73236775 3 Well Control Exercises

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EXERCISE # 1

1. What mud weight is required to balance a formation pressure of 2930 psi at 5420 ft TVD?

___________ppg

2. If the fluid level dropped 550 ft in a 9600 deep hole containing 10.6 ppg mud, what would the hydrostatic at bottom be?

___________psi

3. Bottom hole pressure is reduced the most by gas cut drilling mud when: a. The gas is near the surface

b. The gas is at or near the bottom

c. The gas is about halfway up the well bore d. All are about the same

4. After a round trip at 8960 ft with 10.9 ppg mud, we kick the pump in and start to circulate. An increase in flow was noticed and the well was shut in with 0 psi on the drill pipe and 300 psi on the casing. What kill mud is required? (no float in the drill string)

___________ppg

5. What was most probable in causing the influx or well kick in the last question? a. Abnormal pressure was encountered

b. The mud weight was not high enough to contain formation pressure c. It was swabbed in or the hole was not properly filled while pulling out d. It is impossible to tell

6. Which of the following circumstances would increase the chance of swabbing in a kick? a. High pulling speed

b. Mud properties with high viscosity and high gels c. Tight annulus BHA/hole clearance

d. Mud density in use is close to formation pressure

7. In which of the following cases would you be most likely to swab in a kick? a. When the bit is pulled up into the casing

b. When the first few stands are being pulled off bottom c. About half way up the well

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8. When drilling with 10.3 ppg mud at 11600 ft TVD the annular loss is estimated at 195 psi. What is the BHCP?

_________psi

9. You are pulling out of hole. Two x 93 ft stands of 8" drill collars have been stood back in the derrick. The displacement is 0.0538 bbls. / ft. According to your Assistant Driller, 10 bbls should be pumped into the well. It only takes 10 bbls to fill the hole. (Answer yes or no to each question)

a) Are the calculations correct? b) Have you taken a 5 bbls influx? c) All Ok, keep going

10. You have taken a kick and shut the well in. The active tank while drilling contained 250 bbls. And the mud return line to the pits contains 25 bbls.

The tank now contains 300 bbls. How many barrels of mud have been displaced from the well?

a) 0 bbls b) 25 bbls c) 50 bbls d) 275 bbls

11. The Fracture Gradient of an open hole formation at 3680 ft. is 0.618 psi/ft. The drilling mud currently in use is 9.8 ppg. Approximately how much Surface Casing Pressure can be applied to the well before this formation breaks down?

a) 350 psi b) 2275 psi c) 630 psi d) 400 psi

12. A gas kick is being circulated out. At the time the gas reaches the casing shoe (4250 ft. TVD), the pressure at the top of the bubble is 3000 psi. If the original mud weight is 12 ppg, what is the casing pressure at the surface? (Hole TVD 7000ft)

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Questions 13-14 are based on the following information:

13 3/8” surface casing is set and cemented at 4250 ft. (TVD). The cement is drilled out together with 15 ft. of new hole, using a 11 ppg mud. A leak off test pressure of 800 psi is determined. (Hole TVD 7000ft)

13. What is the formation fracture gradient? a) 0.188 psi / ft

b) 0.686 psi / ft c) 0.760 psi / ft d) 0.384 psi / ft

14. What is the maximum allowable annular surface pressure for 12.3 ppg mud in use at 7350ft. TVD :

15. How often should the MAASP be recalculated? a) After every bit change

b) After a change in mud weight c) After every 500 ft. drilled

16. Calculate the equivalent circulating density in the following circumstances: Circulating pressure = 3100 psi

Pressure losses:

Surface equipment = 20 psi Drill string = 930 psi

Nozzles = 1800 psi Annulus = 350 psi Drilled depth: 12,300 ft. (11,500 ft. TVD) Mud weight: 11.4 ppg ECD is: a) 10.8 ppg b) 12.0 ppg c) 11.4 ppg d) 12.3 ppg

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17. Drill pipe capacity = 0.0178 bbls/ft

Drill pipe metal displacement = 0.0082 bbls/ft Average stand length = 93 ft

Calculate :

a) Mud required to fill the hole per stand when pulled „dry‟ (bbls per stand)

b) Mud required to fill the hole per stand when pulled „wet‟ (bbls per stand)

18. You are determining your kill rate pressure and bringing your pump rate up to a pre-determined 30 SPM by holding the shut in casing pressure constant. You have got a kick in the well of 220 psi shut in drill pipe pressure. At 30 SPM your drill pipe circulating pressure is 1060 psi. Calculate the slow circulating rate pressure loss.

19. Overburden pressure is:

a. the pressure exerted at any given depth by the weight of the rocks and sediments.

b. the pressure exerted at any given depth by the weight of the sediments, or rocks and the weight of the fluids that fill the pore spaces in the rock. c. the pressure exerted at any given depth by the weight of the rocks.

d. the pressure exerted at any given depth by the weight of the fluid in the pore space of the rocks.

20. Of all the pressure losses in the circulating system, which one acts only on the borehole?

A. The pressure loss across the nozzles.

B. The pressure loss in the surface lines.

C. The pressure loss in the drill stem.

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21. At the start of a trip out of the hole for a bit change, the first 20 x 93 ft stands of pipe are pulled from the hole wet with no fill up. Using the following data calculate the reduction in bottom hole pressure?

DP. Metal Displacement = .00764 bbls/ft DP. Capacity = .01776 bbls/ft Casing Capacity = .0758 bbls/ft Mud Weight = 10 ppg A. 48 psi B. 483 psi C. 600 psi D. 683 psi

22. At the start of a trip out of the hole for a bit change, the first 10 x 93 ft stands of pipe are pulled from the hole dry with no fill up. Using the following data calculate the reduction in bottom hole pressure?

DP. Metal Displacement = .00764 bbls/ft DP. Capacity = .01776 bbls/ft Casing Capacity = .0758 bbls/ft Mud Weight = 12 ppg A. 650 psi B. 6 psi C. 65 psi D. 130 psi

23. Select the two things that are needed to accurately determine an Initial Circulating Pressure?

A. drilling pump pressure and mud weight B. shut in drill pipe pressure and mud weight

C. slow circulating rate pressure and final circulating pressure D. slow circulating rate pressure and shut in drill pipe pressure

24. Select the three things that are needed to accurately determine a Final Circulating Pressure?

A. drilling pump pressure, drilling mud weight and kill mud weight B. shut in drill pipe pressure, drilling mud and kill mud weight

C. slow circulating rate pressure, drilling mud weight and kill mud weight

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25. The Drillers Method of Well Control normally requires how many circulations to kill a well? A. one circulation B. two circulations C. three circulations D. four circulations

26. The Drillers Method of Well Control will normally result in:

A. a higher bottom hole pressure than the wait and weight method. B. a lower bottom hole pressure than the wait and weight method. C. a higher surface pressure than the wait and weight method D. a lower surface pressure than the wait and weight method.

