 61 psi
F-21
Closed End = 0.0178 + 0.0076 = 0.0254
c. 81 psi d. 101 psi
1 - 16
72. Mud losses are 20 bbls/hour. Annular Capacity Capacity
=
0.1252 bbls/ft
Mud Density
=
12 ppg
What would be the effect on bottom hole pressure if the hole was not filled for a period of 2 hours? a. decrease by 320 psi b. decrease by 200 psi c. decrease by 150 psi d. decrease by 470 psi
73. A well has been drilled to a depth of 10100 ft: Casing Shoe depth
:
7210 ft
Mud density
:
12.0 ppg
6302
Pore pressure gradient
:
0.61 psi/ft
6161
Casing capacity
:
0.156 bbls/ft
Open hole capacity
:
0.146 bbls/ft
Drill pipe metal displacem displacement ent
:
0.008 bbls/ft
Average Stand Length Length
:
93 ft
Calculate number number of stands that can be pulled (dry) before the well starts to flow. 45 stands
F- 23
(Overbalance (Overbalanc e = 141.4)
74. (S) Pressure recorders recorders located below the drill stem stem test tools show that swab pressure when pulling a stand was 250 psi. Drilling fluid density in the hole is 10 ppg. Top of reservoir is at 9500 ft. If the well does not flow when the pipe is static, what would the reservoir pressure have to be to allow it to flow at this swab pressure. a.
3800 psi.
b.
5800 psi.
c.
4690 psi.
d.
4940 psi.
(F-1) - 250
1 - 17
75. (S) Gas/Water Gas/Water Contact in a Reservoir = 5400 ft Top of Reservoir is at 4000 ft. Gas Gradient = 0.1 psi/ft. Formation Water Gradient = 0.465 psi/ft Calculate pressure at top of the reservoir? a.
2511 psi
b.
140 psi
c.
2371 psi
d.
2231 psi
76. (s reservoir, the highest point of the reservoir usually usually has the highest (s)) In a trapped gas reservoir, pressure. Why is this? a. Reservoir Gas Gas is less dense than formation water. water. b. Artesian effect. c. Highest point point of the reservoir reservoir is more more compacted. compacted.
77. (s)13 (s) 13 3/8” string of casing is run into the hole with with conventional float. float. The Driller did not fill the casing for fourteen fourteen 40 ft joints. If the float were to fail at this point, and mud mud Utubes up inside the casing, calculate the effect on bottom hole pressure. Data: Casing capacity
=
0.152 bbls/ft
Annular capacity capacity
=
0.1238 bbls/ft
Mud Weight
=
12.6 ppg
a.
BHP decreases by 298 psi.
b.
BHP decreases by 102 psi
c.
BHP decreases by 202 psi
d.
BHP decreases by 83 psi
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1 - 20
Section 2 Warning Signs and Indicators
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2-1
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2-2
1. Which of the following following are indicators indicators that a well might be going under-balanc under-balanced? ed? (TWO ANSWERS) a. Increase in the mud weight returning at surface. surface. b. Increasing background gas levels. c.
A big increase in the pump pressure.
d. A change change in in the size and and shape of the cuttings. e. A reduction in the drilling rate.
2. If WOB, RPM, and SPM are held held constant, which which of the following may be a warning of abnormal pressure? (THREE ANSWERS) a.
Change of cuttings cuttings shape and size on the shakers.
b.
Increase in pump pressure.
c.
Increase in penetration rate.
d.
Connection gas.
e.
Increase in Shale Density.
f.
Increased trip tank level.
3. Drilling ahead ahead at constant constant rate of penetration (ROP). Shale Shakers cannot cannot handle amount of cuttings returning in the mud. What would be the safest course of action? a. Slow down the mud pump until the the shakers can handle handle the amount amount of cuttings in the returns. b. Check for flow flow – if none, none, circulate bottoms up at a reduced reduced rate so that that shakers can can handle cuttings volume, flow-check periodically during circulation. c. Check for flow – if none continue drilling at same ROP. d. Check for flow flow – if none, none, then continue continue at the same ROP. Allow Allow half of of the mud returns to bypass the shakers.
4.
Which of the following following is good practice when connection connection gas is observed? (TWO ANSWERS) a.
Control drilling drilling rate rate so that that only one slug of connection connection gas is in the the hole at any one one time.
b.
Pull out the hole to change the bit.
c.
Raise the mud viscosity.
d.
Reduce mud viscosity to minimise swabbing during trips.
e.
Minimise the time time during during a connection when the pumps pumps are switched switched off.
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2-3
5. If mud flows from the well well with the pump off, but there is no gain gain when the pump pump is running, what is the problem? a.
Low mud weight inside the drill string.
b.
Mud hydrostatic pressure is greater greater than formation pressure.
c.
Pump pressure is greater than mud hydrostatic pressure.
d.
Annular pressure loss is giving an overbalance overbalance against formation pressures.
6. While pulling pulling out of the hole the mud required to fill the hole is less less than calculated. calculated. What action should be taken? a. Pump remaining stands out of of the hole. b. Flow check, check, if negative negative continue continue to pull out out of the hole. c. Shut the well well in and circulate hole clean. d. Flow check, check, if negative negative run back to bottom and and monitor returns.
7. While drilling, drilling, which of the following following situations situations make kick detection detection with a P.V.T more more difficult? a. Allowing mud to overflow overflow the shakers. shakers. b. Reducing the pit level level alarm settings settings from 10 bbls to 5 bbls. bbls. c. Keeping active mud system transfers to a minimum when drilling ahead. d. By-passing the solids control pits.
8. After pulling 15 stands stands of pipe, pipe, the well well has not taken the correct correct amount of mud. The Driller takes a flow check, which is negative. What action should be taken? a. Run or strip back to bottom bottom and circulate circulate bottoms up. up. b. Continue pulling pulling pipe from the hole because there was no flow. flow. c. Shut the well in and check check for pressures. pressures. d. Pull another another 15 stands and and flow check.
9. Whilst pulling out of the hole, the Driller Driller observes observes that the hole is taking taking less than the calculated volume. Which is the safest action to follow? a. Flow check for at least least 15 minutes. If the well is static, continue continue pulling pulling out of the hole slowly and carry out a flow check after every 15 stands pulled. b. Flow check for at least least 15 minutes. If the well is static, continue continue pulling pulling out of the hole slowly to prevent swabbing. c. Flow check. If the well is static, circulate circulate bottoms up and and observe returns returns for any swabbed fluids. fluids. If negative, continue pulling pulling out of the hole slowly to avoid any further swabbing. d. Flow check. If the well is static, run back back to bottom, whilst whilst monitoring the trip trip tank. Circulate bottoms up and and observe returns for any swabbed swabbed fluids.
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2-4
10. What action should a Driller take after a drilling break. a. Reduce weight on bit. b. Circulate bottoms up. c. Flow check. d. Reduce pump speed.
11. Which of the following is a positive indication that the well is flowing? a. Increase in torque. b. Increase in flow returns. c. Decrease in pump pressure. d. Gas cut mud.
12. Which of the following are positive indications of a kick whilst drilling? (TWO ANSWERS) a. Increase in pit volume. b. Increase in flow flow rate rate with constant SPM. c. Decrease in flow flow rate rate with constant SPM. d. Decrease in pit volume.
13. Which of the following IS NOT an indicator of a kick whilst drilling? a. Pit gain. b. Decrease in pump strokes. c. Decrease in pump pressure. d. Flow rate increase.
14. The following describes one of the differences between drilling with water based mud and oil based mud. Hydrocarbon gas is more soluble in water based mud than in oil based mud. a. False. b. True.
15. The following describes one of the differences between drilling with water based mud and oil based mud. Hydrocarbon gas remains in solution longer in oil-based mud than in water-based mud when circulating up to surface. a. True. b. False.
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2-5
16. The following describes one of the differences between drilling with water based mud and oil based mud. Gas is less soluble in water based mud than in oil based mud. a.
True.
b.
False.
17. The following describes one of the differences between drilling with water based mud and oil based mud. Gas entering the well bore whilst drilling with oil-based mud will reduce the hydrostatic pressure more than it would when drilling with water-based mud. a.
True.
b.
False.
18. The following describes one of the differences between drilling with water based mud and oil based mud. Whilst circulating out a kick, gas expansion occurs in the annulus at the same rate in oil and water-based mud. a.
True.
b.
False.
19. The following describes one of the differences between drilling with water based mud and oil based mud. Gas entering the well bore whilst drilling with water-based mud will reduce the hydrostatic pressure more than it would when drilling with oil-based mud. a.
True.
b.
False.
20. The following describes one of the differences between drilling with water based mud and oil based mud Whilst circulating out a kick, gas expansion occurs in the annulus at a different rate in oil and water-based mud. a.
True.
b.
False.
21. Which of the following causes of well kicks is totally avoidable and due to bad practice by the Driller? Driller? (Choose ONE ONE answer). answer). a.
Gas cut mud.
b.
Not keeping hole full during a trip.
c.
Abnormal formation pressure.
d.
Reduction in mud hydrostatic due to lost circulation. circulation.
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22. Which of the following could indicate that the well may be going under-balanced. (TWO ANSWERS). a.
An increase in the size and amount of cuttings.
b.
An increase in the mud density returning at Shakers.
c.
Increase in background gas levels.
d.
A gradual reduction in the drilling rate.
e.
An increase in pump pressure.
23. Which of the following is not a kick warning sign ? a.
Increase in pump pressure.
b.
Gas cut mud.
c.
Flow rate increase.
d.
Connection gas.
e.
Increase in mud temperature.
24. Overpull Overpull (drag) while tripping is a stuck pipe pipe warning sign. What problem may overpull overpull result in. a.
Surging.
b.
Swabbing.
c.
On-bottom kick.
d.
Increase in bottom hole pressure.
25. Whilst pulling out of the hole, the mud required to keep the hole full is less than calculated. What action should be taken? a.
Flow check, if negative, negative, continue to pull pull out out of the hole. hole.
b.
Flow check, check, if negative, negative, pump a heavy slug around around BHA then continue continue to pull out of the hole.
c.
Shut the well in and circulate the hole through the choke.
d.
Flow check, check, if negative, negative, run run back back to bottom and monitor returns.
e.
Pump remaining pipe out of the hole.
26. Which of the following are warning signs that the well may be going underbalance (THREE ANSWERS). a. A reduction reduction in the rate of penetration. penetration. b. Increasing background gas levels. c. Change in the shape, size and volume of cuttings. cuttings. d. Increase in the the flowline flowline mud weight. weight. e. An increase in drag values.
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27. Which of the following is not a kick warning sign? a.
Decrease in pump strokes.
b.
Pit gain.
c.
Decrease in pump pressure.
d.
Flow rate increase.
28. Which of the following is the first indication that the well is flowing? a.
Decrease in pump pressure.
b.
Increase in rotary torque.
c.
Gas cut mud seen at the Shakers.
d.
Increase in mud returns from the well.
29. What should the Driller do at a drilling break? a. Stop drilling and flow check b. Stop drilling drilling and circulate circulate bottoms bottoms up. up. c. Increase pump speed to keep hole clean. d. Reduce weight on bit and control control drill. drill.
30. Well flows when when mud pump is shut off. No excess flow or pit gain when pumps pumps are running. What is happening? a.
Mud hydrostatic pressure exceeds formation fracture pressure.
b.
The mud pump is leaking.
c.
Mud hydrostatic pressure is greater than formation pressure
d.
Annular friction losses losses are are keeping keeping enough enough overbalance overbalance to prevent prevent the formation from flowing.
31. What are the positive indicators of a kick seen by the Driller? (TWO ANSWERS). a.
Increase in flow rate (constant SPM).
b.
Decrease in pit volume (constant SPM).
c.
Decrease in flow rate (constant SPM).
d.
Increase in pit volume (constant SPM).
32. Which of the following actions will make it harder to detect a pit gain? a.
Setting high/low alarms to ±5 barrels.
b.
By passing the Shakers.
c.
Allowing mud to overflow shakers.
d.
Keeping mud transfers to a minimum minimum while drilling ahead.
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33. Will a gas kick entering the hole always cause a pit level increase? (please tick in space provided). a. When using Water-based mud
True
False
False
b. When using Oil-based mud
True
34. The following statements describe the difference in behaviour between drilling with Oilbased and Water-based Water-based mud. Indicate whether the statements statements are true or false (please tick in space provided). a. Gas kicks in Water-based mud are normally normally easier easier to detect due to lower lower gas solubility. True True
False
b. Gas kicks in Water-based mud are normally normally harder harder to detect due to higher higher gas solubility. True
False
c. Gas entering the Well bore bore while drilling drilling with with Oil-based mud will reduce reduce the hydrostatic pressure more than when drilling with Water-based mud. True
False
d. When circulating circulating out a gas kick, gas gas expansion expansion occurs in the Annulus at the same rate in Oil-based and Water-based mud. True
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False
2-9
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3-1
Section 3 Shut in Procedures
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3-2
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3-3
1. What is the choke manifold line line up for a soft shut-in procedure whilst whilst drilling? a.
BOP side outlet hydraulic valve (HCR) open. Remote choke open. Valve upstream of the mud-gas separator closed.
b.
BOP side outlet hydraulic valve (HCR) closed. Remote choke open. Valve upstream of the mud-gas separator open.
c.
BOP side outlet hydraulic valve (HCR) open. Remote choke closed. Valve upstream of the mud-gas separator closed.
d.
BOP side outlet hydraulic valve (HCR) closed. Remote choke closed. Valve upstream of the mud-gas separator open.
2. What is the choke manifold line up for a hard shut-in shut-in procedure whilst whilst drilling? drilling? a.
BOP side outlet hydraulic valve (HCR) closed. Choke line open to remote choke. Remote choke closed.
b.
BOP side outlet hydraulic valve (HCR) open. Choke line open to remote choke. Remote choke open.
c.
BOP side outlet hydraulic valve (HCR) closed. Choke line open to remote choke. Remote choke open.
d.
BOP side outlet hydraulic valve (HCR) closed. Choke line open through manual choke. Manual choke open.
3. When picking up to check for f or flow the pumps are usually kept running, why? a.
To take a slow circulating rate pressure.
b.
To check the pressure losses in the Annulus.
c.
To clean the bottom of the hole of cuttings.
d.
To maximise maximise the pressure on the bottom of the the hole. hole.
4. Whilst tripping out of the hole the well starts flowing. What is the first action that should be taken? a.
Stab a drillstring drillstring safety valve and shut the well in.
b.
Pull back to shoe and shut in.
c.
Run back to bottom as quickly as possible.
d.
Close the Annular and make up the Top Drive or Kelly.
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5. The well kicks while tripping. Which of the following actions should be taken to shut the well in using the hard shut in? a.
Stab full opening safety valve. Open BOP side outlet hydraulic valve (HCR). Space out for tool joint. Close BOP. Close choke. Record pressure.
b.
Space out for tool joint. Close the BOP. Stab full opening safety valve. Close the safety valve. Open choke. Record pressure.
c.
Stab full opening safety valve. Close the safety valve. Space out for tool joint. Close BOP. Open BOP side outlet hydraulic valve (HCR). Record pressure.
d.
Open side outlet hydraulic valve (HCR) and remote choke. Space out for tool joint. Close BOP. Stab full opening safety valve. Close safety valve. Record pressure.
6. Which of the following practices would lead to a bigger influx when shutting shutting the well in? (THREE ANSWERS) a. Regular training training for the Derrickman on his duties duties for monitoring monitoring pit level. level. b. Testing stab in in valves valves during during BOP tests. c. Flow Check drilling break after 20 feet drilled. drilled. d. Running regular pit drills drills for for drill crew. e. Calling Toolpusher to floor prior to shutting in the well. f.
Switching off the flow meter alarms while drilling.
7. Why should the well be shut in quickly after a kick has been detected? a.
To minimise the Shut In Drill Pipe Pressure (SIDPP).
b.
To reduce the migration speed of the influx.
c.
To minimise the size of the influx.
8. Shallow Gas Kicks Kicks are less dangerous dangerous than deeper deeper kicks because because there is more more time to react to the warning signs.
True
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False
3-5
9. When tripping out of the hole with 40 stands still to pull the well flows. How do we shut the well in using the soft shut-in method? a.
Open BOP side outlet hydraulic valve (HCR). Close BOP. Stab full opening safety valve. Close safety valve. Close choke. Record pressure.
b.
Stab full opening safety valve. Close the safety valve. Open BOP side outlet hydraulic valve (HCR). Close BOP. Close choke. Record pressure.
c.
Close BOP. Stab full opening safety valve. Close the safety valve. Open choke. Record pressure.
d.
Stab full opening safety valve. Open BOP side outlet hydraulic valve (HCR). Close BOP. Close choke. Record pressure.
10. Put the following five steps in the correct sequence to shut the well in using the soft shut-in procedure (according (according to API RP59). a.
………4 ………4……… Close the BOP.
b.
………3 ………3……… Open the BOP side outlet hydraulic valve (HCR).
c.
………1 ………1……… With choke already open, position the drill sting correctly.
d.
………5 ………5……… Close the choke.
e.
………2 ………2……… Stop the pumps.
11. What is the Choke Manifold line up for the soft shut-in procedure whilst drilling? a.
BOP side outlet hydraulic valve (HCR) open. Choke line open through remote choke. Remote choke open.
b.
BOP side outlet hydraulic valve (HCR) closed. Choke line open through remote choke. Remote choke closed.
c.
BOP side outlet hydraulic valve (HCR) closed. Choke line open through manually operated choke. Manual choke closed.
d.
