Well Control wellsharp course supervisor drilling surface

Introduction.

WHAT TERM MEANS 'AN UNCONTROLLED FLOW OF FLUIDS FROM THE

TRAINING?

A. REVENTON
B. AMAGO (SURGENCIA KICK)
C. LOSS OF CIRCULATION
D. FRACTURED FORMATION

2. WHEN PREPARING FOR A SHIFT CHANGE DURING AN OPERATION OF

DROWNING IN A WELL, WHAT WOULD BE THE BEST PRACTICE WHEN DRIVING IN TRANSFER?

A. ALL THE PASTES INVOLVED SHOULD BE ACTIVE FOR A TIME

SUFFICIENT TO ALLOW A COMPLETE COMMUNICATION OF THE
Ongoing activities.
B. REQUEST THAT THE MUD ENGINEER (INJECTIONIST) ANALYZE THE TASKS WITH
EACH MEMBER OF THE CREW.
C. ONCE THE CURRENT CREW HAS LEFT THE SITE, CALL THE CREW
NEW TO THE DRILLING FLOOR FOR A MEETING TO ANALYZE AS
OBLIGATIONS.
D. IMMEDIATELY TAKE CHARGE OF THE CURRENT CREW AND WORK WITH E
SUPERVISOR TO HELP DROWN (KILL) THE WELL.

3. What is the most important reason for having good ...

shift change procedures between crews during control operations
of wells?

A. It is a regulatory form that must be filled out and submitted to the agency.
local regulator.
B. To allow blame to be assigned in the event of an incident during operations
of drowning.
C. Ensure the continuity of operations and transmit information about the
trends to identify potential problems.
D. Shift change procedures are not considered important during the
well control operations.

4. When drilling and high connection gas levels are recorded, there is a failure.
electric that eliminates the ability to move and rotate. What is the safest action?
for taking?
A. Disconnect and close the well and monitor to see if the pressure in the well increases.
 B. Extract the string up to the shoe of the casing and give the string a to-and-fro movement.
(reciprocate).
C. Align the travel tank and monitor the well
D. Move the pipe up and down ( oscillation ) to avoid a jam ( entrapment )
of pipe.

Question to the Air

What is the main reason for measuring the density and viscosity of the mud when it exits?
from the well?
A. Provide information about the effects of the well on the mud.
B. Instruct the mud engineer (injector) when to conduct the mud tests
C. Allows the drilling mud program of the well plan to continue.
D. Ensure compliance with the campaign policy

BARRIERS.

5. Which of the following is not a well barrier verification method?

A. Leak off test (of dripping or admission)
B. Established weight formation (contact, tagging)
C. Influence test (negative test)
D. Positive pressure test

6. What is a 'negative' pressure test?

A test on a barrier where the pressure at the top of the barrier is increased to
a value higher than the pressure below the barrier.
B. A test where a barrier is tested until there is a leak
C. A test in which the barrier is made to fail
D. A test on a barrier where the pressure at the top of the barrier is reduced to a
value below the pressure below the barrier.

A 500-foot long cement plug is set inside the casing across the shoe.
And the sludge above the plug will be displaced with brine. The formation pressure
beneath the plug is balanced by a mud of 10.7 ppg (lb/gal).
Brine density = 9.5 ppg (lb/gal)
Top of cement plug = 8200 feet
If the plug fails and the well opens, what will happen to the well?

A. The well will remain static

B. The formation will fracture
C. The well will flow
D. The casing will collapse
8. The well is full of mud 12.2 ppg (b/gal) it settles and tests a cement plug of
500 feet. If the mud above the plug is replaced with a brine of 10.2 ppg
(lb/gal), What will happen to the differential pressure between the top and the bottom of the plug?
cement?
A. The differential pressure will decrease
B. The differential pressure will increase
C. The differential pressure will be equal to zero

9. If a surge (kick) is sucked (by upward stroking, swabbed) when

He is taking a trip, which barrier failed?

