QUIZ # 1

1. Which of the following is an inert solid used only to increase the weight of the drilling mud?
A. Bentonite
B. Attapulgite
C. Gypsum
D. Barite

2. Which of the following is not a component of the hoisting equipment for a drilling rig?
A. Crown Block
B. Draw works
C. Drilling line
D. Rotary Table

3. SLIP AND CUT

a. To replace the drilling line wrapped around the crown block and traveling block.

4. Kick Tolerence

a. The max vol of mud that can be circulated inside a well.

b. The max KMW that should be used in the case of kick

c. The max vol of kick that can be safely shut in and circulated out of the hole without breaking the formation.

d. SIDP=SICP=0

5. Kick Tolerence changes with

a. Mud weight

b. Depth

c. Kick Type

d. Formation Pressure

e.  All of the above

P &P 2

Q1. What is the primary means of preventing kick from occurring?

a. Using reducing pump rate and circulating pressure to kill the well.

b. Use of instrumentation to detect and warn for kicks.

c. The use of blow out preventer to close in a flowing well.

d. Using a combination BOPs and drilling fluid hydrostatic pressure.

e. Using of drilling fluid hydrostatic pressure to balance formation pressure.

Q2. A gas bearing formation is over pressured by an artisan effect. Which of the following condition has created the over pressure?

a. Compaction of the formation from the over burden.

b. Formation water source located at a higher level than the rig floor.

c. The difference in length between gas & formation fluid.

Q3. The formation pressure at 9300 ft TVD is 6320 psi. Which one of the option will be correct in case the pressure gradient of the drilling fluid is 0.842 psi/ft?

a. The well is overbalanced.

b. The well is under balanced.

c. The well is balanced.

Q4. At a depth of 10000 ft the formation pressure is 5200 psi. This formation pressure is:

a. Above normal.

b. Below normal.

c. Normal.

Q5. Calculate with following data:

Drill Pipe Capacity = 0.0176 bbls/ft

Drill Pipe Metal Displacement = 0.0082 bbls/ft

Average Stand Length = 92 ft

5a. How much mud is required to fill hole per stand when pulled out dry.

a. 0.75 bbls

b. 2.37 bbls

c. 0.32 bbls

d. 5.56 bbls

5b. How much mud is required to fill hole per stand when pulled out wet?

a. 0.75 bbls

b. 2.37 bbls

c. 0.32 bbls

d. 5.56 bbls

Q6. After having pulled 15 stands of drill pipe from the well the trip sheet confirm that fluid or gas has been swabbed into the well. A flow check is carried out and the well is static. Which one of the option is the best procedure for handling this problem?

a. Close the well immediately and check for pressure.

b. Trip or strip back to bottom and circulate bottoms up.

c. As the well is not flowing, continue pulling the string out of the hole.

d. Pull another 5 stands and check for flow.

Q7. A vertical well is drilled to a depth of 10,500 ft with 11.7 ppg mud and following are the recorded data:

WELL DATA:

Pump speed: 70 spm.

Pressure losses in surface equipment: 180 psi

Pressure losses in drill string: 900 psi

Pressure losses in annulus: 120 psi

Pressure losses at bit nozzles 1600 psi

(i). Calculate Bottom Hole Pressure when well is static

a. 2800 psi

b. 6508.2 psi

c. 6388.2 psi

d. 3655.5 psi

(ii). Calculate Bottom Hole Pressure when mud is circulated at 70 spm

a. 2800 psi

b. 6508.2 psi

c. 6388.2 psi

d. 3655.5 psi

(iii). Calculate pump pressure when mud is circulated at 70 spm

a. 2800 psi

b. 6508.2 psi

c. 6388.2 psi

d. 3655.5 psi

(iv). Calculate the equivalent circulating density

a. 11.92 ppg

b. 12.30 ppg

c. 11.7 ppg

d. 0.22 ppg

Q8. When circulating around the well at 60 SPM with 10 ppg mud, the pump Pressure is 950 psi. What would be the pump pressure be if the mud weight was raised to 12 ppg. Drilled depth of the well is 9587 ft.