BOP side outlet hydraulic valve (HCR) closed. Choke line open through remote choke. Remote choke open.
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3-6
12. Which of the following describes the hard shut-in procedure for a surface stack according to API RP59? a.
With remote choke open, position the drill string correctly Stop the pumps. Open BOP side outlet hydraulic valve (HCR). Close BOP. Close the choke. Record pressures.
b.
With remote choke closed, position the drill string correctly. Stop the pumps. Open BOP side outlet hydraulic valve (HCR). Close BOP. Record pressures.
c.
With remote choke closed, position the drill string correctly. Stop the pumps. Close BOP. Open BOP side outlet hydraulic valve (HCR). Record pressures.
13. Which of the following describes the soft shut-in procedure when the well is observed to be flowing while tripping? a.
Stab open drill pipe safety valve. Open BOP side outlet hydraulic valve (HCR). Space out to clear tool joints from Ram. Close BOP. Close choke. Record pressure.
b.
Open BOP side side outlet outlet hydraulic hydraulic valve (HCR) and Remote Remote choke. Space out to clear tool joints from Ram. Close BOP. Stab open drill pipe safety valve. Close drill pipe safety valve. Close remote choke. Record pressure.
c.
Space out to clear tool joints from the Ram. Close the BOP. Stab open drill pipe safety valve. Close drill pipe safety valve. Open choke. Record pressure.
d.
Stab open drill pipe safety valve. Close drill pipe safety valve. Open BOP side outlet hydraulic valve (HCR). Space out to clear tool joint from Ram. Close BOP. Close choke.
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14. When drilling with a surface BOP how should the stack and choke manifold be set up for a soft shut-in? (THREE ANSWERS) a.
Remote choke open.
b.
BOP side outlet hydraulic valve open.
c.
Remote choke closed.
d.
Choke line open through remote choke.
e.
BOP side outlet hydraulic valve (HCR) closed.
f.
Choke line closed through remote choke.
15. According to API RP59 which type of BOP can be used for the hard shut-in? a.
Annular BOP.
b.
Either type of BOP can be used.
c.
Ram BOP.
16. Which of the following correctly describes the soft shut-in procedure according to API RP 59? a.
With choke already open, Pick up off bottom, Shut down pumps, Open BOP side outlet hydraulic valve (HCR), Close the BOP, Close the choke, Record pressures.
b.
With choke already closed, Pick up off the bottom, Shut down pumps, Open BOP side outlet hydraulic valve (HCR), Close the BOP, Record pressures.
17. Which of the following describes the API RP59 hard shut-in procedure? a.
With choke already closed, Pick up off bottom, Shut down pumps, Close the BOP, Open BOP side outlet hydraulic valve (HCR), Record pressures.
b.
With choke already open, Pick up off the bottom, Shut down pumps, Open BOP side outlet hydraulic valve (HCR), Close the BOP, Close the choke, Record pressures.
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18. Listed below are two procedures to Shut-in the well: a. With choke open, pick up off bottom, shut down pumps, open side outlet valve on BOP, close BOP, close the choke, record pressures. b. With choke closed, pick up off bottom, bottom, shut down pumps, close BOP, open side side outlet valve on BOP, record pressures. Which procedure above is:Hard Shut-in Procedure Number:
… b…
Soft Shut-in Procedure Number:
… a…
19. How should the Choke Manifold be lined up, when drilling, for a Soft Shut-in procedure? (Tick the appropriate box below). Tick here: a.
b.
c.
d.
Side outlet valve on BOP closed. Choke Line open through remote adjustable choke. Remote adjustable choke closed. Side outlet valve on BOP open. Choke Line open through manual choke. Remote choke open. Side outlet valve on BOP open. Choke Line open through remote adjustable choke. Manual choke closed. Side outlet valve on BOP closed. Choke Line open through remote adjustable choke. Remote adjustable choke open.
20. How should the Choke Manifold be lined up, when drilling, for a Hard Shut-in procedure? (Tick the appropriate box below). Tick here: a.
b.
c.
d.
Side outlet valve on BOP closed. Choke Line open through remote adjustable choke. Remote adjustable choke closed. Side outlet valve on BOP open. Choke Line open through manual choke. Remote choke open. Side outlet valve on BOP open. Choke Line open through remote adjustable choke. Manual choke closed. Side outlet valve on BOP closed. Choke Line open through remote adjustable choke. Remote adjustable choke open.
21. Why is it important to shut the well in quickly if a kick is detected? a. Keep kick volume as small as possible. b. Prevent gas migration. c. Keep SIDPP as small as possible.
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22. From the list of practices shown below, select those which lead to an increase in the size of the influx? (THREE ANSWERS). a. Running regular pit drills drills for Drill Crew. Crew. b. Switching off the flow meter alarms. c. Regular briefing briefing for the Derrickman on his duties duties regarding regarding the monitoring monitoring of pit pit level. d. Drilling a further 15 ft after a Drilling Drilling Break, before flow checking. e. Calling Toolpusher to floor prior to shutting in the well. f.
Testing stab in valves during BOP tests.
23. The well starts to flow when when tripping out of the hole. Which of the following actions actions should be taken to close the well in using the Soft Shut-in? a. Close the BOP Stab full opening safety valve Open choke Close the safety valve. b. Stab full opening safety valve Open BOP side outlet hydraulic valve Close BOP Close choke. c. Open BOP side side outlet outlet hydraulic hydraulic valve Close BOP Stab full opening safety valve Close choke Close safety valve. d. Stab a full opening opening safety valve Close the safety valve Open BOP side outlet hydraulic valve Close BOP Close choke.
24. What steps should be taken to divert a shallow gas flow? a.
Slow pumps, pumps, space out and and use choke to maintain maintain a constant bottom hole hole pressure pressure until the well is dead.
b. Maintain or increase increase pump pump rate and activate activate Diverter. Diverter. c.
Pick up and space out. Switch off pumps. Open downwind vent line, close valve to shakers, close Diverter.
25. What action should be taken if the well flows while Tripping out of the hole? a. Install a safety valve on drill string and shut the well in. in. b. Run back to bottom immediately. c. Continue pulling out of hole. d.
Close BOP then install kelly or Top Drive.
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3 - 10
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4- 1
Section 4 Data to Collect
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4- 2
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4- 3
1. A well has been been shut in in on a kick. Which pressure pressure gauge gauge readings readings can be used to determine formation pressure? (TWO ANSWERS) a.
Drill pipe pressure gauge on the choke panel.
b.
Casing pressure gauge on the choke panel.
c.
Drill pipe pressure gauge on the Driller’s panel.
d.
Choke manifold pressure gauge.
2. A well is shut in on a kick and drill pipe pressure pressure recorded. recorded. The casing casing gauge is not working. Which pressure cannot found? a.
Initial Circulating Pressure.
b.
Shut In Casing Pressure.
c.
Bottom hole pressure.
d.
Formation pressure.
3. Which of the following following affect the Shut In Drill Pipe Pressure? Pressure? (TWO ANSWERS) a.
Mud weight in drillstring.
b.
Size of Influx.
c.
Annular volume from Bit to Shoe.
d.
Influx gradient.
e.
Formation fluid pressure.
4. Why is Shut In Drillpipe Pressure usually usually lower than Shut In Casing Pressure? Pressure? a.
The influx fluid is usually usually less dense than the mud.
b.
The cuttings cuttings in the annulus annulus are are lighter, lighter, therefore therefore creating creating a lighter hydrostatic.
c.
The only difference is in the type of gauges used.
d.
The casing pressure is not always higher; higher; it depends on whether whether it is a land or offshore rig.
5. A vertical well with with a surface surface BOP stack is shut in on a kick. The pressure pressure readings readings are as follows: SIDPP : 350 psi
SICP
:
450 psi
What is the reason for the difference in the two readings? a.
The influx is inside the drillstring.
b.
The influx has a lower density than the mud.
c.
The BOP was closed too fast causing trapped pressure.
d.
The influx has a higher density than the mud.
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4- 4
6. Which pressures pressures are needed needed to calculate calculate Shut In Drill Pipe Pressure? (TWO ANSWERS) a.
Fracture pressure.
b.
Shoe pressure.
c.
Hydrostatic pressure.
d.
Formation pressure.
7. Whilst pumping why can the standpipe pressure be slightly lower than the pressure shown on the gauge at the mud pump? a.
Hydrostatic pressure of the mud in the standpipe causes the difference. difference.
b.
Dynamic pressure losses from the pump to the standpipe standpipe affect the readings.
c.
The stand pipe pressure pressure gauge gauge is situated at at a lower lower elevation elevation than the gauge gauge at the the pump.
8. Whilst drilling drilling ahead, ahead, the well kicks kicks and is shut in. Drill pipe pipe pressure and casing casing pressure both start to build up, but before stabilising both start to drop quite rapidly. Which of the following might have occurred? a.
Gas is to migrating up the well.
b.
The drill string has washed out.
c.
The bottom hole assembly has packed off.
d.
Both gauges have malfunctioned. malfunctioned.
e.
A weak formation has broken down.
9. A well has been shut shut in on a kick. The drill pipe pipe pressure pressure is zero because there there is a float float (non-return) valve in the string. How can you find the Shut In Drill Pipe Pressure? a.
Bring the pump up to kill rate rate holding holding the casing pressure pressure constant constant by opening the choke. The pressure shown shown when the pump is at kill rate is the Shut In Drill Pipe pressure.
b.
Shear the the pipe and read read the drill pipe pipe pressure pressure directly directly off off the casing gauge.
c.
Pump very slowly slowly into into the drill string with the well well shut shut in. When casing pressure starts to rise, stop the pump and read the pressure. pressure. This is the Shut In Drill Pipe pressure.
d.
Pump at 2 barrels per minute into the annulus annulus with the well well shut shut in. When the pressure equalises equalises the float will open. This pump pressure is the Shut Shut In Drill Pipe pressure.
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4- 5
10. A well has kicked, kicked, and is shut in. There is a float valve in the drill string. string. What would be the correct course of action to determine the kill mud weight? a.
Pump very slowly into into the drill string string with with the well shut shut in. When the the casing casing pressure rises the float valve has has opened. This pressure on the drill pipe pipe gauge is the Shut In Drill Pipe Pressure.
b.
Start raising the mud weight by 0.5 ppg increments until the well is dead.
c.
Remove Kelly and drop float-opening tool.
d.
Use the annulus pressure to calculate calculate the kill mud mud weight. weight.
11. A well has kicked with a float in the drill string and the Shut In Drill Pipe Pressure gauge reads zero. Which of the following methods should be used to find the kill mud weight? a.
Calculate hydrostatic pressure of of the influx influx and subtract from the Shut In Casing Casing Pressure.
b.
Start circulating circulating at the the slow circulating rate, determine determine the Initial Initial Circulating Circulating Pressure and calculate the Shut In Drill Pipe Pressure.
c.
Pump very very slowly slowly into into the drill pipe with the well well shut in. in. When the casing casing pressure rises the float has opened. opened. The pressure on the drill pipe pipe is the Shut In Drill Pipe Pressure.
12. Shut In Casing Pressure is usually higher than Shut In Drill Pipe Pressure. If there was a large volume of cuttings in the annulus how would this effect pressure readings? a.
Shut In Casing Casing Pressure would be higher than expected.
b.
It would not affect pressure readings.
c.
Shut In Casing Pressure would be lower than expected.
13. Which of the following parameters parameters affect the value of Shut In Casing Pressure after a well is shut in during a kick (THREE ANSWERS) a.
The formation fluid pressure (pore pressure).
b.
Bottom hole temperature.
c.
Annulus capacity.
d.
The kick volume.
e.
Choke line length.
f.
Drill string capacity.
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4- 6
14. Which of the following are affected by formation permeability. permeability. (THREE ANSWERS) a.
SICP
b.
Time for pressures to stabilise
c.
ICP
d.
Kill Mud Weight
e.
Influx volume
f.
SIDPP
15. When drilling a horizontal section of a well a gas kick is taken and the well shut in. If the influx is in the horizontal section what what would you expect the SIDPP and SICP to be? a.
Both are about the same.
b.
SICP is much greater than the SIDPP.
c.
SIDPP is much greater than the SICP.
d.
SIDPP will be zero.
16. A well is shut in with a gas kick. The bit is 90 feet off bottom and the influx is on bottom and 30 feet long (all the influx is below the bit). Shut In Drill Pipe Pressure is 300 psi. What is the Shut In casing Pressure likely to be? a.
Lower than the Shut Shut In Drill Pipe Pressure because of the effect of the annular friction loss.
b.
Higher than the Shut In Drill Pipe Pressure.
c.
The same as the Shut In Drill Pipe Pressure.
d.
Will depend on gradient of the influx.
17. The well is shut in on a kick after an extended period of fast drilling. What would you expect the Shut In Casing Pressure to be? a.
Lower than if the drilling had been slow.
b.
Higher than if drilling had been slow.
c.
The same, same, whether whether the annulus annulus is clean clean or loaded with cuttings.
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18. WELL DATA Shut In Drill Pipe Pressure
= 300 psi
Mud weight
= 10.0 ppg
A salt-water kick has has been taken, filling filling 250 feet of the annulus. annulus. Salt Water weight
= 8.6 ppg
From the data above calculate the Shut In Casing Pressure? a.
18 psi.
b.
318 psi.
c.
430 psi.
d.
412 psi.
F-17
19. A well is shut in after a kick. TVD
9,500 feet
Mud weight
10 ppg
Shut In Drill Pipe Pressure
400 psi
Height of influx
700 feet
Influx gradient
0.1 psi/ft
Calculate the Shut In Casing Pressure? a.
70 psi.
b.
765 psi.
c.
695 psi.
d.
700 psi.
F-17
20. A well is shut in on a kick and the pressures pressures have stabilised. stabilised. Due to equipment equipment problems the kill operation operation is delayed. Shut in Drill Pipe Pressure and and Shut In Casing Pressure are gradually rising after stabilisation. stabilisation. What is the most likely cause of this? a.
There is a non-return valve in the BHA.
b.
The mud in the hole is heating up up and it is causing causing the volume to decrease.
c.
The influx is gas and is migrating.
d.
The formation that kicked has high permeability.
21. What could happen if gas migrates after a well is shut in and pressures have stabilised? a.
Only the drill pipe pressure will increase.
b.
Shut in pressures will remain constant.
c.
Both drill pipe and annulus pressures will increase.
d.
Only the annulus pressure will increase.
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4- 8
22. A well is shut in following following a kick whilst drilling. drilling. After pressures have been been stabilised, both drill pipe and casing pressures are observed to be gradually increasing by the same amount. What is the most likely reason for this? a.
The influx influx is gas and and is migrating up the annulus and drill drill string. string.
b.
The influx is gas gas and is migrating up the annulus.
c.
The influx is gas and is migrating up the drill string.
d.
The influx is gas and is expanding rapidly.
23. A vertical well is shut in with a gas kick. Surface Pressures are: SIDPP
= 500 psi
SICP
= 600 psi
Mud Weight
= 11.5 ppg
If the gas migrates 500 feet up the well what would the pressures be if no action is taken? a.
Drillpipe = 800 psi, Casing = 900 psi
b.
Drillpipe = 500 psi, Casing = 900 psi
c.
Drillpipe = 800 psi, Casing = 600 psi
d.
Drillpipe = 600 psi, Casing = 900 psi
24. A well is shut in on a kick.
SIDPP = 400 psi.
Mud Weight = 13 ppg
SICP = 600 psi.
Influx gradient = 0.1 psi/ft
After 30 minutes both pressures have have risen by 150 psi psi due to gas migration. migration. Calculate Calculate the speed of gas migration in feet per hour. a.
325 ft/hr
b.
444 ft/hr
c.
590 ft/hr
d.
200 ft/hr
F-19
25. A vertical well has been shut in after a gas kick. The surface pressures are as follows:Shut In Drill Pipe Pressure (SIDPP)
= 500 psi
Shut In Casing Pressure (SICP)
= 700 psi
Mud weight in the well
= 12.0 ppg
The well is left shut in for some time, during which time the gas migrates 500 feet up the well. What will be the expected pressures at surface? a.
Drill pipe pressure – 812 psi, Casing pressure – 1,012 psi.
b.
Drill pipe pressure – 500 psi, Casing pressure – 700 psi.
c.
Drill pipe pressure – 812 psi, Casing pressure – 700 psi.
d.
Drill pipe pressure – 500 psi, Casing pressure – 1,012 psi.
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26. Which of the following affect the choice of slow circulation rate? (THREE ANSWERS). a. Casing burst pressure. b. Annular friction losses. c. Ability to mix kill mud. d. Volume of trip tank. e. Size of choke choke and and Choke Choke Lines. Lines.
27. Which of the following statements about slow circulating rates (SCR) are correct? (THREE ANSWERS). a. SCR’s should be taken through the choke manifold.. manifold.. b. SCR’s are needed to calculate formation pressure pressure c. SCR’s should be taken when when mud properties are are changed. d. SCR’s should be read on the drill pipe pressure gauge at the remote choke panel. e. SCR’s should be taken with with the bit near the bottom
28. Which of the following can determine the SPM chosen to kill the well? (TWO ANSWERS). a. Volume of mud in the drill pipe. b. Maximum pressure the pump can handle. handle. c. Volume of mud in the Annulus. d. Viscosity of the mud. mud.
29. When should the Driller consider taking a slow circulation rate pressure? (TWO ANSWERS). a. At beginning of each shift. b. After the well has been shut in on an influx. influx. c. Before running running casing. d. After mud weight weight change.