27. During a well-killing operation, a common way to bring the pump up to kill rate without changing bottom hole pressure is to:

A. keep SIDP constant at the original shut-in value by opening the choke. B. keep SIDP constant at the original shut-in value by opening the choke

and bringing the pump up to kill-rate speed.

C. keep SICP constant at the original shut-in value by opening the choke and bringing the pump up to kill-rate speed. ensure that casing pressure and standpipe pressure rise consistently together.

28. The usable accumulator fluid for a 10 gallon accumulator bottle on a 3,000 psi system with 1,000 psi precharge is approximately:

A. 9 gallons. B. 7 gallons. C. 5 gallons. D. 3 gallons

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29. Use the following well data to calculate the different influx heights:

Drill collar length: 700 ft

DC - OH Capacity .0292 bbl/ft DP - OH Capacity .0459 bbl/ft

Kick size (bbls) Height (ft)

a. 10 ________

b. 20 ________

c. 30 ________

d. 40 ________

30. Using the following data, calculate the influx gradients:

SICP SIDPP Mud Wt Height of Influx Answer

800 720 11.5 400

950 600 10.6 840

680 550 10.2 350

31. Using the following well data calculate Kill mud weights:

SICP (psi) SIDPP (psi) Mud Wt (ppg) TVD (ft) Answer

600 450 10 9500

850 690 11 12000

780 570 10.5 11200

700 300 14 13000

32. Using the following well data calculate the Annular Pressure Losses:

BHCP (psi) Mud Wt (ppg) Depth TVD (ft) Answer

6000 11.6 9450

2600 9.8 5000

5700 10 10000

33. Using the following data, calculate the new pump pressure:

Old pump pressure Old Mud weight New mud Weight Answer

2500 16 17.5

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34. Using the following data, calculate the new pressure:

Old SPM Old pressure New SPM Answer

40 200 80

20 400 55

35. Convert the following pressure gradient to mud weight:

Gradient (psi/ft) Mud Wt (ppg)

.56 .81

36. Change the ECD to BHCD:

ECD (ppg) Depth TVD (ft) BHCD (psi)

12.5 8000

10.2 11400

9.4 12500

37. What would be the annular velocity around the drill collars:

Pump output (bbl/min) DC – OH capacity

(bbl/ft)

Annular Velocity (ft/min)

6 0.3

38. What would be the annular velocity around the drill pipe if the pump output is 6 bbl/min and the DP – OH capacity is .0459 bbl/ft ?

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39. At the start of a trip out of the hole for a bit change, the first 10 x 93 ft stands of drill pipe are pulled from the hole wet.

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

Mud weight: 12 ppg

Casing capacity: .0758 bbl/ft

DP capacity: .01776 bbl/ft

DP metal displacement: .00764 bbl/ft

Answer: psi

40. At the start of a trip out of the hole for a bit change, the first 20 x 93 ft stands of drill pipe are pulled from the hole dry.

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

Mud weight: 12 ppg

DP capacity: .01776 bbl/ft

DP metal displacement: .00764 bbl/ft

Answer: psi

41. While tripping out of the hole, the trip tank is turned off and a flow check is made when the drill collars are at the rotary table.

The last 400 feet of drill collar are pulled from the hole dry with no fill up. Using the following data answer the questions below:

DC metal displacement: .054 bbl/ft

DC capacity: .00768 bbl/ft

Mud weight: 12 ppg

a. What is the maximum level drop in the annulus? Answer: ft

b. What is the reduction in bottom hole pressure? Answer: psi

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42. Using the following data, calculate the loss in hydrostatic pressure if the casing was not kept full and the float failed while running casing in the hole.

Casing capacity Annular capacity Differential height Mud Wt Anwser (psi)

.0754 bbl/ft .067 bbl/ft 1000 ft 10

.0754 bbl/ft .067 bbl/ft 800 ft 12

Formula : Mud gradient x Differencial Height x Casing capacity

(Casing capacity + Annular capacity)

43. An influx in oil based mud is not possible to detect when it is first occurring because gas going into solution will cause no associated pit increase at the surface.

TRUE or FALSE

44. When a kick is taken in oil based mud and the well pressure have stabilized, the SICP will be:

a. Higher than the same kick in water – based mud b. Lower than the same kick in water – based mud

c. The casing pressure would read the same in oil or water – based mud

45. Gas that is in solution will migrate in the annulus in a vertical well at the same rate as free gas.

TRUE or FALSE

46. When drilling a deep high pressure high temperature well using oil base mud, a gas condensate influx enters the well bore undetected.

If the critical bubble pressure was about 800 psi, how far from the surface would it be when it started to break out and become free gas if the mud weight in use is 12 ppg.

a. 800 ft b. 1282 ft c. 9600 ft d. 2182 ft

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EXERCISE # 2

1. Which gauge must be used to read drill pipe pressure while taking SCR‟s?

a. drill pipe gauge on driller‟s panel

b. casing gauge on driller‟s panel

c. drill pipe gauge at the choke panel d. casing gauge at the choke panel

2. A 13 3/8 casing is set at 3126 ft TVD, drilled out and tested with 10.2 ppg mud to 670 psi surface pressure. What is the formation fracture gradient calculated from the test?

a. 0.564 psi/ft b. 0.678 psi/ft c. 0.74 psi/ft d. 0.841 psi/ft

3. What would be the MAASP with 11.4 ppg mud in the hole? (use data from Q-2) a. 400 psi

b. 461 psi c. 500 psi d. 560 psi

4. What mud weight would have a MAASP of 250 psi? (use data from Q-2) a. 11.56 ppg

b. 12.69 ppg c. 11.85 ppg d. 12.21 ppg

5. What happen to MAASP as MW increases? a. increase

b. decrease c. stay the same d. impossible to say

6. What do you consider as essential for an accurate formation test? (4 answers) a. a list of mud additives

b. a known mud yield point

c. accurate TVD for the casing shoe d. Small volume, high pressure pump e. The same known mud weight in and out f. Cement recipe

g. An accurate surface pressure gauge h. A long open hole section

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7. What is the mud weight that we would expect to use to balance normal formation pressure? a. 7.56 ppg b. 8.00 ppg c. 8.94 ppg d. 10.2 ppg

8. What is primary well control?

a. the use of drilling fluid to balance formation b. the use of BOP to secure the well

c. the use of annular preventer to close the well d. the use of cement plug

9. Swabbing will cause the loss of primary well control? a. true

b. false

10. When drilling top hole, which of the following are considered to be good drilling practices? (3 answers)

a. ROP will be maximised

b. MW must be with .5 ppg of plan c. Pump out of hole while tripping d. Drill a pilot hole

e. Pump a slug before tripping f. Control ROP

g. Minimise losses to 15 bbl/hr

11. If the level of 12.5 ppg mud fell by 560 ft in a 6543 ft TVD well, what would be the reduction in BHP?

a. 364 psi b. 244 psi c. 448 psi d. 732 psi

12. What is the reduction in bottom hole pressure if a 5 bbl lightweight pill of 7.5 ppg is spotted around 4 ¾ drill collars (total length 460 ft) in a 6 1/8 hole containing OBM of 11.9 ppg?