A. Cement barrier
B. Temporary mechanical barrier
C. Primary barrier (hydrostatic)
D. Permanent mechanical barrier

10. A cable tool is lowered into a pressurized well. A lubricating assembly is used.
together with a cable preventer (wireline BOP). How would you classify the lubricator
as a barrier?

A. Terciaro
B. Auxiliary
C. Primary
D. Secondary

11. Which of the following is considered a 'procedural barrier'?

A. Monitoring the well to receive gains or losses

B. The casing shoe
C. A group of settled packers
D. The drilling fluid

12. Which of the following is NOT classified as a barrier?

A. Float valve of the drilling string

B. Pipe ram (sounding rods)
C. The hydrostatic pressure of the mud
D. The full opening safety valve
13. What is the minimum number of established barriers that is normally required to
any phase of the operations?

A. Dos
B. Four
C. Three
D. One

14. What is a positive test?

A test on a barrier where the pressure applied to the side of the formation
the pressure on the barrier side is higher than the pressure on the surface side of the barrier

B. A test on a barrier in which the pressure on the surface side of the

The barrier is higher than the pressure on the side of the barrier formation.

C. A test on a barrier where the pressure on the formation side

the barrier is equal to the pressure on the surface side of the barrier

15. Which of the following is considered a 'barrerafsica'?

A. Monitoring of the travel tank

A cement plug
C. Periodic well control drills
D. Appropriate procedure for closing preventers (BOP)

16. If an influence is softened, which type of barrier has failed?

A. Permanent mechanical barrier

B. Operational barrier
C. Temporary Hydrostatic Barrage
D. Proven Barrera

17. A cable tool is lowered into a pressurized well. A lubricating assembly is used.
together with a wireline blowout preventer (wireline BOP). How would you classify the preventer?
with cable (wireline BOP) as a barrier?

A. Tertiary
B. Auxiliary
C. Primary
D. Secondary
 18. The well is filled with mud of 12.2 ppg (lb/gal) that settles and a plug is tested.
500 feet of cement to 2000 feet above the PVV (TVD). The mud above the
the plug is replaced with 10.2 ppg brine (lb/gal). If the cement plug fails,
What would happen to the pressure at the bottom of the well?

A. The BHP would decrease

B. The BHP would increase
C. The BHP would remain the same

19. What is a hydrostatic barrier?

A. The fluid pressure in a pipe closure chamber that maintains a

seal over a closed well
B. A mechanical seal inside the casing or well to isolate a potential flow
Cement located in an open hole or casing to isolate different areas
A column of fluid that exerts a higher pressure than that of the fluids of
training

WELL SIMULATIONS

20. What is the main reason for a drill in tanks (pools)?

A. To see how quickly the driller can align the system to the trip tank
B. To ensure that the crew is capable of effectively recognizing and reacting
facing a hint (kick suggestions)
C. To ensure that the crew is trained to kill (drown) the well
D. To test the tanks and flow alarms

21. Why is it important to monitor the volume in tanks (pools) during a

well construction operation?

A. To know when to adjust the pump speed

B. To know when to adjust the pressure of the drilling pipe (sonde bar)
C. To maintain constant pressure at the bottom of the well
D. To monitor gas expansion and fluid losses

22. The lodist (injectionist) turns on the degasifier and the desilter (de-argiller). What
What will happen with the flow (output) of the well?
 A. The flow will remain the same
B. The flow will increase after two to three minutes.
The flow will decrease after two to three minutes.

23. What is the main reason for a choke drill?

A. To ensure that the crew is trained to align correctly the

equipment for a well drowning with reverse circulation
B. To help the crew understand how the strangler and the
well pressures during a kill operation
C. To verify that the strangler is functioning correctly before
penetrate the casing shoe
D. To see how quickly the driller can close the choke in a
emergency

You are drilling with a 12 ½ inch bit (crown drill) at a speed of

average penetration of 95 feet/hour. In the last 60 minutes there was no
Changes in the level of the tanks (pools). What action would you take?