30. Select the reason for circulating out a kick at a slow pump rate. a. Prevent gas expansion as it is circulated up the well. b. Allow Annular Pressure loss to maintain a high overbalance. overbalance. c. Minimise excess pressure pressure exerted on formations during the kill.
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4- 10
31. Tick 5 situations, from the t he following list, under which you would consider taking a new SCR. a.
Every shift.
b.
Before and after a leak-off test.
c.
Mud property changes.
d.
Mud weight changes.
e.
After each connection when drilling with top drives.
f.
After recharging mud pump pulsation dampener.
g.
When long sections of hole are drilled rapidly.
h.
When returning to drilling after a kick.
32. An influx is to be displaced from the hole at a pump rate slower than used when drilling. Why? (FOUR ANSWERS). a.
Allow Choke Operator time to make the necessary necessary choke adjustments.
b.
To reduce damage to the pump.
c.
Minimise Pressures in the wellbore.
d.
To allow kick fluids to be handled at surface.
e.
To reduce gas migration.
f.
To reduce the chance of overloadin overloading g the mud gas separator.
33. Which of the following would cause pump pressure to increase if pumping at a constant SPM? (TWO ANSWERS). a.
Using larger nozzles.
b.
Drilling deeper.
c.
When the mud weight is reduced.
d.
Increasing the mud viscosity.
34. Mud density = 12 ppg Pump pressure = 750 psi at 60 SPM Calculate approximate pump pressure if mud weight is:a.
Increased to 13 ppg ……812……. ……. ……812
b.
psi
Decreased to 11 ppg ……687……. ……. ……687
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4- 11
psi
35. Which of the following determines the SIDPP. (TWO ANSWERS). a. Influx density. b. Influx size. c. Mud density inside the drillstring. d. Formation fluid pressure. e. Cuttings volume in the Annulus.
36. Which pressure gauge readings could be used to calculate formation fluid pressure? (TWO ANSWERS). a. Accumulator Gauge. b. Casing Pressure Gauge on on Choke Choke panel. panel. c. Drill Pipe Pipe Pressure Pressure Gauge Gauge at Driller’s console. d. Drill Pipe Pipe Pressure Pressure Gauge Gauge on Choke panel.
37. What action should be taken if a well is shut-in and a float is in the string? a. Calculate kill mud density density using Shut-in Casing Casing Pressure. b. Raise the mud density by 0.5 ppg increments until until the well well is dead. c. Pump very slowly into into the drill drill string with the well shut shut in. When the pump pressure stabilises, stabilises, the float valve should have opened. opened. This pressure is the Shut-in Drill Pipe Pressure. d. Remove Top Drive or kelly and install a float opening tool.
38. Why is casing pressure usually higher than the shut-in drill pipe pressure: a. Choke Line is larger in diameter than Kill Line. b. The influx fluid is is usually lighter lighter than the mud weight weight in the hole. hole. c. The Choke Line is longer longer than the Kill Line. Line. d. Cuttings in the Annulus Annulus help reduce reduce the hydrostatic hydrostatic pressure.
39. In a well kick situation, situation, SICP is normally greater than SIDPP. SIDPP. If the Annulus was loaded with cuttings at the time of Shut-in, how would this affect SICP compared to a clean Annulus? a. SICP would be higher. b. SICP would be lower. c. SICP would be the same.
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4- 12
40. After a kick is taken and the well shut-in, it can take 5-10 minutes or more for the pressures to build up. What affects the time for t his build up? a. Friction losses b. Gas migration c. Formation Porosity d. Formation Permeabili Permeability ty
41. Why would the pump pressure gauge on the rig floor read a lower pressure than the gauge on the pump? a. The pressure pressure loss from the pump to the rig floor floor affects the readings. readings. b. The pump pressure gauge on the rig floor is lower than the gauge on the pump. c. The mud mud is is less dense at the pump.
42. How can we establish SIDPP if there is a float in the string? a. Bring the pump up to kill rate rate holding holding Casing Casing Pressure constant. Once up to speed, the pump pressure is SIDPP. b. Pump slowly into the drill pipe with the well shut-in. When Casing pressure starts to rise, the float has has opened. This pump pressure pressure is the SIDPP. SIDPP. c. Pump at kill rate into the drill string string with the well shut in. When Casing Casing pressure pressure starts to rise, read the the pump pressure. pressure. This is SIDPP. d. Reduce SICP by 20%.
43. After SIDPP and SICP have stabilised, it is noticed that they both start slowly rising by the same amount. amount. What is the probable probable cause of this? a. Remote choke is leaking. b. Influx migration up the bore. c. Pumps are being being operated operated at at slow circulating rate. d. Second influx.
44. The Shut-in Casing Pressure (SICP) is used to: a. Establish the true Initial Circulating Circulating Pressure Pressure at start start up. b. Calculate kill mud weight. c. Calculate Initial Circulating Pressure.
45. A well that kicked was was Shut-in. While waiting, it is noted that the SIDPP and SICP SICP are still rising after several several hours. What is the most likely likely cause of this? a. The influx is migrating. b. The formation formation has a high permeability. permeability. c. The non-return non-return valve in the string is leaking. leaking. d. The mud in in the hole is heating up, causing the volume to decrease. RSTS - EGYPT
4- 13
46. SIDPP SICP
=
700 psi
=
900 psi
Mud Weight
=
Influx Gradient=
13.5 ppg 0.15 psi/ft
After 30 minutes, both both SIDPP and SICP have have risen by 150 psi. psi. Calculate speed speed in ft/hour that influx is migrating. a. 214 ft/h b. 427 ft/h
F-19
c. 14 ft/h d. 28 ft/h
47. TVD
:
8000 FT
Mud density
:
10 ppg
SIDPP
:
600 psi
Height of influx
:
700 ft
Influx density
:
0.1 psi/ft
Calculate Shut-in Casing Pressure (SICP). a. 700 psi b. 600 psi c. 294 psi d. 894 psi
F-17
48. Salt Salt Water kick height
=
320 ft
Influx Gradient
=
0.45 psi/ft
Mud Weight in hole
=
11.2 ppg
SIDPP
=
350 psi
Calculate SICP:a. 42 psi b. 128 psi c. 392 psi
F-17
d. 478 psi
49. When pumping pumping at 80 SPM the pump pressure = 4000 4000 psi. What would be approximate approximate pump pressure if pumps were slowed to 40 SPM? a. 500 psi. b. 800psi. c. 1000 psi.
F-9
d. 2000 psi.
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4- 14
50. From the statements below select the correct reason for circulating a kick at a slow rate. a. Minimise pressure pressure exerted exerted on formations formations during the kill operation. operation. b. Minimise expansion expansion of gas influx to reduce casing casing pressure pressure during the kill operation. c. Give sufficient sufficient pressure loss loss in the annulus annulus to give give greater overbalance during the kill operation.
51. Which of the following determine the selection of t he slow circulation rate? (FOUR ANSWERS) a.
Trip tank volume.
b.
The mud/gas separator handling capacity.
c.
The volume of mud the choke can handle.
d.
Capacity of mud mixing equipment.
e.
Annular friction loss during the kill.
f.
The burst pressure of the casing.
52. With a constant flow rate, which factors will increase the circulating pressure? (TWO ANSWERS) a.
When bit nozzle size is increased.
b.
When hole is drilled deeper.
c.
When more drill collars are added.
d.
When mud weight is reduced.
53. Slow circulation rate tests are made at different pump rates (spm). Which of the following help you decide which pump rate is used? (TWO ANSWERS) a.
Mud pump pressure limitation.
b.
Mud/gas separator capacity.
c.
Depth of Casing Shoe.
54. Prior to drilling out the surface casing shoe the slow circulating rates are taken. Which of the following determines determines the choice of pump rate? a.
The size of the surface casing.
b.
Gas handling equipment limitation and kill mud-mixing capability.
c.
The expected Shut In Casing Pressure.
d.
The volume of the trip tank.
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4- 15
55. When should the Driller consider taking a slow circulation rate pressure? (TWO ANSWERS) a.
Every time mud weight is changed.
b.
At the beginning of each shift.
c.
Only after drilling out the casing shoe.
d.
Immediately before running casing.
56. Which of the following statement about slow circulating rate pressure are correct? (THREE ANSWERS) a.
Should be recorded when mud properties have changed significantly.
b.
Recorded on the drill pipe pressure gauge on the choke panel.
c.
The recorded pressures are used to calculate formation pressure.
d.
Recorded with the bit near bottom.
57. When circulating the drilling mud at 80 spm, the pressure on the standpipe gauge reads 3,000 psi. What would the calculated standpipe standpipe pressure be if the pump speed were reduced to 40 spm? a.
Approximately Approximately 500 psi.
b.
Approximately Approximately 600 psi.
c.
Approximately Approximatel y 750 psi.
d.
Approximately Approximately 1500 psi.
58. A vertical well is 5500 feet deep and filled with 11.2 ppg mud. While circulating at 100 spm the friction losses in the well are as follows: a. 150 psi through surface equipment. equipment. b. 900 psi in drill drill string. c. 1,700 psi through through bit nozzles. d. 100 psi in annulus. annulus. What is the bottom hole pressure when the pumps are running at 100 spm? …3303… … …3303
psi
59. A vertical well is 5,520 5,520 feet deep and filled with 11.2 11.2 ppg mud. While circulating at 100 100 spm the friction losses in the well system are as follows: a. 150 psi pressure loss through surface equipment. b. 900 psi pressure loss in drill string. c.
1,700 psi pressure loss through bit nozzles.
d. 100 psi pressure loss in annulus. What is the pump pressure when circulating at 100 spm? …2850… … …2850
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psi
4- 16
60. At 60 strokes/minute, with a mud weight of 12 ppg, the circulating pressure is 600 psi. What would be the approximate circulating pressure (at the same spm) if the mud weight were raised to 13 ppg? ……650……. ……. ……650
psi
61. The equivalent circulating density (ECD) determines the actual bottom hole pressure while circulating. Which part of the t he system pressure losses used to calculate ECD? a.
The pressure loss in the annulus.
b.
The pressure loss in the open hole section only.
c.
The pressure loss across the nozzles.
d.
The pressure loss in the drill string.
e.
The pressure loss in the surface system.
62. (S) At 60 spm, with 10 ppg mud, the pump pressure is 1,500 psi. What would the pump pressure be if the rate were decreased to 20 spm and the mud weight increased to 11.0 ppg? a. 167 psi. b. 183 psi.
F-9 & F-10
c. 204 psi. d. 262 psi.
63. Once the well is shut in, which factor determines the time taken for Shut In Drill Pipe Pressure and Shut In Casing Pressure to stabilise? a. Porosity. b. Permeability. c. Gas migration. d. Friction losses.
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5- 1
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5- 2
Section 5 Fractures and MAASP
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5- 3
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5- 4
1. After setting casing, casing, which of the following following actions are are normally taken prior to making a leak-off test? (TWO ANSWERS) a.
Run bit close to bottom.
b.
Circulate the mud to get a uniform column of mud in the hole.
c.
Drill out the casing shoe approximatel approximately y 15 feet into new formation.
d.
Line up the mud pump to do do the the leak-off leak-off test at at the slow circulating rate.
2. When should should a leak-off test be carried out? a.
Before drilling out casing shoe.
b.
Before running casing.
c.
Immediately after running and cementing casing.
d.
After drilling drilling out the casing shoe and 5 to 15 15 feet feet of of new new formation. formation.
3. Which of the following following are needed needed for the calculation calculation of an accurate accurate formation strength strength at the shoe? (THREE ANSWERS) a.
Accurate pressure gauge.
b.
Accurate stroke counter.
c.
Accurate hole capacity
d.
Exact vertical depth of casing shoe.
e.
Installation of retrievable retrievable packer packer approximately approximately 1000 feet below below the rig floor. floor.
f.
Constant mud weight around the well.
4. Which of the following need need to be known for a leak-off test to be correct? (TWO ANSWERS) a.
The mud weight in the well.
b.
The volume volume of mud mud in the annulus annulus from casing casing shoe to surface. surface.
c.
Slow circulating rate.
d.
The pressure limit for the mud pump.
e.
Mud hydrostatic pressure in the casing annulus.
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5- 5
5. Which of the following following could could influence influence the leak-off leak-off test result? (TWO ANSWERS) a.
The pressure limit for the mud pump.
b.
The planned pump rate for drilling
c.
Casing burst pressure.
d.
The mud volume in the casing annulus.
e.
The mud hydrostatic pressure at the casing shoe.
6. To ensure that that an accurate accurate leak-off test test result a number of parameters parameters must must be accurately recorded. Select those parameters from the following. (THREE ANSWERS) a.
Measured depth of the casing shoe.
b.
Mud volume in the casing.
c.
Pumping time till leak-off starts.
d.
True vertical depth of the casing shoe.
e.
Mud volume pumped till leak-off starts.
f.
Mud Weight in hole.
7. The casing shoe has been been drilled drilled and 10 feet of new hole made. made. A leak-off test test is to be taken. The mud is being conditioned conditioned to make the weight the same around the well. Which of the following would help give an accurate leak-off test result? a.
Condition the mud until the mud weight in the well is constant before conducting the leak-off test.
b.
Stop the pump after 5 barrels and record the drill pipe pressure as leak-off.
c.
Choose the lightest mud weight in the hole and use it in in the the leak-off test result. result.
d.
Slowly pump water down the annulus with the cement pump and record the pressure.
8. Which of the following following is is a definition of MAASP? MAASP? a.
The pressure in excess of mud hydrostatic that, if exceeded, is likely to cause losses at the shoe.
b.
The maximum pressure allowed in the hole during a kill operation.
c.
The maximum pressure allowed on the drill pipe gauge during a kill operation.
d.
The total pressure applied at the shoe that is likely to cause losses.
9. Shoe TVD = 6000 feet.
Mud Weight = 11 ppg
Calculate the maximum allowable mud weight. ………13.88……. ……. ………13.88
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ppg
5- 6
Leak-off pressure = 900 psi
10. WELL DATA: 13-3/8 inch casing is set at 5,210 feet feet TVD. Formation strength at the shoe is 3,800 3,800 psi. Current Mud Weight = 10.6 ppg. What is the Maximum Allowable Annulus Surface Pressure (MAASP) a.
2,050 psi.
b.
555 psi.
c.
928 psi
d.
1,800 psi.
11. (S) (S) Which Which of the following conditions in the well increase the risk of exceeding MAASP during a kill operation? (THREE ANSWERS) a. Small difference difference between formation breakdown breakdown pressure pressure and mud hydrostatic hydrostatic pressure. b. Small influx. c. Large difference difference between between formation breakdown pressure and and mud hydrostatic hydrostatic pressure. pressure. d. Long open hole section. e. Large influx. f.
Short open hole section.
12. What will happen to MAASP if Mud Weight is increased? a. MAASP will stay the same. b. MAASP will increase. c. MAASP will decrease.
13. Which of the following affect Maximum Allowable Annular Surface Pressure (MAASP)? (THREE ANSWERS) a. The TVD of the last casing shoe. b. The maximum pump pressure. c. The mud weight in the hole. d. Viscosity and water loss of the mud. e. The fracture fracture pressure pressure of the formation formation at the shoe. shoe. f. The ID of of the last casing string.
14. When should MAASP be recalculated? recalculated? a. At the beginning of each shift. b. Immediately before entering a reservoir. c. After each bit change. d. After changing the mud weight.
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5- 7
15. (S) Which of the following would give the highest MAASP? a.
When formation formation breakdown pressure is much much higher higher than mud hydrostatic hydrostatic pressure.
b.
The casing shoe is set deep.
c.
When formation pressure is close to mud hydrostatic pressure.
d.
The casing shoe is set close to surface.
16. Which of the following have to be performed before taking a leak-off test? (THREE ANSWERS). a. Circulate the the mud to get same weight weight all the way around. around. b. Line up through through kill line and pump at the slow circulating circulating rate c. To prevent damage damage to the the formation, raise raise the bit bit up inside the shoe. d. Drill out the Casing Shoe and approximatel approximately y 15 ft into new formation.. e. To minimise chance of stuck pipe, raise raise the bit up inside the shoe.
17. Which of the following could influence the leak-off test result? (TWO ANSWERS). a.
Volume of mud in the well.
b.
The slow circulating rate (SCR).
c.
Having mud of different densities around the well.
d.
Maximum pressure mud pump can handle.
e.
Mud hydrostatic in the Annulus.
18. When should a leak-off test be carried out? a.
While waiting on cement to harden.
b.
After drilling drilling out Casing Casing Shoe 5 to 15 ft in new new formation.
c.
Before running casing.
d.
Before drilling out the Casing Shoe.
19. Which of the following conditions help to obtain an accurate formation strength at the shoe? (THREE ANSWERS). a.
Good pressure test of surface equipment.
b.
Working SPM gauge.
c.
Calibrated pressure gauges.
d.
Clean mud in well.
e.
Accurate measured depth of Casing Shoe.
f.
Accurate calculation of Annular Volume.
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5- 8
20. At what pressure does leak-off begin to take place in the graph below?
1200 e r u s s e r P p m u P
1000 800 600 400
V e r tit i c a l D e p t h = 8 5 0 0 f t . M u d W e ig i g h t = 1 2 .3 .3 p p g
200
V o lum e P u m p e d LOT Pressure = ……1000 ……1000…… …… psi 21. (S) Calculate the initial fracture pressure at the Casing Shoe using the leak-off plot below.