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13. Every kick should be handled as a gas kick? a. true

b. false

14. For a Soft shut-in, the choke is left closed while drilling a. true

c. false

15. Calculate the rate of gas migration if SIDDP has increased by 50 psi in 15 minutes? MW: 10.5 ppg MD: 7500 ft TVD:7000 ft

a. 366 ft/hr b. 455 ft/hr c. 244 ft/hr d. 575 ft/hr

16. What is the casing pressure when a 5 bbl gas bubble at 2200 psi in 11.6 ppg mud reaches the casing shoe at 3126 ft TVD?

17. A 9000 ft well is shut in with 200 psi SICP and 0 PSI SIDPP. What is the KMW if OMW is 11.6 ppg?

a. 12.4 ppg b. 12.03 ppg c. 12.4 ppg d. 11.6 ppg

18. W&W method gives lower shoe pressure in all cases a. true

b. false

19. W&W method results in a lower shoe pressure if drill string volume is less than the open hole volume minus the influx volume?

a. true b. false

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20. Surface pressures are always lower if the W&W method is used compared to the Driller‟s method?

a. true b. false

Answer true or false for these statements on the W&W method:

21. Casing pressure must be kept constant during the second circulation

a. true

b. false

22. The pumps are brought up to speed keeping the drill pipe pressure constant

a. true

b. false

23. Surface annulus pressure is lower than with the driller‟s method

a. true

b. false

24. Bottom hole pressure is maintained constant

a. true

b. false

25. The well is dead when you have reached FCP

a. true

b. false

26. SIDPP should be zero once you have reached FCP

a. true

b. false

27. The W&W method is preferred if rapid gas migration is expected

a. true

b. false

28. The W&W is preferred as MAASP is critical and open capacity is greater than the

drill string capacity a. true

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29. The choke operator maintain drill pipe pressure constant while circulating KMW

from surface to bit. What happen to BHP? a. increase

b. decrease c. stay the same

30. What is the BHCP if the MW is 10 ppg, TVD: 12500ft and APL: 400 psi?

a. 6200 psi

b. 6900 psi c. 7300 psi d. 7700 psi

31. The poorboy degasser (mud/gas separator) is identified by its design dimensions. Which two of the given dimensions determine the operating limit of the pressure build up in the separator?

a Body height.

b Inlet line inside diameter.

c Vent pipe inside diameter.

d Height of the U-tube.

e Inside diameter of the U-tube.

f Vent pipe height.

g Body inside diameter.

32. You are using a cup type tester. The mandrel outside diameter is 6 3/4" and the casing inside diameter is 12.615".

Calculate the tension force created on the drill pipe above the cup tester when a 3000 psi test pressure is applied.

a 267,000 lbs

b 167,500 lbs

c 67,500 lbs

33. A larger pit gain will give a higher SIDPP, resulting in a higher kill mud weight. a. True

b. Maybe c. Sometimes d. False e. Always

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34. A larger pit gain will result in higher SIDPP and SICP. a. True b. Maybe c. Sometimes d. False e. Always

35. A larger pit gain will result in a higher SICP, but theSIDPP will remain the same if

the kick is big or small. a. True

b. Maybe c. Sometimes d. False e. Always

36. After circulating out a kick using the driller's method, is the SICP and SIDPP about the same?

a. Only if the influx is a fluid. b. Never c. Yes d. No e. Only if the influx was gas.

37. When killing a well using the wait and weight method, what will happen to the mud pit volume the moment the gas is passing through the choke?

a. The pit volume starts increasing. b. The pit volume starts to drop.

c. The pit volume will stay the same from now on. d. The pit volume will rise and fall erratically. e. The pit volume should not be monitored when killing.

38. What is the value of the Maximum Allowable Annular Surface Pressure usually determined by?

a. The maximum bottom hole pressure that can be sustained. b. The slow circulating rate.

c. The formation strength at the casing shoe. d. The temperature of the influx fluid. e. The annular pressure loss.

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39. When killing a well using the driller's method, what would happen to the mud pit

volume during the second circulation? a. The pit volume decreases.

b. The pit volume stays the same. c. Increase only due to added weight material. d. Increase initially and decreases in the end. e. Decreases at first and increases in the end.

40. What action would you take if while circulating out a kick the choke line parted? a. Stop pump and close the choke.

b. Stop pump and close the HCR. c. Continue to kill if the influx is past the shoe. d. Stop the pump and close the shear rams. e. Start killing with the volumetric method.

41. Whilst circulating out a kick the mud pump fails. What is the first thing to do? a. Fix the pump as soon as possible.

b. Change over to the other pump. c. Shut the well in.

d. Start diverting. e. Start bullheading.

42. If total losses occurred while drilling with water based mud, what would you do? a. Continue drilling blind.

b. Stop drilling, fill the hole with water. c. Stop drilling, shut the well in. d. Spot a hivis pill acroos the shoe. e. Set a barite plug.

43. On a surface stack; what would happen if when bringing the pump up to kill speed

the casing pressure was allowed to increase above the shut in casing pressure? a. BHP would possibly exceed formation fracture gradient.

b. BHP would cause more influx to enter the well bore. c. It doesn't matter at all if SIDPP is constant. d. It is OK if SIDPP also rises the same amount. e. Only while using wait and weight method does it matter.

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44. Mud weight is 12.5 ppg. SIDPP=800 psi, SICP=1025 psi. The annulus capacity is .0292 bbl/ft. The influx volume is 12 bbl.

What is the gradient of the influx? a. .1520 psi/ft

b. .1502 psi/ft c. .1205 psi/ft d. .1025 psi/ft e. .0521 psi/ft

45. TD=12000', MW in the hole=13.5 ppg, Pitgain 50 bbl, SIDPP=600 psi. Ann. cap. with 450' of DC= .0778 bbl/ft. DP/OH cap= .1215 bbl/ft. Influx gradient = .1 psi/ft What is the SICP?

a. 642 psi b. 945 psi c. 573 psi d. 580 psi e. 752

46. SIDPP increases with the size of the kick. a. True

b. False

47. A driller is circulating a kick out and has reached hisfinal circulating pressure of 850 psi with 30 SPM. If this driller speeds the pump up to 35 SPM, and the

toolpusher keeps 850 psi on the drillpipe by adjusting the choke, the bottom hole pressure will:

a. Decrease by 307 psi b. Increase by 253 psi c. Stay constant at 850 psi d. Increase by 140 psi e. Decrease by 405 psi

48. Which of the following functions is activated by the manifold pressure of the

accumulator unit? a. Ram preventers only.

b. Hydrauliccally operated choke and kill line valves. c. Rams and hydraulic operated choke and kill line valves. d. Annular preventers

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A deviated hole has a measured depth of 12,320 ft. (TVD 10429 ft). 9 5/8”, 47 lb/ft.

casing in set at a measured depth of 9750 ft. (9200 ft. TVD). 11.4 ppg mud is in use when the well kicks and is closed in.