A. Prepare to mix sealing material (LCM) because you may be

losing some mud towards the formation
Check if the well flows to find out why the volume in tanks (pools) is
stable
C. Continue drilling, everything is going well
D. Increase the weight on the drill now that the penetration speed
he/she is stable

SHALLOW RISKS

25. Which of the following sentences is a good operational practice in a section?

Does the superior of the quetene pit pose risks of formations that contain gas?

A. Maintain a high penetration speed (VDP, ROP)

B. Control the penetration speed
C. Regularly pump light sweep pills
D. Never use a float valve in the drilling pipe (rods of
survey)

ANALYSIS OF PRESSURES
26. During drilling there were severe losses. The pumps were shut down and did not
I could see the mud in the well. Then the well filled to the brim with water and
remained static
Mud density 12ppg (lb/gal)
Brine density 8.6ppg (ln/gal)
Height of the water column in the annular space 150 feet

What is the pressure reduction at the bottom of the well with 150 feet of water compared to
with the pressure before the losses?

A. 67psi
B. 94psi
C. 30psi
D. 26psi

27. Calculate the Hydrostatic pressure:

9.0 lpg @ 2000 feet = _________

10.8 lpg @ 5300 pies = ________
13.5 lpg @ 7800 pies = ________

28. Calculate the Hydrostatic pressure:

0.8570 psi/pie @ 12900 pies = ________

0.9710 psi/pie @ 17180 pies = ________
0.4650 psi/pie @ 1400 feet = _________

29. Calculate the density of sludge drowning:

11290 psi @ 12700 feet = __________

1520 psi @ 3000 feet = ___________
4840 psi @ 7500 feet =___________

30. Calculate the density of the mud of choking:

1.0343 psi/pie = ___________

0.8000 psi/pie= ___________
o.1300 psi/pie=____________

31. Calculate the pressure gradient:

 11.2 lpg =_________
15.7 lpg =_________
18.0 lpg =_________

32. Calculate the pressure gradient:

7800 psi @ 10200 feet = ________

2980 psi @ 4500 feet =_________
18720 psi @ 18000 feet =________

33. What term is used for the total pressure felt at the bottom of the well when it
is it circulating around the same?

A. Hydrostatic pressure
B. Pressure at the bottom of the well
C. Pump pressure
D. Loss of system total pressure

34. What tool is part of the background assembly (EFP, bottom hole assembly, BHA) and
allows electrical logging (profiling) to be done on the well and to be monitored during
drilling operations?

A. The rotary and steerable drilling tool (steerable, RSS)

B. The single shot survey tool
C. The mud hydraulic motor (bottom motor, mud turbine)
D. The electrical logging tool (profiling, LWD) while drilling

35. A pressure tool while drilling (PWD) in the bottom assembly

well can provide information indicating that there is influx while drilling.
What information from a PWD (pressure while drilling) tool would indicate a
influence in the well?

A weight on bit (WOB) record of vibrations and torque

B. An indication of azimuth and elevation of the well
C. A reduction in the equivalent circulation density (ECD, DEC)
D. An increase in the equivalent circulation density (DEC, ECD)

U-tube effect
 36. 30 bbl of a 14.5ppg (lb/gal) pill are pumped before a trip for extraction.
the drilling string. The mud density is 12.3 ppg (lb/gal). What volume
In addition to the pill, we should expect a return due to the
positioning of the pill in the U tube?

A. 5.96 bbls
B. 7035 barrels
C. 5.36 barrels
D. 6.35 barrels

37. Its current mud density is 11.5 ppg (lb/gal). It is indicated to pump a pill of
35 bbl with a density of 13.5 ppg (lb-7gal). The capacity of your pipe (bar) of
The drilling is 0.0178 bbl/foot. What is the total volume that returns to the surface?