1400 1200 e r u s s e r P p m u P
1000 800 600 400
V e r ti t i c a l D e p t h = 8 7 6 0 f t.t . M u d W e ig i g h t = 1 1 .3 .3 p p g
200
V o lum e P u m p e d
Initial Fracture Pressure = ……6347 …… 6347…… …… psi
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5- 9
22. The Casing Casing Shoe has been drilled out out and 15 ft of new hole made. A leak-off test is to be carried out, but the mud in the wellbore wellbore is not the same density all round. round. Which of the following actions would give the most accurate leak off test results? a.
Stop the pump pump after after 10 barrels has been been pumped then read read the the drill drill pipe pipe pressure. pressure.
b. Condition the mud until mud density in the well is constant. constant. Then carry out the leak-off test. c. Pump at Slow Circulating Rate until fracture fracture pressure pressure is reached. reached. d. Pump down drill string at Slow Circulating Circulati ng Rate and read drillpipe pressure.
23. Which of the following is a definition of MAASP? a. The maximum pressure rating of the choke. b. The pressure pressure above mud mud hydrostatic that is likely likely to cause losses at the the shoe formation c. The pressure pressure at the shoe which causes losses. losses. d. The maximum bottom hole pressure allowed during a kill operation.
24. What happens to MAASP if the mud weight is increased? a. MAASP will increase. b. MAASP will decrease. c. MAASP will stay the same.
25. Which of the following increase the risk of exceeding MAASP during a well kill? (THREE ANSWERS). a. Short section of open hole. b. Large influx. c. Small influx. d. Large overbalance overbalance.. e. Small overbalance. f.
Long section of open hole.
26. Which of the following can affect MAASP. (THREE ANSWERS). a. Annular Volume. b. PH of the mud. c. Shoe Depth. d. Mud Weight. e. The maximum pressure the pump pump can handle. handle. f. The fracture pressure of the formation formation at at the Casing Casing Shoe. Shoe.
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5- 10
27. 9 5/8 inch inch casing set at 8900 8900 ft TVD. Formation strength strength at the shoe is 6350 6350 psi. Mud Weight is 11 ppg. Calculate MAASP? a.
5091 psi.
b.
1260 psi.
c.
3832 psi.
d.
685 psi.
F-12
28. When should MAASP be recalculated? a.
At top of the reservoir.
b.
After changing mud weight.
c.
Every 12 hours.
d.
At casing setting point.
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5- 11
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6-1
Section 6 Kill Methods
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6-2
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6-3
1. Which of the following statements are true? true? (TWO ANSWERS) a. The surface line volume (pump to Rig Floor) does not need to be considered when starting the kill. b. Bring pumps pumps must be brought up to speed holding holding the casing pressure pressure constant. constant. c. The surface line volume volume will affect affect the time at at which the kill mud will will increase increase bottom hole pressure. d.
Maintain the drill pipe pressure pressure constant constant when bringing the pumps pumps up to kill speed. speed.
2. When is Shut In Casing Pressure used used in well control. control. a. To calculate the slow circulating rate. b. To calculate kill mud weight. c. To maintain maintain bottom hole pressure pressure constant constant during during pump start up.
3. With a surface BOP what what will happen if, when bringing bringing the pumps up to kill speed, the casing pressure is allowed to increase above Shut In Casing Pressure? a. No change to downhole pressure. b. Downhole pressure would decrease and possibly cause more influx to enter the wellbore. c. Downhole pressure would increase and may exceed formation fracture fracture..
4. WELL DATA Slow circulation rate pressure
400 psi at 40 spm
The well has been shut in after a kick: Shut In Drill Pipe Pressure
300 psi
Shut In Casing Pressure
700 psi
Circulation is started with the original mud. While the pump is being brought up to 40 spm which pressure must be held constant to maintain the correct bottom hole pressure? a. 1,000 psi at the casing gauge. b. 700 psi at the casing gauge. c. 700 psi at the drill pipe gauge. d. 1100 psi at the drill pipe gauge.
5. During a kill operation operation the choke choke is adjusted to increase increase drill pipe pressure pressure by 100 psi. SPM is held constant. What will happen to the casing shoe pressure? a.
It will decrease.
b.
It will remain constant.
c.
It will increase.
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6-4
6. Whilst drilling a horizontal well well a fault is crossed crossed and a kick is taken. taken. The well is shut shut in. Calculate the mud weight required to kill t he well using the data below: WELL DATA
MD
TVD
Depth at start of horizontal
7,690 feet
6,100 feet
Depth at time of kick
11,000 feet
6,140 feet
Length of horizontal section
3,310 feet
Mud weight
11 ppg
KICK DATA Shut In Drill Pipe Pressure
150 psi
Shut In Casing Pressure
170 psi
……11.46……. ……. ……11.46
ppg
7. In a well with a long open hole section, which of the following kill methods will minimise the risk of losses? a. Bullheading Bullheading Method. b. Driller’s Method. c. Wait and Weight Method. d. Volumetric Method.
8. When killing a well what will will happen to the mud mud pit volume as the gas is circulated circulated up the hole? a. It will increase. b. It will stay the same. c. It will decrease.
9. What is surface pit volume volume most likely likely to do as a gas kick is is being circulated circulated up the hole? hole? a.
Increase.
b.
Stay the same.
c.
Decrease.
10. (S) A gas kick is being circulated out using the Drillers Method. Method. What will happen to the bottom hole pressure if the gas bubble is not allowed to expand as it is circulated up the hole? a.
It will increase.
b.
Stay the same
c.
It will decrease.
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11. Which method removes the influx from the hole before pumping kill mud? a. Wait and Weight Method. b. Driller’s Method.
12. Which method maintains drill pipe pressure constant for the first circulation? a.
Wait and Weight Method.
b.
Driller’s Method.
13. When operating the choke there is normally a time delay before the drillpipe pressure changes. What is the ‘rule of thumb’ for this time delay in pressure transmission from choke to drillpipe gauge? a.
3 – 5 seconds
b.
750 feet/minute
c.
1 minute per 1000 feet of travel
d.
1 second per 1000 feet of travel
14. (S) The Driller’s Method is used to kill a salt-water kick. What will happen to the casing pressure when the influx moves up the annulus? a.
Casing pressure will slowly slowly decrease decrease as as influx influx is circulated up the annulus.
b.
Salt water water will will behave behave in the same way as as a gas influx. influx.
c.
As influx expands Casing Pressure will increase.
d.
Casing pressure will only change due to changes in annular size.
15. When killing a vertical well when is Final Circulating Pressure reached? a.
When kill mud reaches the casing shoe.
b.
When the influx is out of the hole.
c.
When kill mud reaches the bit.
d.
When starting to pump pump kill kill mud mud down down the drill string.
16. Which kill method pumps kill mud at the same time as circulating the influx up the annulus? a. Wait and Weight Method. b. Driller’s Method.
17. Which kill method minimises the pressure in the annulus caused by gas expansion? a. Wait and Weight Method. b. Driller’s Method.
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18. A kill operation operation is ready to start. The Wait and Weight Method is to be used. used. The kill mud is ready to be pumped. It takes 100 strokes to displace surface surface lines. What is the correct procedure? a. Ignore the 100 strokes. strokes. It will not affect the drill pipe pressure pressure schedule, schedule, and and may give an added safety factor. b. Subtract the 100 100 strokes from from the surface to bit strokes and re-calculate re-calculate the drill pipe pressure schedule. c. Re-Zero stroke counter counter after after 100 strokes are are pumped. pumped.
19. A kick is shut in and is to be killed using the Wait and Weight Method. Pre-recorded data:Vertical depth of well
11,000 feet
Total string volume
1,900 strokes
Total annulus volume
13,300 strokes
Slow pump rate data: At 25 SPM
300 psi
Kick data:Shut In Drill Pipe Pressure
550 psi
Shut In Casing Pressure
650 psi
Mud weight in the well
11.0 ppg
Calculate the kill mud weight? ……11.96……. ……. ……11.96
ppg
F-14
20. A kick is shut in and is to be killed using the Wait and Weight Method. Pre-recorded data:Vertical depth of well
11,000 feet
Total string volume
1,900 strokes
Total annulus volume
13,300 strokes
Slow pump rate data: At 25 SPM
300 psi
Kick data:Shut In Drill Pipe Pressure
550 psi
Shut In Casing Pressure
650 psi
Mud weight in the well
11.0 ppg
What is the Initial Circulating Pressure Pressure (ICP) at 25 SPM? ……850……. ……. ……850
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psi
6-7
21. A kick is shut in and is to be killed using the Wait and Weight Method. Pre-recorded data:Vertical depth of well
11,000 feet
Total string volume
1,900 strokes
Total annulus volume
13,300 strokes
Slow pump rate data: At 25 SPM
300 psi
Kick data:Shut In Drill Pipe Pressure
550 psi
Shut In Casing Pressure
650 psi
Mud weight in the well
11.0 ppg
What is the Final Circulating Pressure (FCP) at 25 SPM? ……326……. ……. ……326
psi
22. A kill operation operation is ready to start. The Wait and Weight Method is to be used. used. Kill mud is ready to be pumped, but it takes 10 bbls to fill the surface lines. What is the correct procedure? a. Subtract the 10 10 bbls (converted (converted to pump pump strokes) from the total strokes strokes to be pumped. b. Ignore it. Start the kill operation. It will not affect affect your your drill drill pipe pipe pressure pressure schedule. c. Re-zero stroke counter counter when kill mud reaches the drill pipe. pipe.
23. (S) Kill mud is being circulated circulated down the drill string in a horizontal horizontal well. The pumps are stopped and the well is shut in as the kill mud reaches the start of the horizontal section (2000 ft. long). What would you expect the Shut In Drill Pipe Pressure to be? a.
Zero.
b.
The same as the slow circulation rate.
c.
The same as the original Shut In Drill Drill Pipe Pressure.
d.
The same as the Shut In Casing Pressure.
e.
Original SIDPP less the hydrostatic of 2000 2000 ft of mud.
24. A gas kick is being circulated out using the Wait and Weight Method. What will happen to the bottom hole pressure if spm is increased whilst holding casing pressure constant? (Ignore pressure losses in the annulus). a.
Stay the same.
b.
Increase.
c.
Decrease.
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25. What will happen if we ignore a large surface line volume (from the mud pumps to the drill floor)when preparing a kill sheet for a Wait and Weight Method kill? (TWO ANSWERS) a.
The drill drill pipe pressure schedule will result result in a bottom hole pressure pressure that is too low. low.
b.
The total time to kill the well will be shorter than calculated.
c.
The total time to kill kill the well well will be longer than calculated.
d.
The drill drill pipe pressure schedule will result result in a bottom hole pressure pressure that is too high. high.
e.
There will be not effect on the bottom hole pressure.
26. (S) In a well with a long open hole section, which of the following kill methods will minimise the risk of losses? a.
Bullheading Bullheading Method.
b.
Driller’s Method.
c.
Wait and Weight Method.
d.
Volumetric Method.
27. (S) A kick is being circulated out at 50 spm. Drill pipe pressure reads 850 psi and casing pressure 1,150 psi. It is decided to slow the pumps to 30 spm while maintaining maintaining 1,150 psi on the casing gauge. How will this affect bottom hole pressure (exclude any annular friction losses)? a.
Increase.
b.
Stay the same same..
c.
Decrease.
28. Kill mud is pumped to the bit holding drillpipe pressure constant. What is the effect on bottom hole pressure? a. Stay the same. b. Decrease. c. Increase.
29. (S) During a kill pump speed is increased from 20 to 40 spm whilst holding drill pipe pressure constant. What will happen to bottom hole pressure? a. It will stay the same. b. It will increase. c. It will decrease.
30. (S) If pump speed is increased whilst killing a well, what should happen to the casing pressure to maintain constant bottom hole pressure? a.
Casing pressure should be held steady during spm increase.
b.
Casing pressure should be allowed to rise during spm increase.
c.
Casing pressure should be allowed to fall during spm increase.
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31. (S) A well is being killed using the Driller’s Driller’s method. The drill pipe pressure pressure is 950 psi at 35 spm. Due to increasing pressure inside the mud/gas separator it is decided to reduce the pump speed to 25 spm. What is the effect on bottom hole pressure if 950 psi is held on the drill pipe gauge while the pump rate is reduced? a.
Bottom hole pressure will decrease.
b.
Bottom hole pressure will increase.
c.
Bottom hole pressure will stay the same.
32. (S) During a kill the pump rate is reduced whilst holding casing pressure constant. How will this affect bottom hole pressure? a.
There is no way of of knowing knowing the effect effect on bottom hole pressure.
b.
There will be a large drop in bottom hole pressure.
c.
Bottom hole pressure will increase and may cause formation formation breakdown.
d.
Bottom hole pressure will stay constant.
33. (S) A kick is being circulated out at 30 spm and the Final Circulating Pressure is 650 psi. What will happen to the bottom hole pressure if the pump speed is increased to 35 spm whilst holding drill pipe pressure at 650 psi? a.
It will decrease.
b.
It will stay the same.
c.
It will increase.
34. (S) When starting a kill operation on a Jack Up, the choke pressure is kept constant whilst bringing the pump up to speed. The drill pipe gauge reads 150 psi higher than the calculated Initial Circulating Pressure (ICP). What is the correct action to take? a.
There will now be 150 psi overbalance on the bottom. Nothing Nothing needs needs to be done.
b.
Continue to circulate with the new ICP and adjust adjust the drill drill pipe pressure graph.
c.
Open the choke and let let the standpipe pressure drop to the calculated value (ICP).
35. Due to a power failure, it is not possible to start the kill operation and both drill pipe and casing pressure readings readings are increasing increasing at the same rate due to gas migration. The bit is on bottom. Which pressure must be kept constant to maintain constant bottom hole pressure? a.
Casing shoe pressure.
b.
Influx pressure.
c.
Shut In Casing Pressure.
d.
Shut In Drill Pipe Pressure.
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36. During top hole drilling drilling from a jack-up rig, the well starts to flow due to shallow gas. What will be the safest action to take to secure the safety of the rig and personnel? (TWO ANSWERS) a.
Line up up to the mud/gas mud/gas separator, separator, close close the diverter and send send personnel personnel to the lifeboats.
b.
Start pumping pumping mud into the well at the highest possible rate.
c.
Shut in the well and prepare to bullhead immediately.
d.
Shut in the well using the blind/shear rams.
e.
Activate the the diverter diverter system and remove remove non-essential non-essential personnel from the rig floor. floor.
37. If a shallow gas flow flow is detected, which which of the following following should be taken taken at the same time as activating the diverter? a.
Maintain pump rate.
b.
Increase pump rate.
c.
Decrease pump rate.
38. For each of the following statements, note if it relates to either the Wait and Weight method or the Driller’s Driller’s Method . Tick the appropriate appropriate space. a.
Maintain Drill Pipe pressure constant for 1st circulation.
b.
Driller’s
Wait and Weight
Driller’s
Wait and Weight
Remove influx from hole before pumping kill mud.
e.
Wait and Weight
Pump kill mud whilst circulating influx up the Annulus.
d.
Minimise pressures in the Annulus due to gas expansion.
c.
Driller’s
Driller’s
Wait and Weight
Hold Casing Pressure constant as kill kill mud mud is pumped to the bit. Driller’s
Wait
and Weight
39. Which of the following statements are true when starting up to kill a well? (TWO ANSWERS). a. Maintain the Drill Pipe Pressure constant constant when bringing the the pumps up up to kill speed. speed. b. The Surface line volume volume (pump to rig floor) will will affect the time at which kill mud starts to increase mud hydrostatic. c. Bring pumps pumps up to speed holding casing pressure pressure constant. constant. d. The Surface line volume volume (pump to rig floor) will will not need need to be considered considered during start up.
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40. When circulating circulating up a gas influx, what will happen to the pit volume while the gas is still in the hole? a. It will stay the same. b. It will decrease. c. It will increase. 41. Ready to kill well well using Wait and Weight method. method. It takes 100 strokes to pump kill mud to the rig floor. floor. What action has to be taken? a.
Re-zero stroke counter after 100 strokes are pumped.
b.
Add the 100 strokes to the the bit bit to surface strokes.
c.
Ignore the 100 strokes. It will will not affect the drill pipe pressure graph.
42. Which of the following kill techniques will minimise risk of losses. a.
Bullheading Bullheading Method.
b.
Driller’s Method .
c.
Wait and Weight Method.
d.
Volumetric Method.
43. (S) Which of the following actions would minimise pressure on the open hole? (THREE ANSWERS). a. Slower pump rate to kill kill well. b. Use the Wait and Weight Method. c. Use the Driller’s Method. d. Shut-in early to minimise minimise kick size.
44. During a kill operation, there is a time delay between operating the choke and observing a change in the Drill Pipe Pressure. Pressure. This delay is approximately: approximately: a. 1 second second per 1000 ft of hole length. length. b. 5 to 10 seconds. c. 5 to 10 minutes. d. 750 feet per minute.
45. If a kick occurs while drilling a horizontal well, why is there little or no difference between SIDPP and SICP? a. In horizontal horizontal wells, the influx is not able able to migrate. b. Mud density and and formation fluid density are the same same when drilling drilling horizontal horizontal wells. c. Volume inside the string is the same as volume in the Annulus. d. The vertical height of the influx has little effect on the hydrostatic head in the the Annulus.