Shut in Drill Pipe Pressure : 750 psi

Shut in Casing Pressure: 1050 psi

Kick volume: 15 bbls.

Pre- recorded information is as follows :

Fracture mud weight = 14.4 ppg

Capacity of 19.5 lbs. Drill pipe = 0.01776 bbl/ft.

Capacity of 9 5/8” J55 casing = 0.0732 bbl/ft.

Slow Circulating Rate Pressure = 850 psi

49. The maximum allowable annular surface pressure is rounded off to : a) 1370 psi

b) 1480 psi c) 1435 psi d) 1415 psi

50. The kill mud weight required to balance the formation pressure is: a) 13.1 ppg

b) 12.6 ppg c) 12.8 ppg d) 12.2 ppg

51. The kill mud weight with a Safety Margin of 100 psi is: a) 13.4 ppg

b) 13.0 ppg c) 12.4 ppg d) 11.8 ppg

52. The initial circulating pressure is: a) 1400 psi

b) 1600 psi c) 1900 psi

53. The final circulating pressure (using kill mud weight with a 100 psi Safety Margin is) : a) 850 psi

b) 970 psi c) 920 psi d) 1050 psi

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55. In the area where local legislation requires that BOP equipment must be rated so that maximum anticipated formation pressures do not exceed 75% of BOP equipment pressure ratings, what is the Minimum Acceptable rating for equipment to be used in drilling Normally Pressured Formation to 16,000 ft. TVD?

a) 2,000 psi BOP Equipment b) 3,000 psi BOP Equipment c) 5,000 psi BOP Equipment d) 10,000 psi BOP Equipment e) 15,000 psi BOP Equipment

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EXERCISE # 3

Use the Well Data to answer the questions. Each question has only one correct answer. WELL DATA Well Depth 10,000 ft TVD 10,000 ft MD Marine riser 800 ft

Choke line 820 ft capacity = 0.0087 bbls/ft

Bit size 8.5”

Drill Pipe 5” OD. 19.5 lbs/ft

Capacity = 0.01776 bbls/ft HWDP 5” OD. 50 lbs/ft x 850 ft Capacity = .0088 bbls/ft Drill Collars 61/2” x 213/16” x 750 ft Capacity = 0.00768 bbls/ft Casing 95/8”, 47 lb/ft. P110 8.681” ID

100% Internal yield = 10,900 psi

Set at 7,500 ft TVD

Mud weight in use 15 ppg.

Pump output 0.119 bbls/stk

PUMP PRESSURE

While Drilling 2600 psi at 90 spm (APL = 310 psi) Slow Pump Rate Up Riser 270 psi at 30 spm (APL = 75 psi) Slow Pump Rate Up CL 360 psi at 30 spm

ANNULAR VOLUMES Drill pipe - Casing Drill pipe - Casing = 0.0505 bbls/ft Drill pipe - Open hole = 0.0459 bbls/ft Drill collars - Open hole = 0.0292 bbls/ft Drill pipe – riser = 0.336 bbls/ft Active surface volume = 320 bbls

WELL CONTROL DATA

SIDPP SIDPP = 500 psi

SICP = 720 psi

GAIN = 10 bbls

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1. What is the total capacity of the drill string? A. 150 bbls

B. 162 bbls C. 197 bbls D. 180 bbls

2. Calculate the total annular capacity with the pipe on bottom while controling the well?

A. 482.2 bbls B. 446.5 bbls C. 547.5 bbls D. 627.6 bbls

3. What is the surface to bit time with the pump running at 80 spm? A. 17 minutes

B. 25 minutes C. 32 minutes D. 39 minutes

4. Calculate bit to surface time (bottoms up) at 80 spm? A. 58.5 minutes

B. 46.8 minutes C. 60.3 minutes D. 51.5 minutes

5. What kill mud is required to balance formation pressure? A. 13.4 ppg

B. 13.0 ppg C. 12.4 ppg D. 16.0 ppg

6. The ICP (initial circulating pressure) at 30 spm will be approximately? A. 270 psi

B. 770 psi C. 990 psi D. 1200 psi

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7. The FCP (final circulating pressure) at 30 spm will be approximately? A. approximately 800 psi

B. approximately 390 psi C. approximately 500 psi D. approximately 290 psi

8. After reaching FCP it is decided to increase the pump speed to 40 spm. What would happen to BHP if the drill pipe pressure is held constant at the original FCP value?

A. increase by about 225 psi B. decrease by about 225 psi

C. remain constant because drill pipe pressure was not changed D. increase by about 500 psi

9. What is the hydrostatic pressure at the bottom of the hole before the kick? A. 5800 psi

B. 6800 psi C. 7800 psi D. 6240 psi

10.What is the ECD on bottom while drilling? A. 15.0 ppg

B. 15.5 ppg C. 16.0 ppg D. 16.5 ppg

11.At 80 spm what is the annular velocity around the drill collars? A. 412 ft/min

B. 210 ft/min C. 506 ft/min D. 321 ft/min

12.What is the maximum allowable mud weight? A. 17.5 ppg

B. 16.5 ppg C. 18.0 ppg D. 19.0 ppg

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13.What is the approximate length of the influx? A. 1027 ft

B. 850 ft C. 653 ft D. 342 ft

14.The gradient of the influx is about? A. .137 psi/ft

B. .320 psi/ft C. .465 psi/ft D. .433 psi/ft

15.How many strokes to go from ICP to FCP? A. 1282 stks

B. 1363 stks C. 1680 stks D. 1538 stks

16.How many strokes will it require to go from bit to shoe? A. 5364 stks

B. 4122 stks C. 1658 stks D. 858 stks

17.How long will it take to go from bit to shoe at a pump speed of 30 spm? A. about 214 minutes

B. about 29 minutes C. about 157 minutes D. about 55 minutes

18.At 30 spm what is shoe to surface travel time? A. about 96 minutes

B. about 34 minutes C. about 214 minutes D. about 76 minutes

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19. If the casing shoe is tested with 12.5 ppg mud in the hole, how much pressure is applied at the surface to give a fracture gradient of .91 psi/ft? A. 1250 psi