A. 41 bbls
B. 30 bbls
C. 70 bbls
D. 62 bbls

38. Its current mud density (MW) is 11.5 ppg (lb/gal). You are instructed to pump a
35 bbl pill with a density of 13.5 ppg (lb/gal). The capacity of its piping (bar) of
The drilling is 0.0178 bbl/foot. How many feet of dry pipeline (bar) will it have afterwards?
After having pumped?

A.34 feet
B. 342 feet
C. 321 feet
D. 84 feet

39. A well is closed. What is the pressure of the casing in this 'U' tube?

Well information:
Pressure reading in pipe = 0 psi
Well depth = 12000' TVD/12225' MD
Drilling string filled with water of 8.3 lpg
The annular space is filled with a gas/water mixture of 6.0 lpg.

A. 1435 psi
B. 1462 psi
C. 3744 psi
D. 5179 psi
 40. If the U-tube (well) has lost integrity due to leaks, how can it be determined?
this?

A. The pressure in the casing and the gain in tanks (pools) seem to increase with the
time while the flow circulates upwards.
B. The manipulation of the choke causes a change in the casing pressure.
and a predictable pressure response in the pipeline manometer (bars of
survey).
C. The manipulations of the choke cause unpredictable fluctuations
from the pressures of the casing and of the pipe.
D. Circulation with incomplete returns

41. A well is closed. What is the casing closure pressure in this U-tube?
(communicating vessel) static?

Well information:
The internal pressure of the pipe (sounding rods)
Indicates 0 psi (there is no float valve in the string)
Well depth = 7,000 PVT (TVD) / 7,225
PM (MD)
The drilling string is full of 9.7 ppg (lb/gal) mud.
The annular space is filled with a mixture of gas and mud of 6.0 ppg (lb/gal)

A. 1347 psi
B. 3530 psi
C. 1390 psi
D. 4920 psi

PRESSURE LOSS DUE TO FRICTION

42. How do losses due to annular pressure affect the bottom hole pressure?

A. It will make the BHP lower.

B. It will make the BHP equal to the hydrostatic pressure
C. I noticed no effect on the bottom pressure
D. It will make the BHP greater

43. When traveling at a speed of 100 spm, the boba pressure is 2300 psi. What
Will the new pump pressure be at 120 spm?
44. A pump pressure of 800 psi is recorded with 22 EPM (SPM). What will it be
approximately the pressure at 26 SPM?

A. 945 psi
B. 1117 psi
C. 882 psi
D. 1000 psi

45. When traveling at a speed of 60 spm with 10 lpg, the pump pressure is
950 psi. What will be the new pressure of the pump if the weight is increased to 12 lpg, the
The current depth of the well is 9587 feet?

46. What is a reduced pumping speed (VRB, SCR)?

A. Just like the speed of the pump when it is perforated

B. Between 20 and 50 strokes per minute (EPM, SPM)
C. 75% of the pump's speed when drilling
Between 80 and 100 strokes per minute (EPM, SPM)

47. What manometer is used to record reduced pumping pressure (RPP)?

A. The pressure gauge of the pump in the vertical pipe manifold (standpipe
manifold
B. The pressure gauge of the pump in the vertical pipe manifold (standpipe
manifold
C. The drilling pipe manometer (sounding bars) used to kill
(drown) the well.
D. The pressure manometer of the pump in the mud pump.

48. When would you consider taking a new reduced pumping pressure (PRB)?

A. Before and after a drip test (admission, leak off)

B. After recharging the shock absorber of the mud pump
C. When long sections of the well are drilled quickly
D. After each connection that is drilled with a top drive
 49. Are you circulating through the drill pipe and returning through the annulus? Which
Does the following affect the pressure at the bottom of the well?

A. Pressure loss in the drilling pipe (sondage bars)

B. Pressure loss through the surface line
C. Loss of annular pressure
D. Loss of pressure in the drill (borehole)

50. The bomb is turned off, the well is flowing, and there are gains in the pools (the tanks) of
side. The pump turns on again and the gain in the mud tanks is
Stop. What is happening?