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46. (S) A gas kick is being circulated out. What will happen to the bottom hole hole pressure in the three situations below? below? (Assume no pressure loss loss in the Annulus). I. If drill pipe pipe pressure is held constant constant when when kill mud is being pumped to the bit? a. Stay the same. b. Increase. c. Decrease. II. If the gas influx influx is not allowed allowed to expand as it migrates up up the hole? hole? a. Stay the same. b. Increase. c. Decrease. III. If SPM is increased increased holding holding casing pressure pressure constant? a. Stay the same. b. Increase. c. Decrease. 47. A kick is taken while drilling drilling a horizontal well. well. Using the data below, below, calculate the kill mud weight. Well Data: Measured depth at start of horizontal section
:
6,500 ft
Measured depth at time of kick
:
10,500 ft
True vertical depth at start of horizontal
:
4,050 ft
True vertical depth at time of kick
:
3.970 ft
Length horizontal section
:
4,000 ft
Drilling fluid density
:
11.2 ppg
Shut-in drill pipe pressure
:
150 psi
Shut-in casing pressure
:
150 psi
Kick Data:
……11.9……. ……. ……11.9
ppg
F-14
48. During a kill operation, operation, minor losses losses are experienced. experienced. What could you do to reduce the pressure at the loss zone? a. Reduce mud viscosity. b. Stop circulation circulation and and shut in the well. well. Allow the influx to migrate to surface using using the Volumetric Method. c. Reduce pump pump speed and keep bottom hole pressure as close to formation formation pressure pressure as possible.
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49. (S) When using the Driller’s Method, what must happen to the casing pressure when pumping kill mud to the bit? a. Must be held constant. b. Must be allowed to increase. c. Must be allowed to decrease. d. It is impossible to say.
50. (S) A well is being killed using the the Driller’s method. method. Original Shut In Drill Pipe Pressure
= 600 psi
Original Shut In Casing Pressure
= 900 psi
After the first circulation, circulation, the well is shut shut in and the pressures pressures read: Shut In Drill Pipe Pressure
= 600 psi
Shut In Casing Pressure
= 700 psi
It is decided not to spend any more time cleaning the hole. Which of the following actions should be taken? a. Continue with with second circulation circulation of of Driller’s method, holding holding casing pressure constant until kill mud reaches the bit. b. Bullhead annulus until until Shut In Casing Casing Pressure Pressure is reduced reduced to 600 psi. c. Use Volumetric technique to remove remove remaining remaining influx. d. Continue with the second circulation circulation of Driller’s Driller’s method, following following a calculated calculated drill pipe pressure schedule as kill mud is pumped to the Bit.
51. (S) A (S) A gas kick is being circulated out using the Wait and Weight Method. What will happen to the bottom hole pressure if drill pipe pressure is held constant when kill mud is being pumped to the bit? a. Stay the same. b. Decrease. c. Increase.
52. (S) When (S) When circulating a gas kick from a well using the Driller’s Method, what happens to the casing shoe pressure as the influx is circulated past the shoe? a. The casing shoe pressure pressure will will decrease. decrease. b. The casing shoe pressure pressure will remain remain stay the same. c. The casing casing shoe shoe pressure pressure will will increase. increase.
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53. (S) (S) On On a land rig a salt-water kick is circulated out using the Driller’s Method. When will the surface casing pressure be at it maximum value? (TWO ANSWERS) a.
When the kill kill mud mud is pumped into the the drill drill pipe. pipe.
b.
When the kick reaches the casing shoe.
c.
When the kick has been circulated to the the surface. surface.
d.
When the kill mud reaches the bit.
e.
Immediately after the well has been shut in.
f.
When the kick is in the narrowest annulus
54. (S) If a kick is shut in on a surface BOP stack and the slow circulating rate pressures is not known. What procedure should be used to obtain the correct Initial Circulating Pressure? a. Only use the Driller’s Method. Method. As the drill pipe pressure pressure does not change during the entire circulation it is only required to observe that the drill pipe pressure remains constant and equal to the Shut In Drill Pipe Pressure. b. When starting to kill kill the well, keep the choke pressure pressure as close as as possible to the Shut In Casing Pressure. Pressure. When the selected kill kill pump rate has been reached, reached, read the drill pipe pressure and use that as the Initial Circulating Pressure. c. Check the records records and choose the kill rate circulating circulating pressure taken with the last last BHA in the hole nearest to the depth where where the kick took place. Add 100 psi to this value as a precautionary measure. d. Contact the mud logger logger and request request the best possible possible calculation calculation of the Initial Circulating Pressure intended intended for use during the well kill.
55. (S) Which (S) Which of the following statements is true? a. The Wait and Weight Method should always be used because the pressure against the open hole will always be lower than when using the Driller’s Method. b. If the kill mud enters the the annulus before before the kick reaches reaches the shoe then the Wait and Weight Method will reduce the risk of formation breakdown breakdown compared to the Driller’s Method. c. There is no difference difference between using the Driller’s Driller’s Method or the the Wait and Weight Weight Method.
56. (S) While (S) While circulating out a gas kick, when is it possible for the pressure at the casing shoe to be at its maximum? (TWO ANSWERS) a. When kill mud reaches reaches the casing shoe. b. At initial shut in. c. When kill mud mud reaches reaches the bit. bit. d. When top of of gas reaches reaches the casing shoe.
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57. (S) (S) When When circulating out a kick in a deep well the casing pressure approaches the MAASP while the influx is still in the open hole. Which is the MOST IMPORTANT action to take? a. Minimise any extra pressure in the annulus without allowing bottom hole pressure to fall below pore pressure. b. Keep the casing pressure pressure at MAASP by opening the choke. c. Start pumping mud down the drillstring drillstri ng at 1 ppg higher than needed to kill.
58. (S) At what stage during a kill operation can choke pressure reading exceed MAASP without breaking down the formation at the shoe? a.
When the influx is in the open hole section.
b.
When the influx is on bottom.
c.
When the kill mud is at the bit.
d.
When the influx is above the casing shoe.
59. (S) Which of the following statements are true for the Casing Shoe? a.
The Wait and Weight Weight Method will always always give a lower pressure on the casing shoe shoe than the Driller’s Method.
b.
The Driller’s Driller’s Method will give the lowest casing shoe shoe pressure pressure when the open hole annulus volume is larger than the drill string volume.
c.
The Wait and Weight Method will give the lowest casing shoe pressure when the open hole volume is greater than the drill string volume.
d.
The Wait and Weight Weight Method will give give the lowest lowest casing casing shoe pressure when the open hole annulus volume is smaller than the drill string volume.
e.
The casing casing shoe pressure will always always be the same, same, regardless regardless of the method used. used.
60. (S) Which of the following is correct when comparing the Driller’s Method with the Wait and Weight Method? a.
The Wait and Weight Weight Method should always always be used because because the pressure against against the open hole will always be lower.
b.
It the kill mud is being circulated circulated up up the annulus before the kick has reached the shoe, then the Wait and Weight Method will reduce the risk of lost circulation.
c.
There is no difference difference between between using the Driller’s Driller’s Method Method or the Wait and Weight Method.
61. (S) A kick was detected whilst drilling ahead and the well shut in. The long open hole section has a number of formations that are potential lost circulation zones. Which of the following methods should be used to minimise the well bore pressure in the open hole? a.
Volumetric Method.
b.
Driller’s Method.
c.
Wait and Weight Method.
d.
Bullheading.
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62. (S) In which of the following situations will the Wait and Weight Method give lower casing shoe pressures than the Driller’s Method? a.
Casing shoe shoe pressure pressure is always lower lower when using the Wait and Weight method. method.
b.
Drill string volume less than annulus open hole volume.
c.
Drill string volume greater than annulus open hole volume.
63. (S) The pump is brought up to kill rate holding holding the casing pressure constant. constant. The drill pipe gauge reading was 150 psi above calculated Initial Circulating Pressure. What action should be taken? a. Open choke to reduce drill pipe pipe pressure back to the calculated calculated Initial Circulating Circulating Pressure. b. Shut down and clean out choke manifold or change to another choke. c. Carry on, everything everything is OK. d. Recalculate circulating pressure schedule based on actual drill pipe gauge reading.
64. (S) A well is being killed using the Drillers Method. Original SIDPP
= 750 psi
Original SICP = 1000 psi
After the first circulation, circulation, the well is shut shut in and pressure pressure allowed allowed to stabilise. They read:SIDPP
=
750 psi
SICP = 850 psi
It is decided not to spend anymore time circulating. Which one of the following actions should be taken? a. Use the Wait and Weight Method b. Bullhead to reduce SICP to 0 psi c. Continue with with second circulation circulation of Drillers Drillers Method (holding (holding Casing Pressure Pressure constant until kill mud reaches the bit) d. Reverse circulate circulate to reduce reduce pressures pressures to 0 psi psi
65. (S) When using the Driller’s Driller’s Method , what should happen happen to the Casing Pressure as kill kill mud is pumped to the Bit? a. Stay the same. b. Decrease. c. Increase.
66. (S) Final Circulating Circulating Pressure (FCP) (FCP) is maintained constant: a. Once influx influx is out out of the well. b. While pumping pumping bottoms up after kill kill mud has passed passed the bit. c. Once kill mud mud reaches the Casing Shoe. d. When pumping pumping kill mud mud down to the bit.
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67. (S) In which of the following situations situations will the Wait and Weight Weight method give lower Casing Shoe pressure, compared to Driller’s Method? a. Annulus open open hole capacity capacity is less than drillstring drillstring capacity. capacity. b. Annulus open hole capacity capacity is greater than drillstring capacity. c. Wait and Weight will always always give lower Casing Shoe Shoe pressures. 68. (S) When pumping kill mud to the bit in high angle wells, the stand pipe pressure is always? a.
Lower than in a vertical well with the same measured depth.
b.
Higher than in a vertical well with the same measured depth.
c.
The same as in a vertical well with the same measured depth.
69. (S) Which of the following would give lower annulus pressures in a long open hole section? (THREE ANSWERS) a.
Use the Driller’s Method.
b.
Use the Wait and Weight Method.
c.
Use a slower pump rate to kill the well.
d.
Minimise the amount of influx.
70. (S) What are the correct actions that can be taken taken to minimise pressure in the annulus annulus during the kill operation? (TWO ANSWERS) a.
Use the Wait and Weight Method.
b.
Choose a lower pump rate.
c.
Choose a higher pump rate.
d.
Maintain extra back-pressure on the choke for safety.
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7-1
Section 7 Kill Problems and Bad practices
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7-2
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7-3
1. (S) During the first circulation circulation of the Driller’s Method, Method, the mud pump develops a leak. leak. If the choke operator maintains constant drill pipe pressure, what will happen to bottom hole pressure? a.
It will increase.
b.
It will stay constant.
c.
It will decrease
2. If the drill pipe is plugged plugged and SIDPP SIDPP cannot be read, read, which of the following following parameters parameters cannot be calculated? (TWO ANSWERS) a.
Shoe pressure.
b.
Formation fluid pressure.
c.
Hydrostatic pressure.
d.
Fracture pressure.
e.
Kill Mud Weight.
3. After a kick the Drill pipe pipe pressure and and Casing pressure pressure start to build build up, but before stabilising they suddenly suddenly drop. Which of the following situations situations may have occurred? occurred? a.
A weak formation has broken down.
b.
Wash out in the drill string.
c.
Problem with the gauges.
d.
Annulus has packed off.
e.
Salt water influx is migrating up the hole.
f.
Size of influx.
4. Choke is adjusted to increase increase Drill Pipe pressure pressure by 150 psi (SPM held constant). What will happen to the following following pressures? (Tick appropriate appropriate space provided). a.
Casing Shoe Pressure:
b.
Decrease
Remain Constant
Increase
Decrease
Remain Constant
Increase
Decrease
Remain Constant
Bottom Hole Pressure:
c.
Increase
Choke Pressure:
5. (S) When SPM is increased during during a kill, what should happen happen to casing pressure to keep bottom hole pressure steady? a.
Casing pressure should be allowed to increase.
b.
Casing pressure should be allowed to decrease.
c.
Casing pressure should be held steady.
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6. How would choke plugging be recognised during a kill operation? a.
Decrease in pump pump pressure pressure with with no change to casing pressure.
b.
Continually opening the choke choke to maintain correct circulating circulating pressure.
c.
Decrease in casing pressure with no change to pump pressure.
d.
Continually closing the choke choke to maintain correct circulating circulating pressure.
7. (S) The well is shut-in shut-in with the following following pressure readings: Shut-in casing pressure
:
0 psi
Shut-in drill pipe pressure
:
435 psi
The annulus is observed through the choke, and there is no flow. What will be the diagnosis? a.
The well was swabbed in.
b.
The hole is packed off around BHA.
c.
The formation at the shoe has been fractured.
d.
The drill string has twisted off.
e.
The choke gauge failed.
8. (S) During a kill operation, operation, it is recognised that there is a small loss loss of drilling fluid to the formation. Which of the following actions has to be performed in order to reduce the pressure at the weak zone? a.
Reduce the viscosity in the kill fluid circulated.
b.
Reduce the drilling drilling fluid pump pump speed or change change to the cement pump for a reduction in the flow rate and keep the bottom hole pressure as close as possible to pore pressure.
c.
Stop circulation and shut-in the hole. Let the influx come to the the surface surface by migration migration while the bottom hole pressure is controlled by use of the Volumetric Method.
9. How can a washout washout at the choke be recognised? a.
Drill pipe and casing pressures both falling.
b.
Increase in casing pressure pressure but but drill pipe pipe pressure pressure does not change. change.
c.
Drill pipe and casing pressures both rising.
d.
Increase in drill pipe pressure but casing pressure does not change.
10. Kill rate rate is 35 SPM. Pump Pressure = 700 700 and Casing Casing Pressure = 1000. 1000. Pump speed is decreased to 25 SPM holding holding 1000 psi on Casing. Casing. How will this affect bottom hole hole pressure (ignore any ECD effect). a.
Decrease.
b.
Stay the same.
c.
Increase.
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11. (S) When circulating out out a kick, the Casing pressure approaches approaches MAASP while influx influx is still in the open hole. What should be be done? a.
Operate choke to prevent prevent pressure exceeding MAASP.
b.
Minimise any extra pressure in the annulus annulus without without going underbala underbalance. nce.
c.
Start pumping extra heavy mud down the drill string.
12. (S) What is the effect on bottom hole pressure if the following following actions are taken during during a well kill? a.
If SPM is increased increased from from 20 to 30 whilst holding drill pipe pipe pressure pressure constant: constant:
b.
Increase
Decrease
Stay the same
Kill Mud Mud is pumped to the bit while while holding holding drill drill pipe pipe pressure pressure constant: constant:
Increase
Decrease
Stay the same
13. (S) Kick is taken in a horizontal horizontal well. well. SIDPP = SICP. Influx is circulated out using Driller’s Method. When influx is circulated out out of the horizontal section and and into the more vertical section, the Casing pressure increase quite rapidly, why? a.
ECD is much greater in the horizontal section.
b.
This is because kill mud was not pumped from the start start of the kill.
c.
This is normal for any well when when Driller’s Driller’s Method Method is used.
d.
There is no loss of hydrostatic hydrostatic head until gas arrives arrives at the inclined inclined or vertical section section of the well.
14. (S) Pump speed is increased increased during a kill and bottom hole hole pressure is kept constant. constant. What should happen to pump pressure? a. Pump pressure should rise. b. Pump pressure pressure should stay the same. same. c. Pump pressure should fall.
15. (S) During a well kill operation, operation, the choke operator operator notices that both drill pipe and casing casing pressures are slowly slowly decreasing. He reacts by adjusting the choke choke to maintain the original pump pressure. What effect does this choke adjustment have on the bottom hole pressure? a.
Bottom hole pressure decreases.
b.
Bottom hole pressure is returned to correct correct value.
c.
Bottom hole pressure is not not affected by choke choke adjustment. adjustment.
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16. (S) When stripping into the hole hole which of the following will will maintain a constant bottom bottom hole pressure? pressure? (Assume there is no influx migration). migration). a.
Bleed off the drill pipe closed closed end displaceme displacement nt while stripping each stand. stand.
b.
Pump a volume of mud into the well equal to the drill pipe closed end displacement while stripping each stand.
c.
Bleed off the drill pipe pipe steel steel displacement displacement while while stripping stripping each each stand. stand.
d.
Pump a volume of mud into the well equal to the drill pipe steel displacement while stripping each stand.
17. 5-inch drill pipe is stripped into the hole through the Annular Preventer. Average length of a stand
93 feet
Drill pipe inside capacity
0.0177 bbls/ft
Closed end displacement displacement
0.0253 bbls/ft
Metal displacement displacement
0.0076 bbls/ft
For each stand of pipe stripped, how many barrels of mud must be pumped to keep the drillstring full? ……1.6……bbls ……bbls ……1.6
18. (S) Well kicks after 25 stands stands have been pulled out of the hole. Shut In Casing Pressure = 100 psi Shut In Drillpipe Pressure = 100 psi Which of the following would be the best action to take to return to primary control? a.
Circulate the kick out using using the Wait Wait & Weight Weight Method whilst keeping keeping drill drill pipe pressure constant at the Shut In Drillpipe Pressure.
b.
Strip back to bottom using the combined Stripping and Volumetric Volumetric Method, Method, then circulate the influx out using Driller’s Method.
c.
Increase mud mud weight weight by 100 100 psi and circulate circulate this heavy mud with the bit 25 stands off bottom.