B. 1500 psi C. 2000 psi D. 1950 psi

20. What would be the new MAASP once the well has been killed? A. 685 psi

B. 1638 psi C. 700 psi D. 585 psi

21. At 30 spm how long will it take to pump kill mud to the bit? A. 157 mins

B. 214 mins C. 45 mins D. 76 mins

22. If a 100 psi safety margin is included in the kill mud weight, what would the new kill weight be?

A. 15.5 ppg B. 16.0 ppg C. 15.4 ppg D. 16.2 ppg

23. What would be the approximate pressure step down from ICP to FCP in psi/100 strokes.

A. 30 psi/100 stks B. 35 psi/100 stks C. 50 psi/100 stks D. 66 psi/100 stks

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Answer the following gauge questions as the well is killed using the Drillers method. 1 00 200 3 00 400 5 00 600 70 0 80 0 90 0 1000 1 100 1200 1300 1400 15 00 160 0 1700 1 800 1900 10 0 200 300 4 00 5 00 6 00 700 800 900 10 00 1100 1 200 13 00 14 00 1 500 1600 1 700 18 00 1 900 O P EN P O S IT IO NC H O KE C LO S E P S I P S I T O TA L S TR O K E S D R ILL P IP E P R E S S U R E P U M P S P E E D C A S IN G P R E S S U R E 5 0 3 0 7 7 0 6 3 0

24. The kill operation has started. This is what the choke control console shows. What should you do?

A. open the choke a little B. close the choke a little C. increase the pump speed D. decrease the pump speed E. nothing everything looks alright F. Possible plugged nozzle

G. Possible choke wash out H. Possible choke plugging

1 00 2 00 300 40 0 5 00 60 0 70 0 800 900100 01 100 120 0 130 0 140 0 1500 16 00 170 0 1800 1 900 100 2 00 300 40 0 5 00 60 0 70 0 800 900100 011 00 120 0 130 0 1400 1 500 160 0 170 0 1 800 1 900 O P E N _{P O S ITIO N}C H O K E C LO S E P S I P S I TO T A L S TR O K E S D R IL LP IP E P R E S S U R E P U M P S P E E D C A S IN G P R E S S U R E 30 600 580 600

25. Pit room calls up to confirm a .5 bbl rise in the level. What should you do? A. open the choke a little

B. close the choke a little C. increase the pump speed D. decrease the pump speed E. nothing everything looks alright

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100 200 300 400 500 600 700 8 00 900 1000 1100 1200 1 300 1400 1500 1600 1700 1800 1900 100 200 300 400 500 600 700 800 900 1000 1100 1200 1300 1400 1500 1600 1700 1800 1900 O PEN _{PO SITIO N}C H O K E C LO S E P S I P S I TO TA L S TR O K ES D R ILLP IPE PR E SS U R E PU M P S PE E D CA S IN G PR E SS U R E 3 0 3 2 5 0 7 7 0 1 0 20

26. The pit levels are still reported to be increasing slightly. This is what you see on the panel.

A. open the choke a little B. close the choke a little C. increase the pump speed D. decrease the pump speed E. nothing everything looks alright

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EXERCISE # 4

1. Most kicks have been caused by the failure of drilling crews to: a. Properly install and test BOP equipment

b. Keep mud weight high enough

c. Make sure that hole takes the proper amount of fluid during a trip

2. What is the correct action if the hole does not take the proper amount of fluid while tripping out of the hole?

a. Observe, watch for flow, and if there is none, pull out of hole b. Stop, spot a high viscosity pill, then pump out of hole

c. Go back to bottom, circulate bottoms up and evaluate the problem d. Check for gas cut mud at the surface

3. The most important rule in well control is to:

a. Know how to take SIDPP with a float in the string

b. Shut the well in quickly and properly with the least amount of gain

c. Circulate the kick out using constant circulating pressure and pump strokes d. Hold 200 psi extra back pressure with the hydraulic choke while circulating out

the kick

4. A large percentage of all kicks have been caused by: a. Abnormally pressured formations

b. People not reacting or handling situations properly c. BOP equipment failure

d. Lost circulation

5. The mud weight required in the hole to balance normal formation pressure would have to be:

a. 8.3 ppg b. 10.3 ppg c. 8.9 ppg d. 9.5 ppg

6. Mud monitoring equipment such as P.V.T. and pit alarm systems, trip tanks and trip records should be used:

a. Any time the well is open

b. Any time fluid is circulated through the mud pit c. When abnormal formation is expected

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7. Every kick should be handled as a gas kick a. True

b. False

8. The first reliable indication that a kick is in progress is: a. No warning

b. An increase in pump pressure

c. An increase in mud flow, mud volume and a decrease in pump pressure d. Reduced drilling rate

9. When a gas kick is being circulated up a well, the surface pit volume will: a. increase

b. decrease c. stay the same

10. Final circulating pressure is reached when: a. The influx is circulated out

b. Kill mud has made a complete circulation c. Kill mud has made a bottom-up

d. Kill mud reaches the bit

11. Mark the statements below "true" or "false" when drilling with a float valve in the string. a) Surge pressure is reduced.

 True

 False

b) Reverse circulation is possible.

 True

 False

c) Flow back through the drillstring often occurs after pumping a slug.

 True

 False

d) Shut-in drillpipe pressure can be taken without starting the pumps.

 True

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12. What is the primary function of the choke in the overall BOP system? a) To divert contaminant to burning pit.

b) To hold back pressure while circulating up kick. c) To divert fluid to the mud tank.

d) To prevent the loss of mud due to expansion of gas. e) To close the well in softly.

13. While testing the BOP stack, it is noticed that hydraulic oil is leaking from the weep hole on the upper rams. Which one of the following best describes the proper action to be taken?

a) Energize plastic seal and repair BOP at next scheduled maintenance. b) A primary seal is leaking, secure the well and repair the seal.

c) The rams packer is leaking due to wear. Change the worn packer. d) Do nothing. The seal requires a slight leak for lubrication purpose.

14. Why should the side outlet below a test plug be kept in the open position while testing a surface BOP stack?

a) Because of potential damage to casing/open hole. b) Because the test will create extreme hook load.

c) Otherwise reverse circulation will be needed to release the plug

15. Which three of the following conditions in the well increase the risk of exceeding the MAASP during the well kill operation?

a) Long open hole section.

b) Large difference between formation breakdown pressure and mud hydrostatic pressure.

c) Small influx.

d) Short open hole section. e) Large influx.

f) Small difference between formation breakdown pressure and mud hydrostatic pressure.

Questions 16-18 are base on the following information:

13 3/8” surface casing is set and cemented at 3126 ft. (TVD) The cement is drilled out together with 15 ft. of new hole, using a 10.2 ppg. mud. A Leak Off Pressure of 670 psi is determined.

16. What is the formation fracture gradient? a) 0.619 psi/ft

b) 0.837 psi/ft c) 0.745 psi/ft d) 0.530 psi/ft.

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17. What is the Maximum Allowable Annular Surface Pressure for 11.4 ppg mud used at 6500 ft TVD. a) 865 psi b) 474 psi c) 449 psi d) 563 psi

18. How often should the MAASP be recalculated? a) After every bit change

b) After a change in mud weight c) After every 500 ft. drilled

19. A gas kick is being circulated out. At the time the gas reaches the casing shoe (3126 ft TVD) the pressure at the top of the bubble is 2200 psi. If the original mud weight is 11.6 ppg.