a. 950 psi

b. 792 psi

c. 1040 psi

d. 1140 psi

Q9. The Stand pipe pressure at 70 SPM was 2000 psi using 11 ppg drilling fluid. What will be the approximate pump pressure after having increased the drilling fluid density to 13 ppg and reduce the pump rate to 50 SPM ?

a. 4633 psi

b. 1206 psi

c. 2364 psi

d. 1021 psi

Q10. Which of the following causes of well kick is totally avoidable and is due to lack of alertness of driller? (Select two answers)

a. Drill pipe is lowered too fast in heavy mud causing lost circulation

b. Gas cut mud

c. Abnormal pressure

d. Not keeping hole full

Q11. With following well data, calculate the reduction in bottom hole pressure if a driller has pulled out 15 stands of 5” drill pipe dry, without filling the hole.

Drill pipe capacity – 0.0176 bbl/ft

Drill pipe steel displacement – 0.0080 bbl/ft

Casing capacity – 0.0733 bbl/ft

Length of one stand – 90 ft

Mud weight – 12 ppg

a. 81.14 psi

b. 0.06 psi

c. 103.21 psi

d. 0.076 psi

Q12. Which of following practices are likely to increase the chances of swabbing?

(Select three answers)

a. Maintaining high drilling fluid viscosity.

b. Puling through tight spots with pumps on.

c. Pumping out of the hole.

d. Pumping low viscous pill.

e. Pulling pipe fast.

f. Pulling pipe slowly.

g. Pulling through the tight spots with the pumps stopped.

Q13. In a well, during trip out swabbing was suspected. The flow check was negative and it was decided to run back to bottom (30 stands) checking for flow after lowering every 5 stands. The flow checks after 5, 10, 15 & 20 stands showed no flow. But with stand number 25 back in the hole, the well was found to be flowing.

What could be the most likely cause of the well flow?

a. Abnormal formation fluid pressure.

b. Derrick man mixed too light a slug prior to pulling out of the hole.

c. Running into the swabbed fluids caused hydrostatic pressure in annulus to drop.

d. In the hurry, it was forgotten to slug the pipe while preparing for running back.

14. For the following well data how many 90 ft length stands can be pulled out dry before the well starts to flow.?

Well Depth: 10,750 ft TVD

Casing Shoe Depth: 5,930 ft TVD

Mud Gradient : 0.798 psi/ft

Formation Pressure : 8,410 psi

Casing Capacity : 0.1499 bbl/ft

Open Hole Capacity : 0.1458 bbl/ft

Drill pipe Metal Displacement : 0.0080 bbl/ft

Drill Pipe Capacity : 0.0176 bbl/ft

a. 40

b. 41

c. 42

d. 43

Q15. If the pit level increases when the pumps are off but stays constant when pumps are running. What is the problem?

a. Annular pressure losses are giving overbalance against formation pressure.

b. Mud hydrostatic pressure is greater than formation pressure.

c. The pumps need to be repaired.

d. Pump pressure is greater than mud hydrostatic pressure.

Q15. What will be the reduction in bottom hole pressure if 8 stands of drill pipes are pulled out wet without filling the hole? (Mud bucket was not used)

One stand length : 92 ft

Casing Capacity : 0.0745 bbls/ft

Drill Pipe Capacity : 0.0176 bbls/ft

Drill pipe steel displacement : 0.0080 bbls/ft

Mud Weight : 13.5 ppg

a. 204 psi

b. 503 psi

c. 512 psi

d. 216 psi

Q17. In a well while tripping out the hole was filled during pulling drill pipes. Thereafter the trip tank pump was stopped and the complete BHA was pulled out wet.

Using following data, calculate approximate reduction in the bottom hole pressure.