A. The loss of pressure in the annulus is creating an overbalance against the pressure of
training.
B. The density of the mud inside the drilling pipe (drill rods) is
creating a counterbalance against formation pressure.
C. The pump pressure is greater than the hydrostatic pressure of the mud
The hydrostatic pressure of the mud is higher than the formation pressure.

FORMING PRESSURE

51. What is the most common cause of abnormally high formation pressures throughout
the world?

A. Layers of carbonates
B. Depleted arenas
C. Fluid trapped in lutites (shales)
D. Fractures in limestone

52. When drilling in a transition zone to a formation with abnormal pressure.

What changes do you expect to see in the mud?

A. Increase in sludge density

B. Increase in gas content
C. Reduction of sludge filtration
D. Decrease in gas content
53. When drilling in a transition zone to an abnormal pressure formation, what
What changes do you expect to see in the training based on what returns to the screens?

A. Reduction in the size of each cut (cutting)

B. Decrease in the density of the lutta cuttings (schist)
C. Decrease in the amount of debris
D. Increase in the density of the lutite cuttings (shale)

54. What abnormal pressure data does the Mud Logger (logging technician) typically measure?
data

A. Gas level in the mud

B. Weight on the drill
C. Weight on the hook
D. Strokes per minute

55. When drilling in a transition zone to a formation with abnormal pressure, what
What changes do you expect to see in the drilling data?

A. Reduction in the torque of the drilling string by more than 50%

B. Increase in weight on the drill (bore) to maintain the same ROP
C. A gradual increase of the VDP (ROP, rate of penetration)
D. Reduction of drag during connections

56. Which of the following is a possible warning sign of an increase in pressure?

of training?

A increase in the density of the lutta (schist)

B. Increase of gas in connection
C. Gradual decrease in penetration rate (VDP, ROP)
D. Decrease of bottom gas

57. calculate the equivalent density of mud that would fracture the casing shoe, using the
Admission test graph (drip, leak-off) below.

A. 13.9 ppg
B. 14.2 ppg
C. 13.7 ppg
D. 14.1 ppg
 58. Which of the following practices should be observed when conducting a test?
leak-off (L.O.T. or drip or admission)?

A. Always use water, pump quickly and turn off the pump when the trend between
pressure and volume change.
B. Pump slowly, use a known mud density, and turn off the pump when the
The trend between pressure and volume changes.
C. First establish an injection cup, use known mud density and pump
at a fast speed.
D. Move the drill string (sondeing rod) with base oil or water, close the
well and pump slowly until the formation starts to take fluid.

59. When should you recalculate the maximum allowable annular pressure at the surface?
(MAASP)?

A. After a change in the density of the mud

B. After changing the drill (trepan)
C. After every 300 to 500 feet drilled
D. Each turn

60. What will happen to the MAASP if the density of the sludge decreases?

A. The MAASP will increase

B. The MAASP will decrease
C. The MAASP will remain the same

GAS MIGRATION

61. Is a gas kick (surge) circulated out of the well using the method of
driller, what happens to the pressure at the bottom of the well if the bubble is not allowed to
Does gas expand as predicted while it is being circulated upward through the well?

A. Increases
B. Falls the same
C. Decreases

62. What best describes the effect of gas migration on closing pressure?
internal of the pipe (sounding bars) (assuming there is no float valve inside)
the same one?)
 A. Decreases
B. Falls the same
C. Increases

63. What could happen if the gas migrates after the well is closed and the pressures have
stabilized (there is no float valve in the string)

A. Both the pipe (bar) pressures and the annular pressures will increase.
B. Only the internal closing pressure of the pipe (bars) will increase.
C. Only the internal closing pressure of the pipe (bars) will increase.
D. Closure pressures will remain constant

64.