What is the casing pressure at surface. a) 314 psi

b) 442 psi c) 542 psi d) 506 psi

21. What is primary well control?

a) The slow Circulating Rate Pressure used in the kill process.

b) The used of Mud hydrostatic to balance fluid pressures in the formation. c) The use of Blow Out Preventers to close in a well that is flowing.

d) The use of Pit Volume and Flow Rate measuring devices to recognize the kick.

22. What is meant by Abnormal High Pressure with regard to fluid pressure in the formation? a) The excess pressure due to circulating mud at high rates.

b) The excess pressure that needs to be applied to cause „leak-off „ into a normally pressure formation.

c) High density mud used to create a large overbalance.

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23. Which factors most influence the rate at which shut in pressures stabilize after the well is shut in? a) Gas migration b) Friction losses c) Permeability d) Type of influx

24. While running pipe back into the hole, it is noticed that the normal displacement of mud into the trip tank is less than calculated. After reaching bottom and commencing circulation, the return flow meter is observed to reduce from 50% to 42%. A pit loss of 2 bbl. is noted. What is the most likely cause of these indications?

a) Partial lost circulation has occurred. b) Total lost circulation has occurred. c) A kick has been taken.

d) The well has been swabbed.

25. If total losses occurred while drilling with water based mud what would you do? a) Continue drilling blind.

b) Stop drilling and fill the annulus up with water, from the top until stabilized. c) Stop drilling, shut the well in and see what happens.

26. Lost circulation during a well control operation is usually detected by: a) Monitoring the return flow with the flow show.

b) Monitoring the mud volume in the mud tanks. c) Monitoring the weight indicator.

27. A kick has been taken and it is known that a potential lost circulation zone exists in the open hole. Select two correct actions which can be taken to minimize pressure in the annulus during the kill operation.

a) Maintain extra back pressure on the choke for safety. b) Use the wait and weight method.

c) Choose a lower circulating rate. d) Choose a higher circulating rate.

28. Which of the following causes of well kicks is totally avoidable and is due to a lack of alertness by the driller?

a) Lost circulation. b) Gas cut mud.

c) Not keeping hole full. d) Abnormal Pressures.

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29. Which two of the following cause swabbing? a) Pulling the pipe too fast.

b) Insufficient trip margin. c) Improper circulating density. d) Going into the hole too fast.

e) Failure to slug pipe prior to pulling out of hole.

30. Why is a 20 barrel kick in a small annulus more significant than a 20 barrel kick in a large annulus?

a) The kill weight mud cannot be calculated as easily.

b) It result in higher annulus pressures, due to the height of the kick. c) The kicks are usually gas

d) The pipe usually get stuck.

31. Which one of the following is not an indication when a kick may be occurring? a) Flow rate increase.

b) Increase torque. c) Pit gain.

d) Gas cut mud.

32. What should the driller do at a drilling break? a) Circulate bottoms up.

b) Flow check

c) Reduce weight on bit. d) Increase pump speed.

33. Which two practices are used to maintain primary well control as a precaution when connection gas is noticed?

a) Pumping a low viscosity pill around bit to assist in reduction of balled bit or stabilizers.

b) Control drilling rate so that only one slug of connection gas is in the hole at any one time.

c) Pulling out of the hole to change the bit. d) Raising Mud yield point.

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34. Of all the following warning signs, which two signs would leave little room for doubt that the well is kicking?

a) flow line temperature increase. b) increased rotary torque

c) flow rate increase.

d) decrease drill string weight e) pit volume gain

f) increased rate of penetration

35. Which of the following statements best describes formation porosity. a) The ratio of the open spaces to the total volume of rock.

b) The ability of fluid and gas to move within the rock.

c) The presence of sufficient salt water volume to provide gas lift. d) All of the above

36. While drilling The active tank contained 200 bbls and the mud return line to the pits contains 20 bbls. After having a kick the tank contains 240 bbls. What is the size of the influx?.

a) 260 bbls b) 20 bbls c) 40 bbls d) 240 bbls.

37. The driller is tripping pipe out of a 12 ¼” diameter hole. 25x92 ft. stand of 5” pipe have

already been pulled. There are 85 more stands to pull. The calculated metal displacement of the 9 ½” collars is 0.08 bbls/ft. The capacity of the drill pipe is 0.01776 bbls/ft and the metal displacement 0.0075 bbls/ft. The trip tank volume has reduced from 27 barrels to 15 barrels. What action should be taken in this situation?

a) Flow check, if negative continue to pull out of hole. b) Shut the well in and circulate hole clean.

c) Flow check, if negative displace a 100 ft. heavy slug into annulus and continue to pull out of hole.

d) Flow check, if negative run back to bottom and monitor returns. e) Pull remaining stands out of hole.

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38. Prior to pulling out of the hole from 10485 ft. TVD, the pipe is full of 10.4 ppg. mud. The pipe capacity is 0.01776 bbls/ft. A 25 bbls slug weighting 12.0 ppg is pumped into the drill pipe causing the level to drop some 216 ft. inside the drill pipe.

What is the drop in bottom hole pressure due to pumping the slug into position? a) 25 psi

b) 0 psi. c) 117 psi d) 135 psi.

39. Which of the following possible indications suggest that mud hydrostatic pressure and formation pressure are almost equal?

a) A drilling break. b) Connection gas.

c) Large, splintery cuttings. d) Trip gas.

e) All of above.

40. While pulling out of the hole it is noticed that mud required to fill the hole is less than calculated. What action must be taken?

a) Flow check, if negative displace a 100 ft. heavy slug into annulus and continue to pull out of the hole.

b) Flow check, if negative run back to bottom circulate bottoms up and monitor returns. c) Pull remaining stands out of the hole.

d) Flow check, if negative continue to pull out of the hole. e) Shut the well in and circulate the hole clean.

41. You are pulling out of hole. Two 93 ft. stands of 8” drill collars have been stood back in the derrick. The displacement is 0.0549 bbls/ft.

According to your Assistant driller - 5.1 bbls should be pump into the well. It only takes 5 bbls to fill the hole. (Answer “Yes” or “No” to each question.)

a) Are the calculations correct?

Yes No

b) Have you taken a 5 bbls influx?

Yes No

c) All OK, keeps going?

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42. While tripping out of the hole a kick was taken and a full bore kelly cock was stabbed and closed. A non return type safety valve was made up on top of the kelly cock prior to stripping in. (Answer “Yes” or “No” to each question.)

a) Should the kelly cock be closed?

Yes No

b) If the kelly cock is left in the open position, can a wire line be run inside the drill string?

Yes No

43. From the list of practices shown below, choose the six most likely to lead to an increase in the size of the influx.

a) Switch off the flow meter alarms.

b) Regular briefing for the derrickman on his duties regarding the monitoring of pit levels. c) Drilling 20 ft further after a drilling brake, before flow checking.

d) Running regular pit drills for drill crew. e) Maintaining stab in valves.

f) Testing stab in valves during BOP tests.

g) Excluding the drawworks from the SCR assignment. h) Keeping air pressure on choke control console at 10 psi. i) Calling toolpusher to floor prior to shutting in the well.

j) Not holding down master air valve on remote BOP control panel while functioning a preventer.