BHA length – 531 ft

BHA capacity – 0.009 bbls/ft

BHA Steel Displacement – 0.068 bbls/ft

Annular Capacity, BHA to 13 3/8” Casing – 0.07 bbls/ft

Casing capacity – 0.147 bbls/ft

Mud Density – 11 ppg

a. 159 psi

b. 141 psi

c. 115 psi

d. 19 psi

Q18. While drilling a vertical well at a depth of 9,000 ft with 13 ppg mud. Gas cut mud was observed at shale shaker. Tool Pusher decided for bottoms-up monitoring of out coming mud. They recorded average mud weight of:

12.5 ppg for 0 to 900 ft

12.8 ppg mud for 900 ft to 1500 ft

13.0 ppg mud for 1500 ft to 9000 ft.

Due to the gas cut mud, how much was the reduction in bottom hole pressure?

a. 15 psi

b. 25 psi

c. 30 psi

d. 60 psi

Ans: c

Q19. Is it true that the original drilling fluid density will be sufficient to control the formation pressure once stripped back to bottom if a kick has been taken off bottom due to swabbing?

a. Yes

b. No

Q20. It was decided to reduce the mud weight from 12.4 ppg while tripping in the well of 9,880 ft TVD. String was run to 5,950 ft and original mud was displaced by 10.8 ppg mud.

(i). What will be the bottom hole pressure now?

a. 6043 psi

b. 5548 psi

c. 6370 psi

d. 5875 psi

(ii). When string was run down to bottom the entire well was displaced by 10.8 ppg mud. Calculate the bottom hole pressure in static condition.

Q21. What is the definition of MAASP?

a. The total pressure applied at casing shoe that can cause losses at shoe.

b. The surface casing pressure that in addition to hydrostatic pressure is likely to cause losses at the shoe formation if exceeded.

c. The maximum pressure allowed on the casing gauge during a kill operation.

d. The maximum pressure allowed on the drill pipe gauge during a kill operation.

e. The maximum bottom hole pressure allowed during a kill operation.

Q22. While drilling, the mud weight was increased from 12 ppg to 13.5 ppg expecting higher formation pressure below. How this increase of mud weight will affect MAASP (the casing shoe is at 4697ft/5500 ft)?

a. Increase by 366 psi

b. Decrease by 366 psi

c. Increase by 429 psi

d. Decrease by 429 psi

Q23. Which of the following are important for the calculation of formation strength at the shoe? (Select three answers)

a. Accurate pump strokes counter.

b. Accurate pressure gauge.

c. Exact mud density.

d. Exact vertical depth of casing shoe.

e. Accurate hole capacity.

f. The pressure limit for the pump.

g. Exact measured depth of the casing shoe.

Q24. Select three parameters that influence the MAASP?

a. The fracture pressure of the formation at casing shoe.

b. The dia of last casing string.

c. The pump rate when performing the formation strength test.

d. The density of the drilling fluid.

e. The maximum allowable pump pressure.

f. The casing shoe depth of the last casing string.

Q25. After lowering casing, which of the following operations are to be taken care of prior to conducting a leak —off test. (Select two answers)

a. Drill casing shoe and about 10 ft in to new formation.

b. Keep the bit close to bottom.

c. Circulate and condition the mud to get uniform column of mud in the well.

d. Line up pump to conduct leak off at slow circulating rate.

Q26. What is normal formation pressure normally assumed to be?

a. 0.433 psi/ft.

b. 1 psi/ft

c. 0.465 psi/ft

d. 0.5 psi/ft.

Q27. A casing is set at a depth of 7260 ft and true vertical depth of casing shoe is 6298 ft. After drilling shoe and new formation, leak off test was conducted with 11.2 ppg mud. It was found that the formation strength is 5400 psi.