19. 5-inch drill pipe is stripped into the hole through the Annular Preventer. Average length of a stand
93 feet
Drill pipe inside capacity
0.0178 bbls/ft
Closed end displacement displacement
0.0252 bbls/ft
Metal displacement displacement
0.0076 bbls/ft
For each stand of pipe stripped, how many barrels of mud must be bled off from the annulus? ……2.3……bbls ……bbls ……2.3
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20. After pulling 40 stands the well starts to flow and is shut in. Well Data: Well depth
= 11,000 feet
9-5/8 inch casing shoe
= 7,000 feet
8-1/2 inch hole capacity
= 0.702 bbls/ft
Mud weight Drill Collar length
= 11 ppg = 450 feet
5” Drill pipe
-Capacity
= 0.0077 bbls/ft
-Metal displacement displacement
= 0.033 bbls/ft
-Capacity
= 0.0178 bbls/ft
-Metal displacement displacement
= 0.0075 bbls/ft
Capacity drill collar/open hole
= 0.0292 bbls/ft
Capacity drill pipe/open hole
= 0.0459 bbls/ft
Capacity drill pipe/casing
= 0.0515 bbls/ft
The bit depth at time of kick
= 7,280 feet
Shut In Casing Pressure
= 150 psi
Influx volume
= 15 bbls
The influx is on bottom and is NOT migrating. a. Calculate the volume volume to bleed off per 93 feet of drill pipe stripped back into into the hole? ……2.35……bbls ……bbls ……2.35 b. What will happen to the bottom hole pressure if too much mud is bled off whilst stripping back to bottom?
Increase
Decrease
Stay the same
c. What is likely to happen to casing pressure as the drill string is stripped into the influx?
Increase
Decrease
Stay the same
21. (S) When stripping into the hole hole which of the following will will maintain a constant bottom bottom hole pressure? pressure? (Assume there is no influx migration). migration). a.
Bleed off the drill pipe closed closed end displaceme displacement nt while stripping each stand. stand.
b.
Pump a volume of mud into the well equal to the drill pipe closed end displacement while stripping each stand.
c.
Bleed off the drill pipe pipe steel steel displacement displacement while while stripping stripping each each stand. stand.
d.
Pump a volume of mud into the well equal to the drill pipe steel displacement while stripping each stand.
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22. (S) Well has kicked kicked when 30 Stands off bottom. Shut-in pressures pressures both equal equal 150 psi. Which of the following is the best action to take to restore primary control? a. Strip to bottom and circulate well well using Driller’s Method. b. Circulate kick kick out while while 30 stands stands off bottom using using the Driller’s Driller’s Method. Method. c. Raise mud weight by 150 150 psi and circulate out using Wait and and Weight Method. 23. (S) What is the correct action to take when when stripping in the hole? hole? Assume that there is no influx migration? a. Strip in until until Casing Pressure equals equals MAASP then then bleed off off each stand to keep Casing Pressure constant. b. Bleed off the Drill Pipe Pipe capacity capacity each each stand c. Bleed off the Drill Pipe closed closed end displacemen displacementt each stand. d. Bleed off the Drill Pipe steel steel displacement displacement each each stand.
24. During a trip out, the well well kicks due to swabbing. The pipe is stripped back back to bottom. Will the original mud weight be sufficient to control the well? a. Yes b. No 25. Drill pipe is is to be stripped in the hole. There is a float valve in the string. Average Stand length length
=
93 ft
Drill pipe capacity
=
0.0346 bbls/ft
Closed end displacement displacement
=
0.0438 bbls/ft
Metal displacement
=
0.0092 bbls/ft
For each stand stripped, calculate: a. Volume of mud to bleed from Annulus.
………4.07……….bbls ……….bbls ………4.07
b.
………3.2……….bbls ……….bbls ………3.2
Volume of mud to keep the pipe full.
26. If gas is migrating and you are unable to start the kill operation, which pressure should be held constant to maintain a constant bottom hole pressure? a.
Shut-In Casing Pressure.
b.
Casing Shoe Pressure.
c.
Influx Pressure.
d.
Shut-In Drill Pipe Pressure.
27. When stripping to bottom, which of the following actions should be taken? a.
Bleed off a volume of mud equal to 100 psi of hydrostatic head.
b.
Bleed off a volume of mud equal to the closed end displacement of the pipe stripped into the well.
c.
Bleed off off a volume volume of mud mud equal to the metal displacement displacement of the pipe pipe stripped stripped into the well.
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28. Shoe at
= 6,000 ft
TVD at
=
9,000 ft
Collar Capacity Collar Displacement Displacement Collar Length
= = =
0.0077 bbls/ft 0.033 bbls/ft 1000
Pipe Capacity Pipe Displacement Displacement
= =
0.0178 bbls/ft 0.0082 bbls/ft
Pipe to Casing Annulus = Pipe to Open Hole = Collars to Open Hole =
Mud Weight
=
11.4 ppg
0.052 bbls/ft 0.046 bbls/ft 0.029 bbls/ft
Well starts to flow after 50 stands pulled. Shut-in Data is:Bit Depth = 4350 ft Influx = 38 bbls SICPP = 400 psi Influx Gradient = 0.12 psi/ft Answer the following following question question (assume no gas migration). a. Calculate the volume volume to bleed bleed off to strip back to bottom ? ……121…… …… ……121
bbls
b. What will happen happen to bottom hole hole pressure if too much much mud is bleed off? (Tick appropriate space provided).
Increase
Decrease
Stay the same
c. What will happen happen to bottom bottom hole pressure if too too little mud mud is bled off? (Tick appropriate space provided).
Increase
Decrease
Stay the same
d. What should happen happen to Casing Casing Pressure as string string is stripped into into influx? (Tick appropriate space provided).
Increase
Decrease
Stay the same
29. A well is being killed at 30 spm using the Driller’s Method. Halfway through this first circulation the choke operator observes a sudden increase in drill pipe pressure. The choke pressure and pump speed have not changed. What could have happened? (TWO ANSWERS) a. There is a blockage in the standpipe manifold. b. The bit nozzles have partly plugged. c. The kick is about about to enter enter the choke. choke. d. The choke has partly plugged. e. The mud/gas separator separator is plugged plugged with cuttings.
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30. (S) Using the Drillers Method to circulate out the influx the circulating pressure 1,000 psi The circulating pressure increases rapidly to 1,400 psi (pump speed remains constant). It is decided that a bit nozzle has plugged. plugged. Which of the following will maintain constant bottom hole pressure? a. Maintain the circulating pressure pressure at 1,400 1,400 psi and and the pump pump speed constant. constant. b. Adjust the circulating pressure to 1,000 psi by by changing the pump speed. c. Stop the pump pump and shut shut the well in. Re-calculate Re-calculate Initial Circulating Circulating Pressure and and Final Circulating Pressure adding adding 400 psi to t o the original SIDPP. d. Adjust the circulating pressure to 1,000 psi by by adjusting the the choke and and maintaining constant spm. 31. (S) Which of the following could could be affected by a string washout during during a kill operation? (TWO ANSWERS) a.
MAASP.
b.
Bottom hole pressure.
c.
Slow circulating rate pressure.
d.
Kick Tolerance and Fracture Pressure.
32. (S) The choke is gradually gradually closed to compensate for a string washout. washout. What effect does the gradual closing of the choke have on the bottom hole pressure? a.
Increase.
b.
Stay the same.
c.
Decrease.
33. (S) If the drill string washes out during a kill operation operation which of the following following pressures would remain constant? a. Slow circulating rate pressure. b. Casing pressure. c. Drill pipe pressure. d. Initial Circulating Pressure 34. A well is shut in with the following readings: readings: Shut In Casing Pressure
0 psi
Shut In Drill Pipe Pressure
200 psi
There is no flow from the annulus when the choke is opened. What is the most likely cause of zero Shut In Casing Pressure? a.
Swabbing.
b.
The choke gauge has failed.
c.
The formation at the shoe has been fractured.
d.
The drill string is plugged.
e.
The hole is packed off around around the BHA.
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35. How is lost circulation usually detected during a well control operation? a. By a decrease decrease in in the mud mud volume volume in the pits. b. By a decrease in the weight indicator. c. By monitoring monitoring the return return flow flow with with the flow-show. d. By an increase in pump pump speed.
36. The choke line parted while killing killing a well, what is the first action to take? a. Stop pump and close the choke. b. Stop pump and close the BOP side outlet hydraulic hydraulic valve (HCR). (HCR). c. Stop pump pump and close the IBOP at the Top Drive or Kelly. d. Stop pump and and close close the the shear shear rams. rams.
37. Whilst circulating out a kick, the mud pump fails. What is the FIRST action to take? a. Change over to No.2 pump. b. Shut the well in. c. Divert the well. d. Fix pumps as soon as possible.
38. Whilst circulating out a kick the Rotary (Kelly) hose in the Derrick bursts, what is the first action to take? a. Hang tool joint on pipe ram and close the shear rams. (Shear ram above the pipe ram being used). b. Stop the pump, pump, close the full opening opening safety valve valve on the drill drill string then then close the choke. c. Drop the the drill string and and close close the blind/shear blind/shear rams. d. Stop the pump, close close the choke and record pressures. pressures.
39. When killing a well what is the correct action to take if a sudden loss in drill pipe pressure is observed? a. Increase the the pump rate to return return drillpipe drillpipe to correct value. value. b. Continue at at the same pump pump rate holding holding the new drillpipe drillpipe pressure. pressure. c. Shut the well well in and investigate pressure loss. d. Close the choke to compensate for the pressure loss. loss.
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40. Whilst drilling, drilling, a 20 bbl gas kick is taken and the well shut in. The pressures at surface stabilise after a 15 minutes. Due to a delay in mixing kill mud the kill kill operation cannot cannot start. The pressures at surface begin to increase due to gas migration. What action should be taken to keep bottom hole pressure constant (assume there is no float in the string)? a. Start bleeding bleeding off mud and and let the casing pressure pressure decrease decrease according according to volumetric volumetric calculations. b. Bleed mud from the choke, keeping the drill pipe pressure constant. c. Bleed off mud keeping the casing casing pressure pressure constant. constant. d. Leave it as it is. Gas migration migration will will not not affect the bottom bottom hole pressure.
41. WELL DATA: Slow rate circulation pressure
300 psi at 30 spm
The well has been shut in after a kick: Shut In Drill Pipe Pressure
600 psi
Shut In Casing Pressure
750 psi
Before starting to kill the well, there is a complete power failure at the pumps. Which pressure should be kept constant in order to maintain the correct bottom hole pressure if the influx migrates? a. 600 psi drill pipe pressure. b. 750 psi casing pressure. c. 1050 psi casing pressure. d. 900 psi drill pipe pressure.
condensate (with 42. (S) A well is shut in on a 15 bbl kick. The influx is known to be a gas condensate both gas and liquid present). Shut In Drill Pipe Pressure 400 psi Shut In Casing Pressure
500 psi
There is a power failure on the rig and the influx influx starts to migrate. Drill pipe and casing casing pressures are increasing. If the choke was used to keep casing pressure constant at 500 psi, what would happen to bottom hole pressure? a. Increase. b. Decrease. c. Remain constant. 43. (S) Whilst killing a well a sudden sudden loss in standpipe pressure pressure is observed. If the choke was closed to compensate for the t he reduction in pressure, what would happen to the bottom hole pressure? a. It would increase. b. It would decrease. c. It would remain constant. RSTS - EGYPT
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44. Why is pressure build up in the mud/gas separator (poor boy degasser) dangerous whilst circulating out a kick? a. Pressure build build up will increase increase the risk of lost circulation. circulation. b. Pressure build up may allow gas to be blown up the derrick vent line. c. Pressure build up may allow allow gas to enter the shale shaker area. area. d. Pressure build build up will make make choke adjustment difficult.
45. (S) When killing a well using the Driller’s Method the choke pressure suddenly increases by 200 psi. Shortly after, the choke operator sees the same pressure increase on the drill pipe pressure gauge. What is the most likely cause of this pressure increase? increase? a. A restriction restriction in the the Rotary Rotary (Kelly) (Kelly) hose. hose. b. A plugged plugged nozzle in the bit. c. The choke is partly plugged. d. A wash wash out out in the drill drill string. string. e. A second influx has entered the well.
46. (S) When killing a well using the Driller’s Method the choke pressure suddenly increases by 200 psi. Shortly after, the choke operator observes the same pressure increase on the drill pipe pressure gauge. What would be the correct response to this problem? a. Reduce the pump rate to reduce both pressures by 200 psi. b. No action required. c. Shut the well in and change change to another pump. d. Shut the well in and change to another choke. 47. During a kill operation which of the following problems problems require the pump to be shut down quickly to prevent over-pressuri over-pressuring ng the formation. a. A washout in the choke. b. A plugged choke. c. A washout in the drill pipe. d. A plugged standpipe. e. A washed out bit nozzle. f.
A plugged bit nozzle.
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48. How would a choke washout be recognised? a. Drill pipe and casing casing pressures both falling despite closing closing the choke. choke. b. Increase in casing pressure pressure with no no change in drillpipe drillpipe pressure. pressure. c. Rapid rise in drillpipe pressure with no change in casing pressure. d. Drill pipe and casing pressures both both rising despite despite closing closing the choke. choke. 49. How would a choke washout be recognised? a. Rapid rise in casing pressure and no change in drill pipe pressure. b. Continually closing the choke to maintain maintain correct circulating pressure. c. Increase in drill pipe pipe pressure pressure and no change change to casing casing pressure. pressure. d. Continually opening the choke to maintain correct correct circulating pressure.
50. (S) The choke has to be gradually closed closed due to to a string washout. washout. What effect does does this have on the bottom hole pressure? a.
Increase
b.
Decrease
c.
Stay the same.
51. (S) 51. (S) The drill string is slowly washing out and choke is closed to maintain correct drill pipe pressure. pressure. What is happening happening to the bottom hole pressure? pressure? a.
It will decrease.
b.
It will remain constant.
c.
It will increase.
following a gas kick. The kill operation is delayed delayed and the 52. (S) A vertical well is shut in following 52. (S) influx has started to migrate with both drill pipe pressure and casing pressure increasing by 100 psi. WELL DATA Well depth
9,000 feet
Casing shoe depth
5,000 feet
Mud weight
11 ppg (.572 psi/ft)
Open hole/drill pipe capacity
0.060 bbls/ft
Casing/drill pipe capacity
0.065 bbls/ft
NOTE: Assume only drill pipe pipe to be present present in the well Kick Data: Shut in stabilised drill pipe pressure
600 psi
Shut in stabilised casing pressure
800 psi
Kick volume
25 bbls
How many barrels of mud should be bled from the well in order to maintain original bottom hole pressure (before gas started migrating)? ………0.442…….bbls …….bbls ………0.442 RSTS - EGYPT
F-24 7 - 15
53. Select the products commonly used to prevent the formation of hydrates: (TWO ANSWERS) a. Fresh Water. b. Methanol. c. Carboxy Methyl Cellulose (CMC). d. Glycol. e. Diesel oil.
54. (S) Which of the following statements best describes the Volumetric Method? a.
Maintain constant casing shoe pressure as the influx migrates to surface. surface.
b.
Maintain Shut In Casing Casing Pressure Pressure at its initial value as the influx influx migrates to surface.
c.
Maintain constant bottom hole pressure as the influx is migrates migrates to surface. surface.
d.
Maintain constant pressure inside the influx influx as it is allowed to migrate migrate to surface.
55. (S) A well is shut in on a kick. Circulation cannot start due to mechanical mechanical problems. problems. Gas is migrating and bottom hole pressure has to be kept constant. In which of the following situations can the volumetric method of well control be used? (THREE ANSWERS) a.
With the bit on on bottom, bottom, and a non-return non-return valve in the string.
b.
When the bit is a long way way off the bottom, and no non-return non-return valve in the string. string.
c.
With bit on bottom, no non-return valve in the string.
d.
With the bit on on bottom, bottom, and the drill drill string fully plugged plugged off.
56. (S) A gas kick has been taken in a well with a long long open hole section. The drill drill pipe is plugged (Drill pipe pressure cannot be read, and pumping down the drill pipe is not possible). There is evidence evidence of gas migration migration taking place. place. Which one of the following well control procedures can be applied? a.
Volumetric Method.
b.
Wait and Weight Method.
c.
Driller’s Method.
d.
Concurrent Method.
57. (S) When can maximum Casing Shoe pressure occur when using the Volumetric Method.? (TWO ANSWERS). a.
When the influx reaches the BOP stack.
b.
When the influx reaches the Casing Shoe.
c.
When the well is first Shut-in.
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58. (S) During a kill, kill, a washout in the string develops. develops. What happens to the drill pipe pressure? a.
It should increase.
b.
It should decrease.
c.
It should remain constant.
59. (S) During a kill a washout washout develops in the drill string above above the influx. What is the safest way to handle this situation? a.
Stop pumping. Use the volumetric volumetric method until the influx is above the washout. Then resume pumping.
b.
Stop pumping. pumping. Strip out of the the hole to locate the washout washout in the drill string, then then replace washed out joint and strip back to bottom.
c.
Keep pumping pumping until the influx is above the washout, washout, then use the Volumetric technique to remove the influx.
60. (S) Why is it important to monitor the pit volume during during a well control operation? operation? (TWO ANSWERS) a.
To check for mud losses.
b.
Tells you when to adjust drill pipe pressure.
c.
To monitor the gas expansion.
d.
To maintain bottom hole pressure constant.
e.
Tells you when to adjust pump speed.
61. (S) During a kill operation operation the pump starts to leak. The choke operator operator knows nothing about the leak and is maintaining correct drill pipe pressure. What will happen to the bottom hole pressure? a.
It will increase.
b.
It will decrease.
c.
It will remain constant.
62. Which of the following will be affected by a string washout? (TWO ANSWERS). a.
MAASP.
b.
Pump Pressure for kill.
c.
Formation fracture pressure.
d.