44. If flow through the drillpipe occurs while tripping, what should the first action be? a. Pick up and stab kelly.

b. Run back into bottom.

c. Close the annular preventer.

d. Stab a full opening safety valve, close the valve.

45. Which list below (a, b, c or d) describes how the choke manifold will most likely be set up for Hard Shut-in while drilling?

BOP Side Outlet HydraulicValve(HCR) Auto Choke

A open closed closed

B open open closed

C closed open open

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46. While drilling along at a steady rate the derrickman asks to slow the mud pumps down so that the shakers can handle the increase in cuttings coming back in the returns. Which one of the following would be the safest course of action.

a) Continue at the same rate allowing the excess to bypass the shakers and get caught in sand traps which can be dumped later.

b) Pick up off bottom and check for flow, if there is not any then circulate bottoms up to reduce rate so shakers can handle cutting volume, flow check periodically during circulation.

c) Slow down the mud pump until the shakers can handle the volume of cuttings in the returns as requested by derrickman.

d) Slow down the drilling rate and the pump rate until the shakers clear up then go back to the original parameters.

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EXERCISE # 5

1. When a kick occurs, why is it important to get the well shut in as soon as possible a) A larger pit gain will result in a higher SIDPP resulting in a heavier kill mud weight

True or False.

b) A larger pit gain will result in higher SIDPP and SICP True or False.

c) A larger pit gain will result in higher SICP but SIDPP will stay the same True or False.

2. A flowing well is closed in. Which two pressure gauge readings might be used to determine formation pressure?

a) BOP manifold pressure gauge

b) Choke console drill pipe pressure gauge c) Driller‟s console drill pipe pressure gauge d) Choke console casing pressure gauge

3. A kick is being circulated out at 30 SPM. The drill pipe pressure reads 550 psi, and casing pressure 970 psi. It is decided to slow the pumps to 20 SPM while maintaining 970 psi on the casing gauge. How will this affect bottom hole pressure (exclude any Equivalent Circulating Density [ECD] effect)? Pick one answer.

a) Increase b) Decrease c) Stay the same d) No way of knowing

4. While killing a well, as pump speed is increased, what should happen to casing pressure in order to keep bottom hole pressure steady?

a) Casing pressure should be held steady during SPM change b) Casing pressure should be allowed to rise during SPM change c) Casing pressure should be allowed to fall during SPM change

5. The principle involved in Constant Bottom Hole Pressure methods of well control is to maintain a bottom hole pressure that is :

a) Equal to the slow circulating rate pressure b) At least equal to the formation pressure c) Equal to the shut in drill pipe pressure d) At least equal to the shut in casing pressure

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6. At what point while correctly circulating out a gas kick is it likely that the pressure at the casing shoe to be at its maximum?

a) At initial shut in

b) When kill mud reaches the bit c) When kill mud reaches the shoe d) When top of gas reaches the shoe

7. If Drill pipe Pressure is held constant while displacing the string with kill mud, what will happen to Bottom Hole Pressure?

a) Increases

b) Remains the same c) Decreases

8. How is a choke wash-out recognized?

a) Rapid rise in casing pressure with no change in drill pipe pressure b) Increase in drill pipe pressure with no change in casing pressure

c) Continually having to open choke to maintain drill pipe and casing pressure d) Continually having to close choke to maintain drill pipe and casing pressure 9. The choke has to be gradually closed due to a string washout. What effect does the

gradual closing of the choke have on the bottom hole pressure?

a) Decreases b) Increases c) Stays the same

10. If Bottom Hole Pressure is held constant while circulating the influx out, the pressure on at the casing shoe will not increase after the influx passes, even though surface pressure on the annulus continues to rise.

a) True b) False

Questions 10-18 are based upon the following information :

A well is closed in having taken a 30 bbl gas kick, while drilling 8 ½” hole at 11,000 ft. (TVD) with 5” drill pipe and 750 ft. of 6 ½” drill collars

Annular capacities

5" DP / 8 ½" Hole, = 0.0459 bbls / ft.

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11. The mud weight is 12.3 ppg and the Shut in Drill Pipe Pressure is 350 psi. Assuming the gas Pressure Gradient to be 0.115 psi/ft, what will be the approximate Shut in Casing Pressure:

12. While preparing to circulate Kill Mud, the gas bubble begins to migrate. If no action is taken, what will happen to the pressure in the gas bubble as it rises:

a) Increase b) Decrease

c) Remain approximately the same 13. What will happen to Bottom hole Pressure?

c) Remain approximately the same

14. What will happen to Shut in Casing Pressure? a) Increase

b) Decrease

15. What will happen to the pressure on the Casing Seat? a) Increase

b) Decrease

16. If you decide to bleed enough mud to keep the Drill Pipe Pressure constant at 350 psi, what would the pressure in the bubble do as the gas rises?

17. What would happen to Bottom Hole Pressure? a) Increase

b) Decrease

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18. What would happen to the Shut in Casing Pressure? a) Increase

b) Decrease

19. What would happen to the Pressure on the Casing Seat while the bubble is below the Casing Shoe?

20. What would happen to the Pressure on the Casing Seat when the bubble is above the Casing Shoe?

21. A kick is being circulated from a well using the Driller‟s Method; Pumping pressure

having been established as 1000 psi at 30 SPM. During the operation, pressure suddenly increases to 1350. You are reasonably sure that a Nozzle of the Bit is plugged. What should you do?

a) Reduce pump pressure to 1000 psi by adjusting the choke b) Shut the well in and re-establish the pumping pressure

c) Hold casing pressure constant at the value recorded just before the bit plugged d) (a) and (b) are acceptable courses of action

22. During the well kill operation, slowly but regularly you have had to reduce choke size because the drill pipe and casing pressures keep dropping with constant pump strokes. What is the likely cause of this?

a) A bit nozzle is washing out b) The choke is washing out

c) You have a washed out pump swab

23. An influx is being circulated out using the Driller‟s Method and using 1100 psi at 30 SPM. The operator increases pump speed to 35 SPM, while holding pump pressure constant.