Find out the maximum allowable annular surface pressure (MAASP).

a. 1171 psi

b. 5400 psi

c. 3668 psi

d. 1732 psi

Q28. Calculate the fracture strength at casing shoe for the following data:

Shoe TVD: 5500 ft

Test Mud Weight: 12 ppg

The Casing Pressure – Volume Pumped graph deviated after 600 psi

a. 4032 psi

b. 2832 psi

c. 6032 psi

d. 3432 psi

Q29. Calculate maximum allowable mud weight for the following data:

Well Depth: MD 15,050 ft / TVD 13,090 ft

Casing Shoe Depth: MD 11,000 ft / TVD 10,550 ft

Casing Shoe leaked with 11 ppg mud at 1675 psi

a. 13.14 ppg

b. 13.46 ppg

c. 13.93 ppg

d. 14.05 ppg

Q30. when a gas kick. which three conditions in e well are likely to increase the risk of exceeding the MAASP during e well kill operation?

a Small influx

b Large influx

c. Long open hole section.

d Short open hole section.

e. Small difference between the formation strength pressure at the shoe and drilling fluid hydrostatic pressure.

f. Large difference between the formation strength pressure at the shoe and drilling fluid hydrostatic pressure.

Q31. Which of the following possible warning signs indicate that well may go under balance? (Select two answers)

a. Increase in pump pressure.

b. Reduction in rate of penetration.

c. Change in cuttings size & shape.

d. Increase in drilled gas percentage.

Q32. Which of the following equipment may warn of increase in formation pressure while drilling overbalance? (Select three answers)

a. ROP meter

b. Flow line Temperature gauge

c. Gas detector

d. Return flow meter

Q33. After recognizing a drilling break, what is the first action to be taken?

a. Make a flow Check

b. Circulate bottoms up

c. Continue drilling

d. Reduce pump speed

Q34. From all the following indications, which TWO indications would have little room for doubt that the well is kicking?

a. Increased rotary torque.

b. Flow rate increase.

c. Pit volume gain.

d. Increased rate of penetration.

Q35. Will a kick always occur in the event of a loss of return?

a. No. it depends on the mud level in the annulus and the formation pressure.

b. No, it depends on the drill string weight reduction noted on the weight indicator.

c. Yes, losses will always occur above any potential kick zone.

d. Yes, loss of return is always followed by a kick.

Q36. Which one of the following is the first reliable indication that well is flowing?

a. Increase in torque.

b. Gas cut mud.

c. Decrease in pump pressure.

d. Increase in return flow.

Q37. Which one of the following be the first action to be taken, if the mud pump safety  valve pops-off or hose going to the drill string is parted while circulating out a kick?

a. Drop the drill string, close blind/shear rams, close the choke.

b. Stop the pump, close the choke.

c. Stop the pump, close Kelly cock, close choke.

d. Repair pump or hose and resume well killing.

Q38. Which of the following situation make kick detection more difficult with PVT while drilling?

a. By passing solid control equipment

b. Minimum mud transfer to active system

c. Allowing mud loss by over flowing the shakers

d. Reducing the range of high /low alarm setting of PVT

Q39. Which of the following drilling practices would be considered when connection gas is noticed? (Select two answers)

a. Pulling out of the hole to change the bit.

b. Raising the mud yield point.

c. Minimizing the time during a connection when the pumps are switched off.

d. Controlling drilling rate so that only one slug of connection gas is in the hole at a time.

Q40. A slug pill is being circulated around the well. When BHP will first increase?

a. When the pill is about to exist the bit.

b. When the beginning of slug pill enters the annulus through the bit.

c. When the beginning of slug pill enters the drill string.

d. When the end of the slug pill has gone through the bit and is displaced in the annulus by the original drilling fluid.

Q41. If the cuttings volume in the annulus was high and the well had been shut in on kick. Would the drill pipe pressure be higher than in a clean well?

Yes OR No

Ans:

Q42. If the cuttings volume in the annulus was high and the well had been shut in on kick. Would the casing pressure be higher than in a clean well?

Yes OR No

Q43. The influx is usually circulated out at a pump rate considerably slower than that used while drilling. What are the reasons for that?

(Select two answers)

a. To enable the choke operator to make the necessary choke adjustment.

b. To get adequate time to dispose off the kick fluid at surface.

c. To allow experts to reach the well site.

d. It is difficult to increase pump rate with the influx in the annulus.

Q44. Which of the following should be considered while selecting kill rate SPM? (Select two answers)

a. Volume handling capacity of chokes.

b. Formation pressure.

c. Rated working pressure of BOP.

d. Capacity of kill mud preparation.