Bottom Hole pressure
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63. (S) Which of the following parameters parameters will NOT be affected by a string wash-out wash-out during a well kill operation, when using the Driller’s Method? a. Bottom hole pressure. b. Formation fracture pressure. c. Slow circulating rate pressure.
64. Killing the well well at 40 SPM with 750 psi pump pressure. pressure. If SPM was increased to 50 and pump pressure held constant at 750 psi, what would happen to bottom hole pressure? a. It will increase. b. It will stay constant. c. It will decrease.
65. (S)The (S)The well is being killed properly using the Wait and Weight method of Well Control. 10.6 ppg Kill Weight Mud is being pumped down the drillstring. After Pumping 600 strokes, the drill pipe pressure is 1300 psi. The crew then reduces the pump rate from 40 SPM to 30 SPM using proper procedure. What will be the drill pipe pressure reading at the new rate after pumping a total of 800 strokes? Data: Original mud weight
=
9.6 ppg
Surface to bit strokes
=
1,200 stks
Bit to surface strokes
=
2,400 stks
SCR pressure at 40 SPM
=
1,000 psi
SIDPP
=
500 psi
SICP
=
850 psi
Pit Gain
=
22 bbls
TVD/MD
=
10,000 ft
Kill Weight Mud
=
10.6 ppg
Initial Circulating Pressure
=
1,500 psi
Final Circulating Pressure
=
1,100 psi
Psi/stk
=
0.333
a. 1,350 psi b. 1,234 psi c. 769 psi d. 694 psi
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Section 8 Kill Sheet & Gauge Problems
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1- WELL CONTROL Hole Size
83/8 inch
Hole Depth
11095 ft. TVD/MD
Casing
95/8 Casing set at 8856 ft.
Drill Pipe
5 inch Capacity = .0178 bbls/ft
Heavy Weight Pipe
5 inch, 630 ft. long, Capacity = .0088 bbls/ft
Drill Collars
61/2 inch, 450 ft. long, Capacity = .0077 bbls/ft
Mud Density
12.0 ppg
Volume Open Hole/Collars
.0271 bbls/ft
Volume Open Hole/Drill Pipe/HWDP
.0439 bbls/ft
Volume Casing/Drill Pipe
.0493 bbls/ft
Leak Off Test Pressure using 10.3 ppg mud =
1700 psi
Mud Pumps Output
.109 bbls/Stroke
Slow Circulating Rate
450 psi at 40 SPM
Surface Lines
7 bbls
Shut In Data Shut-in Drill Pipe Pressure
650 psi
Shut-in Casing Pressure
850 psi
Pit Gain
15 bbls
CALCULATE 1. Strokes Surface to Bit
= 1714 Strokes
2. Strokes Bit to Shoe
= 832 Strokes
3. Strokes Bit to Surface
= 4844 Strokes
4. Kill Mud Weight
= 13.2 ppg
5. Initial Circulating Pressure
= 1100 psi
6. Final Circulating Pressure
= 49 495 5 psi
7. MAASP with current mud weight
= 917 psi
8. MAASP after circulation of kill mud
= 363 psi
9. Time for complete circulation
= 16 164 4 minutes minu tes
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2- WELL CONTROL HOLE DIMENSIONS Casing Size Casing Shoe Depth Open Hole Diameter Hole Depth Drill Collars Drill Pipe
= = = = = =
13-3/8" OD (ID = 12.515”) 6,500 ft 12-1/4" 9,800 ft (TVD = 9,800 ft) 8.5” OD ; 2.75" ID ;Length = 680 ft 5" OD ; 4.276" ID
Drill Pipe Capacity Drill Collar Capacity CSG to Pipe Annulus OH to Pipe Annulus OH to Collar Annulus
= = = = =
.01776 bbls/ft .007 bbls/ft .1279 bbls/ft .1215 bbls/ft .0756 bbls/ft
CAPACITIES
PUMPING DATA Pump Output = .15 bbls/stroke Slow Circulating Circulating Rate Pressure Pressure at at 40 SPM = 950 psi. FRACTURE DATA Leak Off Test Pressure = Mud Weight in Hole at Test =
1,800 psi, 10.2 ppg
Present Mud Weight SIDPP SICP Pit Gain
10.8 ppg 800 psi 1,000 psi 30 bbls
KICK DATA = = = =
CALCULATE 1. Kill Mud Weight
= 12.36 pp ppg g
2. The Fracture Mud Weight.
= 15.53 pp ppg g
3. MAASP with present mud in hole.
= 1599 psi
4. Surface to Bit Strokes and Time.
= 1112 stk & 28 min
5. Bit to Shoe Strokes and Time.
= 2465 stk & 61.6 min
6. Total Circulation Strokes for Wait and Weight method.
= 9113 strokes
7. ICP and FCP
= 1750 psi & 1090 ps psii
8. Complete Step Down Chart OR Graph showing reduction in Drill Pipe Pressure as Kill Mud is pumped to the Bit.
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9. The well is shut in and the SIDPP and SICP can be read on the gauges. The kill is ready to start at 40 SPM.
2000
4000
1000
See next set of gauges.
2000
3000
PSI
5000
30
0
12
0
0
2000
4000
a. Increase SPM
c. Open the Choke to obtain correct pressure pressure d. Close the Choke Choke to obtain correct pressure pressure e. Carry on - all is OK!
30
20
0
1
2000
4
c. Open the Choke to obtain correct pressure d. Close the Choke to obtain correct pressure e. Carry on - all is OK!
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0
30
0
4000
3
4
5000
12
5
TOTAL STROKES
7 - 24
3000
CASING PRESSURE
40
10 50 0 60 PUMP RATE (SPM) 0
TIME 00 Hrs : 3.5Mins 3.5Mins
PSI
5000
20
6
1000
PSI
b. Decrease SPM
3
2000
DRILLPIPE PRESSURE
a. Increase SPM
9
0
4000
0
CASING PRESSURE
12
3000
1000
5000
40
TOTAL STROKES
11. 345 strokes have been pumped, drillpipe pressure is approx. 1500 psi. Casing pressure has fallen a small amount From the options given below choose the action you would take at this time.
3000 4000
0
10 50 0 60 PUMP RATE (SPM) 0
TIME 00 Hrs : 00 Mins
PSI
5000
DRILLPIPE PRESSURE
b. Decrease SPM
6
1000
PSI 0
3
2000
3000
1000
9
0
TOTAL STROKES
10. Kill has started. started. SPM is 40 and 140 strokes have been been pumped. From the options given below choose the action you would take at this time.
CASING PRESSURE
40
10 50 0 60 PUMP RATE (SPM) 0
5000
0
DRILLPIPE PRESSURE
20
4000
1000
PSI 0
3000
9
3 6
TIME 00 Hrs : 8.5 8.5 Mins
12. 928 strokes have have been pumped pumped and SPM is at 40. 40. From the options given below choose the action you would take at this time.
2000
2000
3000 4000
1000
PSI
5000
b. Decrease SPM
30
20
c. Open the Choke to obtain correct pressure pressure d. Close the Choke Choke to obtain correct pressure pressure
10
0
e. Carry on - all is OK!
12
9
2
2000
4000
6 TIME 00 Hrs : 28 Mins
a. Increase SPM
3000 4000
1000
PSI
PSI
5000
0
3
2000
3000
1000
9
8
TOTAL STROKES
13. Drillpipe pressure seems stable but Casing pressure is near 800 psi. From the options given below choose the action you would take at this time.
CASING PRESSURE
40
50 0 60 PUMP RATE (SPM) 0
5000
0
DRILLPIPE PRESSURE
a. Increase SPM
4000
1000
PSI 0
3000
5000
0
DRILLPIPE PRESSURE
CASING PRESSURE
b. Decrease SPM c. Open the Choke to obtain correct pressure pressure d. Close the Choke Choke to obtain correct pressure pressure e. Carry on - all is OK!
30
20 10
12
40
50 0 60 PUMP RATE (SPM) 2
0
4
7
2000
6 TIME 1 Hrs : 2 Mins
2000
3000 4000
1000
0
DRILLPIPE PRESSURE
b. Decrease SPM c. Open the Choke to obtain correct pressure pressure d. Close the Choke Choke to obtain correct pressure pressure e. Carry on - all is OK!
20
30
10
7
5
0
12
0
TOTAL STROKES
RSTS - EGYPT
7 - 25
5000
CASING PRESSURE
40
50 0 60 PUMP RATE (SPM) 0
4000
PSI
5000
0
3000
1000
PSI
a. Increase SPM
3
0
TOTAL STROKES
14. Not much change to casing pressure for a long long time. From the options given below choose the action you would take at this time.
9
9
3 6
TIME 3 Hrs : 7 Mins
15. 8000 strokes strokes made and and casing pressure pressure is fluctuating up and down. Gas is making a lot of noise as it passes through the choke. From the options given below choose the action you would take at this time.
2000
2000
3000 4000
1000
PSI
5000
b. Decrease SPM
30
20
c. Open the Choke to obtain correct pressure d. Close the Choke to obtain correct pressure
10
8
12
0
0
2000
4000
6 TIME 3 Hrs : 20 Mins
a. Increase SPM
3000 4000
1000
PSI
PSI
5000
0
3
2000
3000
1000
9
0
TOTAL STROKES
16. Casing pressure has dropped to almost zero, am I letting in another kick?. From the options given below choose the action you would take at this time.
CASING PRESSURE
40
50 0 60 PUMP RATE (SPM) 0
e. Carry on - all is OK!
5000
0
DRILLPIPE PRESSURE
a. Increase SPM
4000
1000
PSI 0
3000
0
DRILLPIPE PRESSURE
5000
CASING PRESSURE
b. Decrease SPM c. Open the Choke to obtain obtain correct pressure pressure d. Close the Choke to obtain correct pressure pressure e. Carry on - all is OK!
30
10
12
40
50 0 60 PUMP RATE (SPM) 0
f. Shut well in and check if well is dead
RSTS - EGYPT
20
9
3
0
0
TOTAL STROKES
7 - 26
9
3 6
TIME 3 Hrs : 52 Mins
3- WELL CONTROL HOLE DIMENSIONS Casing Size Casing Shoe Depth Open Hole Diameter Hole Depth Drill Collars Drill Pipe
= 9-5/8" OD (ID = 8.91") = 10,100 ft = 8-1/4" = 12,250 ft (TVD = 12,250 ft) = 6" OD; 2.25" ID; Length = 800 ft = 5" OD ; 4.276 " ID.
Drill Pipe Capacity Drill Collar Capacity CSG to Pipe Annulus OH to Pipe Annulus OH to Collar Annulus
= = = = =
CAPACITIES .01776 bbls/ft .005 bbls/ft .0529 bbls/ft .0418 bbls/ft .031 bbls/ft
PUMPING DATA Pump Output = .2 bbls/stroke, Slow Circulating Circulating Rate Pressure Pressure at 35 SPM = 1,100 psi. FRACTURE DATA Leak Off Test Pressure Mud Weight in Hole at Test
= =
2,300 psi. 11.7 ppg.
Mud weight in hole SIDPP SICP Pit Gain
= = = =
12.2 ppg 750 psi 1,050 psi 25 bbls
KICK DATA
CALCULATE 1. Kill Mud Weight if we use 0 psi Overbalance. Overbalance .
= 13.37 pp ppg g
2. The Fracture Mud Weight.
= 16.08 pp ppg g
3. MAASP with present mud in hole.
= 2037 psi
4. Surface to Bit Strokes and Time.
= 1037 stk & 29.6 29.6 min
5. Bit to Shoe Strokes and Time.
= 406 stk & 11.6 11.6 min
6. Total Circulation Strokes for Wait and Weight method.
= 4112 strokes
7. ICP and FCP
= 1850 psi & 1205 psi
8. Complete Step Down Chart OR Graph showing reduction in Drill Pipe Pressure as Kill Mud is pumped to the Bit.
RSTS - EGYPT
7 - 27
9. The well is shut in and the SIDPP and SICP can be read on the gauges. The kill is ready to start at 35 SPM.
2000
4000
1000
See next set of gauges.
2000
3000
PSI
5000
30
0
12
0
0
2000
4000
6 TIME 00 Hrs : 00 Mins
a. Increase SPM
3000 4000
1000
PSI
PSI
5000
0
3
2000
3000
1000
9
0
TOTAL STROKES
10. Kill has started. started. SPM is 35 and 30 strokes strokes have been been pumped. From the options given below choose the action you would take at this time.
CASING PRESSURE
40
10 50 0 60 PUMP RATE (SPM) 0
5000
0
DRILLPIPE PRESSURE
20
4000
1000
PSI 0
3000
5000
0
DRILLPIPE PRESSURE
CASING PRESSURE
b. Decrease SPM c. Open the Choke to obtain correct pressure pressure d. Close the Choke Choke to obtain correct pressure pressure e. Carry on - all is OK!
30
20 10
12
40
50 0 60 PUMP RATE (SPM) 0
0
0
3
2000
6 TIME 00 Hrs : 2 Min
2000
3000 4000
1000
3000 4000
1000
PSI
PSI
5000
0
3
0
TOTAL STROKES
11. 80 strokes have been pumped, drillpipe pressure is approx. 1900 psi. Did I take the right action at start-up? From the options given below choose the action you would take at this time.
9
0
DRILLPIPE PRESSURE
5000
CASING PRESSURE
a. Increase SPM 20
b. Decrease SPM c. Open the Choke to obtain correct pressure pressure d. Close the Choke Choke to obtain correct pressure pressure
12
40
10 50 0 60 PUMP RATE (SPM) 0
0
0
8
0
TOTAL STROKES
e. Carry on - all is OK!
RSTS - EGYPT
30
7 - 28
9
3 6
TIME 00 Hrs : 3 Mins
12. Drillpipe and Casing Casing pressures are now less than immediately following following start-up and SPM is 35! From the options given below choose the action you would take at this time.
2000
4000
1000
c. Open the Choke to obtain correct pressure pressure d. Close the Choke Choke to obtain correct pressure pressure
0
12
1
7
2000
6 TIME 00 Hrs : 6 Mins
4000
c. Open the Choke to obtain correct pressure pressure d. Close the Choke Choke to obtain correct pressure pressure e. Carry on - all is OK!
30
20
0
12
6
3
2000
4000
6 TIME 00 Hrs : 20Mins
a. Increase SPM
0
DRILLPIPE PRESSURE
c. Open the Choke to obtain correct pressure pressure d. Close the Choke Choke to obtain correct pressure pressure
20
30
1
0
4
12
5
TOTAL STROKES
RSTS - EGYPT
7 - 29
5000
CASING PRESSURE
40
10 50 0 60 PUMP RATE (SPM) 0
e. Carry on - all is OK!
4000
PSI
5000
b. Decrease SPM
3000
1000
PSI 0
3
2000
3000
1000
9
5
TOTAL STROKES
14. Drillpipe pressure pressure is gradually decreasing decreasing as kill mud is pumped to the bit. From the options given below choose the action you would take at this time.
CASING PRESSURE
40
10 50 0 60 PUMP RATE (SPM) 0
5000
0
DRILLPIPE PRESSURE
b. Decrease SPM
4000
PSI
5000
0
3000
1000
PSI
a. Increase SPM
3
2000
3000
1000
9
0
TOTAL STROKES
13. 635 strokes made while holding 35 SPM. From the options given below choose the action you would take at this time.
CASING PRESSURE
40
10 50 0 60 PUMP RATE (SPM) 0
e. Carry on - all is OK!
30
5000
0
DRILLPIPE PRESSURE
20
4000
PSI
5000
b. Decrease SPM
3000
1000
PSI 0
a. Increase SPM
2000
3000
9
3 6
TIME 00 Hrs : 32 Mins
15. 1080 strokes pumped. From the options given below choose the action you would take at this time.
2000
2000
3000 4000
1000
a. Increase SPM
4000
1000
PSI
PSI
5000
0
3000
5000
0
DRILLPIPE PRESSURE
CASING PRESSURE
b. Decrease SPM c. Open the Choke to obtain correct pressure pressure d. Close the Choke Choke to obtain correct pressure pressure e. Carry on - all is OK!
30
20
12
40
10 50 0 60 PUMP RATE (SPM) 1
0
0
8
2000
6 TIME 00 Hrs : 33 Mins
2000
3000 4000
1000
a. Increase SPM
c. Open the Choke to obtain correct pressure pressure d. Close the Choke Choke to obtain correct pressure pressure e. Carry on - all is OK!
1
17. Well has been been shut in and following following pressures pressures are noted. What should I do now? Choose from the options given below.
12
5
9 6
TIME 00 Hrs : 35 Mins
2000
3000 4000
a. SPM was increased increased too much
c. You opened opened the Choke Choke too much 20
d. You closed the Choke Choke too much e. Drillstring is partially partially restricted, start up and observe observe pressures.
0
30
1
1
6
12
5
TOTAL STROKES
RSTS - EGYPT
7 - 30
5000
CASING PRESSURE
40
10 50 0 60 PUMP RATE (SPM) 0
4000
PSI
5000
DRILLPIPE PRESSURE
b. Driller decreased decreased SPM
3000
1000
PSI 0
3
0
TOTAL STROKES
1000
CASING PRESSURE
40
1
2000
5000
0
10 50 0 60 PUMP RATE (SPM) 0
f. Shut the well in in and consider the problem problem
30
20
4000
PSI
5000
DRILLPIPE PRESSURE
b. Decrease SPM
3000
1000
PSI 0
3
0
TOTAL STROKES
16. Drillpipe pressure seems to have gone up over last 50 to 100 strokes! What may have happened? From the options given below choose the action you would take at this time.