Q45. Which of the following situations require recording of a slow circulating rate (SCR) pressure? (Select two answers)

a. Only after drilling out casing shoe.

b. At beginning of each shift.

c. Every time mud density is changed.

d. After carrying out LOT.

Q46. When should the slow circulating rate pressure be recorded?

(Select two answers)

a. Each time when drilling rate changes.

b. When bit nozzle size is changed.

c. After installation of BOP.

d. After liner size of pump is changed.

Q47. Match each of the following statements to one of the answers below:

1. Amount of space between the grains of rock .

2. Rock ability to allow flow of formation fluid through It

3. The presence of formation fluids within the pore spaces

4. Momentary increase in BHP

a. Porosity

b. Formation Pore Pressure

c. Permeability

d. Surging

P & P 1

Q1. What is meant by PRIMARY WELL CONTROL?

a. The use of Blow Out preventers to close in a well that is flowing

b. The slow Circulating Rate Pressure used in the kill process

c. The use of Mud Hydrostatic to balance fluid pressures in the formation

d. The use of Pit Volume and Flow rate measuring devices to recognize a kick
Q2. In an open well with gas cut mud when is bottom hole pressure reduced the most?

a. When the gas is at the surface

b. When the gas is at bottom

c. When the gas is at the casing shoe

Q3. When you would consider taking a slow circulating rate pressure?

(Select two answers)

a. Only after drilling out casing shoe
b. At beginning of each shift
c. Every time mud density is changed
d. Immediately after cementing

Q4. Which of the following parameters are required for accurate formation strength?

(Select three answers)

a. Accurate pump stroke counter.
b. Accurate pressure gauge.
c. Exact mud density.
d. Hydrostatic pressure in casing.
e. Accurate hole capacity.
f. Measured depth of casing.

Q5. Which factors can increase pressure surges while running in ?

(Select four answers)

a. Large annular clearance

b. Small annular clearance

c. High viscous mud

d. Running in at fast speed

e. Large size nozzles

f. Low viscous mud

g. Running in at slow speed

h. Balled up stabilisers

Q6. Which of the following statements are considered to be good operating practices in TOP HOLE where there is a risk of gas bearing formation?

( Select two answers )

a. Circulating while pulling out of the hole on trips

b. Use a high density mud to create maximum overbalance

c. Drill a pilot hole

d. Maintain high rates of penetration to ensure mud viscosity level is as high as possible

e. Regularly pump fresh water pill to remove the cuttings from the hole

Q7. Which of the following conditions help in selecting kill rate?

(Select two answers)

a. Capacity of kill mud preparation

b. Trip tank volume

c. Volume handling capacity of the choke

d. Formation pressure

Q8. If the mud weight is increased during drilling what will happen to the MAASP?

a. MAASP will increase
b. MAASP will remain same
c. MAASP will decrease

Q9. Which one of the following is the most reliable indication thatawell is flowing?

a. increase in torque

b. Gas cut mud

c. Decrease in pump pressure

d. Increase in flow returns

Q10. Select the roducts commonl used to prevent the formation of hydrates?
(Select Two Answers)

a. Glycol.

b. Carboxy Methyl Cellulose(CMC).

c. Water

d. Methanol

Q11. Which of the following possible warning signs indicate that well may go under balance? (Select two answers)

a. Increase in pump pressure
b. Change in cuttingsisize & shape
c. Reduction in rate of penetration
d. Increase in drilled gas percentage
e. Increase in weight on bit

Q12. It can be said that closing in the well promptly is one of the most important duties of a Driller. Any delay may make the well potentially more difficult to kill. From the list shown below, tick the most likely practices which can lead to an increase in the size of the influx:

(Select three answers)

a. Switching off the flow meter alarms

b. Regular briefing for the Derrick man on his duties

c. Drilling a further 15 feet after a drilling break, before flow checking

d. Running regular pit drills for drill crew

e. Testing stab—in valves during BOP tests

f. Calling tool pusher to floor prior to shut—in the well

Q13. A kick is being circulated out at 35 SPM, Drill Pipe Pressure reads 650 psi, and Casing Pressure 1050 psi. It is decided to slow the pump to 30 SPM while maintaining 1050 psi on the casing gauge.

How will this affect bottom hole pressure (Exclude any ECD effect ) ?

a. Increase

b. Decrease

c. Stay the same

d. No way of telling

 Q14. The reason shut in casing pressure is usually higher than the shut-in drill pipe pressure is because?

a. The cutting in the annulus are lighter, therefore creating a lighter hydrostatic in the annulus
b. The influx is usually less dense than the existing mud weight
c. The casing pressure is not necessarily higher, it depends on whether it is an offshore or
land operation
d. The only difference is in the gauges used

Q15. After shutting in on a kick the SIDPP and SICP have stabilized, then they both start slowly rising by the same amount. What is the probable cause?

a. A further influx is occurring

b. The influx is gas 8. migrating up the Well Bore

c. The gauges are faulty

d. The BOP stack is leaking

Q16. Select 3 conditions which you feel will increase the risk of exceeding the MAASP during a well kill operation?

a. Small difference between formation breakdown pressure and mud hydrostatic pressure

b. Large difference between formations breaks down pressure and mud hydrostatic pressure

c. Long open hole section

d. Short open hole section

e. Large influx

f. Small influx

Q17. For each of the following statements tick whether it relates to the Driller’s method or the Wait and Weight method.

a. Remove influx from well before pumping kill mud
Driller’s OR Wait and Weight

b. Pump kill mud whilst circulating influx up the annulus
Driller’s OR Wait and Weight

Q18. What is the approximate pressure pulse travel rate in the mud?

a. 4.5 ft/sec

b. 750 ft/min

c. 1000 ft/sec

Q19. What should be done when complete loss of return occurs while drilling 7

a. Pump heavy mud in the annulus

b. Pump cement in to the annulus

c. Prepare to pump LCM immediately

d. Fill and top up the annulus with lighter fluid available (e.g. water) monitoring and properly recording the volume filled in.

Q20. Well is shut-in SIDPP is recorded but SICP gauge is broken ,which of the following pressure can not be calculated?

a. Casing Shoe Pressure
b. Formation Pressure
c. Bottom Hole Pressure
d. Initial circulating Pressure

Q21. When there are more cuttings in the system, which of the following is true?

a. It will increase the difference between SICP 8. SIDPP
b. It will decrease the difference between SICP 8. SIDPP
c. It will have no effect on SICP 8. SIDPP

Q22. Which of the following could be the immediate effect of swabbing?

a. lncrease in Bottom Hole Pressure

b. A kick

c. Reduction in Bottom Hole Pressure

d. Lost circulation.

Q23. During well control operation, power failed 8. well is shut in .After some time both SICP and SIDPP started rising. To maintain BHP constant which pressure is to be maintained?

a. SIDPP

b. SlCP

c. Influx Pressure

d. Casing Shoe Pressure

Q24. You are pulling out, after 15 stands it was found that the hole is not taking proper amount of mud. What action you are going to take?

a. Shut in the well

b. Run back to bottom

c. Pull out another 5 stand and flow check again

d. Flow check if negative run back to bottom and circulate out monitoring returns

e. Continue pulling out

Q25. If the pit leveI increases when the pumps are off, but stays constant when the pumps are running”. What is the problem?

a. Annular pressure losses are giving an overbalance against formation pressure.

b. Mud hydrostaticpressure is greater than formation pressure.

c. The pumps need to be repaired.

d. Pump pressure is greater than mud hydrostatic pressure.

Q26. Kill rate circulating pressure are taken at different pump rate (SPM). Which one of the following should be used to determine the maximum pump rate to use to kill the well?

a. Mud/Gas separator limit.
b. Size of the casing.
c. Depth of the casing shoe.