9
9
3 6
TIME 00 Hrs : 36 Mins
18. Start back up to 35 SPM, SPM, these are the pressure! pressure! From the options given below choose the action you would take at this time.
2000
2000
3000 4000
1000
1000
5000
0
b. Decrease SPM
d. Close the Choke Choke to obtain correct pressure pressure e. Carry on - all is OK!
30
20
1
12
1
8
2000
6 TIME 00 Hrs : 37 Mins
4000
b. Decrease SPM
4000
PSI
5000
0
3000
1000
PSI
a. Increase SPM
3
2000
3000
1000
9
5
TOTAL STROKES
19. 2900 strokes made. From the options given below choose the action you would take at this time.
CASING PRESSURE
40
10 50 0 60 PUMP RATE (SPM) 0
5000
0
DRILLPIPE PRESSURE
c. Open the Choke to obtain correct pressure pressure
4000
PSI
PSI
a. Increase SPM
3000
5000
0
DRILLPIPE PRESSURE
CASING PRESSURE
c. Open the Choke to obtain correct pressure pressure d. Close the Choke Choke to obtain correct pressure pressure e. Carry on - all is OK!
30
20
12
40
10 50 0 60 PUMP RATE (SPM) 2
0
9
0
2000
6 TIME 1 Hrs : 25 Mins
2000
3000 4000
1000
a. Increase SPM
3000 4000
1000
PSI
PSI
5000
0
3
0
TOTAL STROKES
20. Casing pressure has dropped, have I done something wrong?. From the options given below choose the action you would take at this time.
9
0
DRILLPIPE PRESSURE
5000
CASING PRESSURE
b. Decrease SPM c. Open the Choke to obtain correct pressure pressure d. Close the Choke Choke to obtain correct pressure pressure e. Carry on - all is OK!
30
12
40
10 50 0 60 PUMP RATE (SPM) 0
f. Shut well in and check if well is dead
RSTS - EGYPT
20
4
2
0
0
TOTAL STROKES
7 - 31
9
3 6
TIME 1 Hrs : 58 Mins
RSTS - EGYPT
7 - 32
4- WELL CONTROL HOLE DIMENSIONS Casing Size Casing Shoe Depth Open Hole Diameter Hole Depth Drill Pipe Heavy Weight Pipe Drill Collars
= = = = = = =
13-3/8" 8,620 ft (TVD = 6,500) 12-1/4" 12,220 ft (TVD = 10,200 ft) 5" OD; Length = 11,048 ft 5" OD; Length = 630 ft 8" OD; Length = 542 ft
Drill Pipe Capacity
=
.01776
Heavy Weight Capacity Drill Collar Capacity CSG to Pipe Annulus OH to Pipe/HWAnnulus Pipe/HWAnnulus OH to Collar Annulus
= = = = =
.0088 .0061 .1238 .1251 .086
CAPACITIES
bbls/ft bbls/ft bbls/ft bbls/ft bbls/ft bbls/ft
PUMPING DATA Pump Output = .11 bbls/stroke, Slow Circulating Rate Pressure at 30 SPM = 750 psi. 40 SPM = 1,350 psi. FRACTURE DATA Leak Off Test Pressure Mud Weight in Hole at Test
= =
1,600 psi. 9.8 ppg.
Mud weight in hole SIDPP SICP Pit Gain
= = = =
10.5 ppg 800 psi 1,100 psi 60 bbls
KICK DATA
KILL THE WELL USING THE DRILLER’S METHOD
RSTS - EGYPT
7 - 33
CALCULATE 1. Strokes Surface to Bit
= 1864 Strokes
2. Strokes Bit to Shoe
= 3900 Strokes
3. Strokes Bit to Surface
= 13604 Strokes
4. Strokes for Total circulation
= 15468 15468 Strokes Strokes
5. Kill Mud Weight
= 12 12 ppg ppg
6. Initial Circulating Pressure (at 30 SPM)
= 1550 1550 psi psi
7. Final Circulating Pressure
= 857 857 psi psi
8. Maximum allowable Mud Weight
= 14.5 14.5 ppg ppg
9. The Fracture Pressure at the Shoe
= 4901 psi
10. The Fracture Gradient
= 0.755 psi/ft
11. MAASP with current Mud Weight
= 1363 psi
12. MAASP with Kill Mud Weight
= 855 855 psi psi
13. Time for complete circulation
= 516 516 minutes minutes
RSTS - EGYPT
7 - 34
Well is shut in. Plan is to kill well using Drill er Method at 30 SPM SPM
2000
2000
3000
4000
1000
4000
1000
PSI
PSI
5000
0
CASING 1100 psi
12
30 40
10
50
0
60
9
3
PUMP RATE 00 SPM 0
0
0
0
5000
0
DRILLPIPE 800 psi
20
3000
6
0
TOTAL TOTAL STRO STROKES KES
TIME 0 Hrs Hrs : 0 Mins
14. You note these values. Any action to be taken ? 2000
4000
1000
a. Increase SPM
2000
3000
PSI
5000
0
c. Increase choke size
4000
1000
PSI
b. Decrease SPM
3000
5000
0
DRILLPIPE 1400 psi
CASING1000 psi
d. Decrease choke size e. Carry on - all is OK!
12
30
20
40
10
50
0
60
9
3
PUMP RATE 30 SPM
6
0
4 0
TOTAL TOTAL STRO STROKES KES
TIME 0 Hrs : 13 Mins
15. You note these values. Any action to be taken ? 2000
4000
1000
a. Increase SPM
2000
3000
PSI
5000
0
c. Increase choke size
4000
1000
PSI
b. Decrease SPM
3000
0
DRILLPIPE 1550 psi
5000
CASING1200 psi
d. Decrease choke size e. Carry on - all is OK!
20
12
30 40
10
50
0
60
PUMP RATE 30 SPM
1
2
0
0
TOTAL TOTAL STRO STROKES KES
RSTS - EGYPT
7 - 35
9
3 6
TIME 0 Hrs : 40 Mins
16. You note these values. Any action to be taken ? 2000
a. Increase SPM
4000
1000
b. Decrease SPM
2000
3000
c. Increase choke size
PSI
5000
e. Carry on - all is OK!
CASING 1150 ps i
12
30
20
5000
0
DRILLPIPE 1400 psi
d. Decrease choke size
4000
1000
PSI 0
3000
40
10
50
0
60
9
3
PUMP RATE 23 SPM 1
5
0
5
TOTAL TOTAL STROKES STROKES
6 TIME 0 Hrs : 52 Mins
17. You note these values. Any action to be taken ? 2000
4000
1000
a. Increase SPM
2000
3000
PSI
5000
0
c. Increase choke size
4000
1000
PSI
b. Decrease SPM
3000
5000
0
DRILLPIPE 1550 psi
CASING 1350 psi
d. Decrease choke size e. Carry on - all is OK!
12
30
20
40
10
50
0
60
9
3
PUMP RATE 30 SPM 4
0 0
6
0
TOTAL TOTAL STROKE STROKES S
TIME 02 Hrs : 13 Mins
18. Current situation is as shown. 2000
Casing Pressure exceeded MAASP Any action to be taken taken ?
2000
3000
4000
1000
1000
a. Increase SPM
4000
PSI
PSI
5000
0
3000
0
DRILLPIPE 1550 psi
5000
CASING1800 psi
b. Decrease SPM c. Increase choke size
20
d. Decrease choke size
12
30 40
10
50
0
60
PUMP RATE 30 SPM
e. Carry on - all is OK!
6 0 0 0 TOTAL TOTAL STROKE STROKES S
RSTS - EGYPT
7 - 36
9
3 6
TIME 04 Hrs : 26 Mins
19. Gas is at the choke. What action would you take ? 2000
a. Increase choke size
4000
1000
b. Decrease choke size
2000
3000
4000
1000
PSI
PSI
5000
0
c. Increase pump rate
e. Casing pressure is expected, carry on, keep drillpipe pressure at 1550 psi
5000
0
DRILLPIPE+\DRILLPIPE+\- 1550 psi
d. Decrease pump rate
CASING CASING+\+\- 2000 2000 psi
12
30
20
40
10
50
0
60
9
3
PUMP RATE 30 SPM 2
1
9
Now you ready for the 2 nd circulation, switch over to kill mud and zero the stroke counter
2000
TIME 7 Hrs : 10 Mins
2000
3000
4000
1000
6
0
0
TOTAL TOTAL STROKE STROKES S
You finished the 1 st circulation and shut down the well, Drillpipe and Casing Pressures are reading approximately approximately the same.
4000
PSI
5000
5000
0
DRILLPIPE 800 psi
CASING850 psi
12
30
20
40
10
50
0
60
9
3
PUMP RATE 0 SPM 4
1
0
2000
TIME 07 Hrs : 47 Mins
2000
3000
4000
1000
a. Increase SPM
6
0
0
TOTAL TOTAL STROKE STROKES S
20. You start the kill mud and note these values. Any action to be taken taken ?
c. Increase choke size
4000
PSI
5000
0
3000
1000
PSI
b. Decrease SPM
3000
1000
PSI 0
3000
0
DRILLPIPE 1350 psi
5000
CASING 650 psi
d. Decrease choke size e. Carry on - all is OK!
20
12
30 40
10
50
0
60
9
3
PUMP RATE 30 SPM 1
5
0
TOTAL TOTAL STROKE STROKES S
RSTS - EGYPT
7 - 37
6 TIME 0 Hrs : 5 Mins
21. You note these values. Any action to be taken ? 2000
4000
1000
a. Increase SPM
2000
3000
1000
4000
PSI
PSI
b. Decrease SPM
5000
0
c. Increase choke size
3000
5000
0
DRILLPIPE 1150 psi
CASING 800 psi
d. Decrease choke size e. Carry on - all is OK!
12
30
20
40
10
50
0
60
9
3
PUMP RATE 30 SPM 1
2
TOTAL TOTAL STROKE STROKES S
22. You note these values. Any action to be taken ?
2000
a. Increase SPM
TIME 0 Hrs : 40 Mins
2000
3000
4000
1000
6
0
0
1000
5000
0
d. Decrease choke size
CASING 900 psi
12
30
20
e. Carry on - all is OK!
5000
0
DRILLPIPE1100 DRILLPIPE1100 ps i
c. Increase choke size
4000
PSI
PSI
b. Decrease SPM
40
10
50
0
60
9
3
PUMP RATE 30 SPM 2
0 0
2000
a. Increase SPM
4000
0
DRILL PIPE 860 psi
c. Increase choke size d. Decrease choke size
20
e. Carry on - all is OK!
12
40
10
50
0
60
4 0 0 5
5000
CASING 300 psi
30
PUMP RATE 30 SPM
0
TOTAL TOTAL STROKE STROKES S
7 - 38
4000
PSI
5000
0
3000
1000
PSI
b. Decrease SPM
RSTS - EGYPT
TIME 01 Hrs : 7 Mins
2000
3000
1000
6
0
TOTAL TOTAL STROKE STROKES S
23. You note these values. Any action to be taken ?
3000
9
3 6
TIME 2 Hrs : 13 Mins
5- WELL CONTROL CONTROL Answer the following following questions questions using the attached attached filled up kill kill sheet, Pump strokes is 30 SPM, kill the well using the drillers method.
RSTS - EGYPT
7 - 39
RSTS - EGYPT
7 - 40
RSTS - EGYPT
7 - 41
The Questions 1. 60 strokes pumped 2 minutes passed. Drill pipe pressure = 900 psi. Casing pressure = 750 psi. Pump strokes = 30 SPM What action would you take ? a. Increase choke size b. Decrease choke size c. Increase pump speed d. Decrease pump speed e. Every thing thing is correct
2. 510 strokes pumped 17 minutes passed. Drill pipe pressure = 1160 psi Casing pressure = 1020 psi Pump strokes = 30 SPM What action would you take ? a. Pench choke b. Open choke c. Increase pump speed d. Decrease pump speed e. Carry on, on, all : good
3. 600 strokes pumped 20 minutes passed Drill pipe pressure = 1130 psi Casing pressure = 1030 psi Pump strokes = 28 SPM What action would you take ? a. Pench choke b. Open choke c. Increase pump speed d. Decrease pump speed e. Carry on, on, all : good
RSTS - EGYPT
7 - 42
4. 5000 strokes pumped 2 hours + 46 minutes passed. Drill pipe pressure = 1200 psi. Casing pressure = 1400 psi. Pump strokes = 30 SPM What action would you take ? a. Decrease choke size b. Increase choke size c. Decrease pump speed d. Increase pump speed e. Carry on, on, all : good
5. 7700 strokes pumped. 4 hours + 16 minutes passed. Pump strokes = 30 SPM You decided to shut the well-in at this stage, what are the expected pressures at the drill pipe and the casing gauges ? SIDPP SIDP P = 800 psi SICP = 800 ps i
6. You start to pump the kill mud 980 strokes pumped Drill pipe pressure = 480 psi. Casing pressure = 820 psi. Pump strokes = 30 SPM What action would you take ? a. Decrease choke size b. Increase choke size c. Decrease pump speed d. Increase pump speed e. Carry on, on, all : good
RSTS - EGYPT
7 - 43
7. You still pumping the kill mud 1500 strokes pumped Drill pipe pressure = 490 psi. Casing pressure = 1000 psi. Pump strokes = 30 SPM What action would you take ? a. Decrease choke size b. Increase choke size c. Decrease pump speed d. Increase pump speed e. Carry on, on, all : good
RSTS - EGYPT
7 - 44
6- WELL CONTROL ATTACHED KILL SHEET SHEET Use the data from the attached kill sheets (following two pages) to answer each of the questions 49a through 49 g about the well killing process. You are required to indicate the first action that should be taken: The well will be killed with the Wait and Weight Method at 30 SPM.
11.0
1099
13 5/8 6,000 5,820
0.119
0.119
12 1/4 7,560 30
500
6000
500
1085
RSTS - EGYPT
7 - 45
36
1420
47
6519
217
7939
265
9024
301
680
550
25
12.5
1050
570 44.2
0 100 200 300 400 500 600 700 800 900 1000 1085
RSTS - EGYPT
1050 1006 962 917 873 829 785 741 696 652 608 570
7 - 46
The Questions 1. After 5 minutes of circulation the following following readings readings are observed on the choke panel: panel: Drill pipe pressure Casing pressure Pump speed Strokes circulated
= = = =
940 psi 640 psi 25 spm 139 strokes
What action should be taken? (One answer) a. Open the choke slowly. slowly. b. Close the choke choke slowly. slowly. c. Increase the pump pump rate. rate. d. Decrease the pump pump rate. e. Continue – Everything Everything is O.K.
2. After 9 minutes of circulation the following following readings readings are observed on the choke panel: panel: Drill pipe pressure Casing pressure Pump speed Strokes circulated
= = = =
930 psi 620 psi 30 spm 270 strokes
What action should be taken? (One answer) a. Open the choke slowly. slowly. b. Close the choke choke slowly. slowly. c. Increase the pump pump rate. rate. d. Decrease the pump pump rate. e. Continue – Everything Everything is OK
3. After 15 minutes of circulation the following following readings readings are observed on the choke panel: panel: Drill pipe pressure Casing pressure Pump speed Strokes circulated
= = = =
851 psi 600 psi 30 spm 450 strokes
What action should be taken? (One answer). a. Open the choke slowly. slowly. b. Close the choke choke slowly. slowly. c. Increase the pump pump rate. rate. d. Decrease the choke choke rate. e. Continue – Everything Everything is OK
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4. After 870 strokes have been circulated, circulated, the following following readings are observed observed on the choke panel Drill pipe pressure Casing pressure Pump speed Strokes circulated
= = = =
720 psi 640 psi 30 spm 870 strokes
What action should be taken? (One answer) a. Open the choke slowly. slowly. b. Close the choke choke slowly. slowly. c. Increase the pump pump rate. rate. d. Decrease the pump pump rate. e. Continue – Everything Everything is O.K.
5. After 1400 strokes have been circulated, circulated, the well has been been shut-in to make a check and the following readings are observed on the choke panel: Drill pipe pressure Casing pressure Pump speed Strokes circulated
= = = =
0 psi 620 psi 0 spm 1400 strokes
After the check, the kill kill procedure is continued. continued. Which should should be done? (One answer) a. Calculate new new kill mud density density and pump rate. rate. b. Start up holding drill pipe pressure pressure constant. c. Start up holding casing casing pressure constant while while bringing the pump up to kill speed, speed, then hold the observed drill pipe pressure constant. d. Everything is OK, continue kill kill procedures with 40 spm and and same final circulating circulating pressure.
6. After 7,000 strokes have been circulated, circulated, the following readings readings are observed observed on the choke panel: Drill pipe pressure Casing pressure Pump speed Strokes circulated
= = = =
458 psi 720 psi 30 spm 7,000 strokes
What action should be taken? (One answer) a. Open the choke slowly. slowly. b. Close the choke choke slowly. slowly. c. Increase the pump pump rate. rate. d. Decrease the pump pump rate. e. Continue – Everything Everything is O.K.
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7. After 9,100 strokes have been circulated, circulated, the following readings readings are observed observed on the choke panel: Drill pipe pressure Casing pressure Pump speed Strokes circulated
= = = =
570 psi 0 psi 30 spm 9,100 strokes
What action should be taken? (One answer) a. Open the choke slowly. slowly. b. Close the choke choke slowly. slowly. c. Stop pumping and resume drilling. d. Stop pumping, pumping, shut-in the well, and and observe pressure. pressure. e. Continue – Everything Everything is O.K.
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