Q27. Which is not the indication that well may be kicking?

a. Increase in flow rate

b. Decrease in pump stroke

c. Decrease in pump pressure

d. Pit gain

Q28. Which of the following factors will affect the MAASP?
(Select two answers)

a. Casing Shoe Depth

b. Diameter of casing

c. Shoe Fracture strength

d. Water loss

e. Maximum allowable pump pressure

Q29. During well killing operation Driller reduces the pump speed from 35 SPM to 30 SPM maintaining drill pipe pressure constant .What will happen to Bottom Hole Pressure?

a. Increase
b. Decrease
c. Stay the same

Q30. Calculate reduction in bottom hole pressure due to gas cut mud with the following data, the original mud density being 13.0 ppg: –

Depth Interval             Average Mud Weight

0 -1000 ft.                           12.3 ppg
1.1 000- 2000 ft.                12.7 ppg
2000- 9800 ft                    13.0 ppg

Q31. The following statement describe one of the differences between drilling with oil base and water base mud.

“Gas entering the well bore while drilling with oil base mud will reduce the hydrostatic pressure more than it would when drilling with water base mud”

a. True.
b. False.

Q32. In a well of 9450 ft. depth 25 bbls of slug of 12.8 ppg was pumped , mud level in drill string dropped by 358 ft. What will be the change in BHP if mud in use is 10.2 ppg & drill string capacity is 0.0178 bblslft ?

a. 0 psi

b. 142 psi

c. 113 psi

Q33. Which of the following situation make kick detection more difficult with PVT while drilling?

a. By passing solid control equipment

b. Minimum mud transfer to active system

c. Allowing mud loss by overflowing the shakers

d.Changing the high/ low alarm setting of the PVT

Q34. Which of the following well control problems requires the pump to be shut down quickly to prevent over pressurizing open hole formation?

a. A plugged bit nozzle.

b. A pump liner wash out.

c. A wash out in the drill pipe.

d. A lost bit nozzles.

e. A wash out in the choke manifold.

f. A plugged choke.

Q35. Which of the following parameter will effect the rate of initial pressure build up?

a. Gas migration
b. Only porosity
c. Permeability
d. All of the above

Q36. A flowing well has been shut in. The drill pipe pressure is ‘0’ because there is a non-return valve in the string. To determine the SIDPP. What action should be taken?

a. Bring the pump up to kill rate holding the casing pressure constant by opening the choke. The pressure shown when the pump is at kill rate is SIDPP.

b. Pump very slowly into the drill pipe with the well shut in. When the pumping pressure
stabilizes the float has opened. This pump pressure is equal to SIDPP.

c. Shearing the pipe and reading the SIDPP directly from the casing gauge

Q37. The drill pipes are being stripped in to the well with annular preventer closed

Drill pipe capacity 0.01776 bblslft
Drill pipe metal displacement 0.0087 bblslft

Length of one stand 90 ft

i). How much mud is to be bIeed—off after stripping in pipe?
a. Equal to closed end volume of the pipe stripped in
b. Equal to the steel displacement of the pipe stripped in
c. Equal to the capacity of the pipe stripped in

ii). How much mud is to be filled in the pipe after stripping one stand in bbl

Q38. While circulating out a kick mud pump failed. What first action is to be taken?
a. Shut in the well
b. Change mud pump
c. Repair the mud pump

Q39. How the choke wash-out can be recognized while well killing?
a. Continuously opening choke to maintain correct circulating pressures
b. Rapid rise in casing pressure no change in drill pipe pressure
c. Continuously closing choke to maintain correct circulating pressures
d. Rapid rise in drill pipe pressure no change in casing pressure

Q40. Answer the following if Well is killed using Weight & wait method :-

i). When the FCP is to be maintained constant ?
a. When kill mud reaches casing shoe
b. After kill mud reaches bit
c. When kill mud is pumped down the string
d. When influx is out of hole

ii). When surface line volume is 5 bbls , what is to be done ?
a. Ignore it
b. Re—set stroke counter after kill mud reaches drill string
c. Subtract 150 strokes from surface to bit strokes and recalculate step down

Q41. What will happen to mud pit volume when the gas is circulated up the hole?

a. increases
b. Decreases
c. Remains same

Q42. During killing operation sudden loss in drill pipe pressure is observed. What action should be taken?

a. Continue killing at same rate

b. Increase the pump rate

c. Close choke to compensate for pressure loss in drill pipe

d. Shut the well & investigate the problem of pressure loss

Q43. While pulling out the well starts flowing, what first action is to be taken?

a. Run back to bottom
b. Install FOSV, close it & shut the well
c. Connect kelly & circulate

Q44. With the following data calculate the number of stands that can be pulled out dry before the wellstarts to flow.

Shoe depth: 5,000 ft

Well depth : 8,500 ft

Mud weight : 13.5 ppg

Pore pressure gradient 0.685 psi/ft

Casing capacity : 0.147 bbl/ft

Open hole capacity 0.138 bbl/ft

D/P metal displacement : 0.0082 bbl/ft

Average stand length: 88.5 ft

Q45. What is the definition of MAASP?

a.The maximum BHP can be allowed during kill operation

b. The maximum drill pipe pressure that can be allowed during kill operation

c. The surface pressure in excess of mud hydrostatic that if exceeded is likely to cause losses at shoe

d. The total pressure applied at casing shoe that can cause losses at shoe

Q46. While killing a well, sudden increase in drill pipe pressure was noticed but the casing pressure remain unchanged. What is the probable cause? (Select two answers)

a. Blockage in stand pipe / drill pipe

b. Bit nozzle plugged

c. Choke plugged

d. Pressure build up in MGS

Q47. Which of the following problems needs immediate stoppage of mud pumps ?

a.Partial nozzle plugging

b. Nozzle washout

c. Choke plugging

d. String washout

Q48. Derrick man observed that shakers are overflowing due to increased cuttings coming out in mud returns. What is the safest action to be taken?

a. Slow down pumps until shakers can handle the flow & continue drilling

b. Flow check if negative, circulate at reduced rate so that shakers can handle the flow

c. Flow check if negative, continue circulating at same rate

d. Flow check if negative, return at original drilling parameters

Q49. A 10000 ft well (TVD) is killed after a kick. The additional mud weight required to provide a trip margin equal to an increase in BHP of 250 psi is

a. 0.5 ppg
b. 0.2~0.3 ppg
c. 0.3 ppg

Q50. At what point casing shoe pressure will be maximum while circulating out a gas kick?

a. When kill mud reaches bit
b. When kill mud reaches shoe
c. When top of gas reaches shoe.
d. At initial shut in.

Q51. Calculate the mud level increase in the trip tank after pumping 25 bbls of 16.5 ppg slug

Mud in use 12.2 ppg
Drill string capacity 0.0177 bbls /ft Ans: —————————- –bbl
Well TVD 10200 ft

Q52. When drilling with a surface BOP installed, how should the stack and choke manifold be set up for a soft shut-in? ( Select three answers )

a. BOP side outlet hydraulic choke line valve open.

b. BOP side outlet hydraulic choke line valve closed.

c. Open circuit from remote choke down to the mud gas separator.

d. Remote choke open.

e. Remote choke closed.

f. One valve closed between remote choke and mud gas separator.

Q53. Over pull while tripping out is a stuck pipe warning sign. What well control problem may be associated with over pull?

a. The presence of hydrocarbons.

b. Swabbing.

c Surging.

d A flowing well.

Q54. What is the first action to take if, while circulating out a kick, the chiksans or hose going to the
drill string parted?

a. Drop the drill string and close the blind/shear rams.
b. Close the shear rams. (Shear ram above the pipe ram being used).
c. Stop the pump, close the full opening safety valve on the drill string then close the choke.

Q55. Calculate the new slow circulating pressure at 30 spm if mud weight has been increased from 10 ppg to 12 ppg: ‘

Recorded data:

SCR @ 30 spm: 400 psi

Drilled depth – 9587 ft

Mud density: 10 ppg

a. 333 psi

b. 576 psi

c. 480 psi

d. 525 psi