What happens to Bottom Hole Pressure? a) Increases

b) Decreases

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24. Which of the following parameters can be affected by a drill string washout during a well kill operation?

a) Bottom hole pressure b) Kick tolerance

c) Formation fracture pressure d) Slow circulating rate pressure

25. You are killing a well using the Drillers Method, maintaining constant Drill pipe pressure. The drill pipe pressure begins to drift down, but the casing pressure remains

unchanged. The pump strokes remain constant. You close up your choke slightly, the drill pipe pressure remains unchanged but the casing pressure goes up. What is the probable cause for this?

a) Choke is plugging off b) Bit is plugging off c) Hole in drill pipe d) Choke is washing out

26. If regularly and rather slowly, you have to pinch in the choke to maintain drill pipe and choke pressures while the pump strokes remain constant, you may have:

a) a washed out bit nozzle b) a washed out choke c) a pump failure

27. How can a washout at the adjustable choke be recognized? a) Drill pipe and casing pressures both falling

b) Drill pipe and casing pressures both rising

c) Rapid rise in casing pressure with no change to drill pipe pressure d) Increase in drill pipe pressure with no change to casing pressure

28. The reason shut in casing pressure is usually higher than the shut in drill pipe pressure is:

a) The cuttings in the annulus are lighter, therefore creating a lighter hydrostatic in the annulus.

b) The influx fluid is usually less dense than the existing mud weight.

c) The casing pressure is not necessarily higher, it depends on whether it is an offshore or land operation.

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29. After shutting in on a kick, the SIDPP and SICP are observed to be stable for fifteen

minutes. Both, then, start rising slowly by the same amount. Which one of the following is the probable cause?

a) A further influx is occurring

b) The influx is migrating up the well bore c) The gauges are faulty

d) The BOP stack is leaking

30. After a round trip at 9854 ft with 10.3 ppg mud, we kick the pump in and start to circulate. The well kicks and is closed in with 0 psi on the SIDPP and 150 psi on the SICP. There is no float in the drill string. What kill mud weight is required?

a) 10.3 ppg b) 11.3 ppg c) 10.7 ppg

d) No way of knowing

31. Shut in casing pressure is used to calculate a) Kill weight mud

b) Influx gradient and type when influx volume and well geometry are known c) Maximum Allowable Annular Surface Pressure

d) Initial circulating pressure

32. A kicking well has been shut in. The drill pipe pressure is „0‟ because there is a non-return valve (float) in the string. To establish the SIDPP, what action should be taken?

a) Shearing the pipe and reading the SIDPP directly off the casing gauge

b) Pump at kill rate into the drill string with the well shut in. When casing pressure starts to rise, read the pump pressure. This is the SIDPP.

c) Pump very slowly into the drill pipe with the well shut in. When the pumping pressure stabilizes, the float has opened. This pumping pressure is the SIDPP. d) Bring the pump up to the kill rate holding the casing pressure constant by opening the choke. The pressure shown when the pump is at kill rate is the SIDPP.

33. After circulating out a kick using the driller‟s method (no weight up), are the SICP and

SIDPP about the same? a. yes

b. no

34. A gas kick is being circulated up the well. What is the surface pit volume most likely to do?

a) Increase b) Stay the same c) Decrease

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35. On a surface stack, what would happen if when bringing the pumps up to kill speed, the casing pressure was allowed to fall below shut in casing pressure?

a) Formation would most probably break down b) More influx would be let into the well bore c) It would have no effect on anything

36. For each of the following statements, note whether it relates to the Drillers Method or the Wait and Weight Method.

a) Minimize pressures generated in the annulus due to gas migration.

Driller W&W

b) Remove influx from well before pumping kill mud

Driller W&W

c) Pump kill mud while circulating influx up the annulus

Driller W&W

d) Maintain Drill Pipe pressure constant for 1 st circulation

Driller W&W

37. Which one of the following actions taken while stripping into the hole will help to maintain an acceptable bottom hole pressure?

a) Pumping a volume of mud into the well, equal to the drill pipe closed end displacement at regular intervals

b) Bleeding off the drill pipe steel displacement at regular intervals

c) Pumping a volume of mud into the well, equal to the drill pipe steel displacement, at regular intervals

d) Bleeding off the drill pipe closed end displacement at regular intervals 38. Which of the following statements is true?

a) There is no difference between using the Drillers method and the Wait and Weight method

b) If the kill mud is being circulated up the annulus before the kick has reached the shoe then Wait and Weight method will reduce the risk of breaking down the formation compared to using the Drillers method

c) The Wait and Weight method should always be used because the pressure against the open hole will always be lower when using the Drillers method

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39. Mud weight increase required to kill a kick should be based upon : a) shut in drill pipe pressure

b) shut in casing pressure

c) original mud weight plus slow circulation rate pressure losses d) shut in casing pressure minus shut in drill pipe pressure

40. How is the Initial Circulating Pressure found on a land rig or a jack-up, when the slow pump rate circulating pressure is not known but a kick has been taken?

a) Circulate at desired strokes per minute to circulate out the kick, but hold 200 psi back pressure on drill pipe side with choke

b) Add 400 psi to casing pressure and bring pump up to kill rate while using the choke to keep the casing pressure +400 constant

c) Bring pump strokes up to kill rate while keeping casing pressure constant by manipulating the choke, observed pump pressure is ICP

d) Add 1000 psi to shut in drill pipe pressure and circulate out the kick

41. Having completed the first circulation of the Driller‟s Method, the well is shut in. Should

casing pressure be:

a) Less than Shut in Drill Pipe Pressure b) Equal to Shut in Drill Pipe Pressure c) Greater than Shut in Drill Pipe Pressure

42. On the second circulation of the Driller‟s method, if the casing pressure was held

constant until the kill mud reached Surface, what would happen to the bottom hole pressure?

a) Increase b) Decrease c) Stay the same

43. Using Wait and Weight method, if the drill pipe pressure drops below the line of the graph as the kill mud goes down, what happens to the bottom hole pressure?

a) Increases b) Decreases c) Stays the same

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44. You have taken a kick with a non-return valve (float) in the drill string. After shutting the well in properly, it is best to :

a) Use the annulus pressure to calculate the kill weight mud

b) Start raising the mud weight 1 ppg per circulation until the well is dead

c) Use either the rig pump or cementing unit pump to increase pressure in 100 psi increments until a change is seen on casing gauge

d) Pump slowly into the drill pipe. When the pump pressure stabilizes, the float is open. The pumping pressure is the SIDPP used to calculate kill mud

45. A well is being killed using the Driller‟s Method.

Original shut-in drill pipe pressure = 500 psi

Original shut-in casing pressure = 900 psi

After the first circulation, the well is shut in and pressures allowed to stabilize. They then read :

Shut-in drill pipe pressure = 500 psi Shut-in casing pressure = 650 psi

It is decided not to spend any more time cleaning the hole Which one of the following actions should be taken

a) Prepare to use the Wait and Weight method

b) Bull-head the annulus until shut-in casing pressure is reduced to 500 psi c) Reverse circulate until shut-in casing pressure is reduced to 500 psi

d) Continue with second circulation of Drillers Method (holding casing pressure constant until mud reaches the bit)

46. If the slow pump circulating pressure was not known, and a kick has been taken with the well closed in, how would you find the ICP?

a) Bring pump up to the desired rate, while holding the casing pressure 150 psi above the original SICP

b) Bring pump up to desired rate, but hold 200 psi back pressure on the drill pipe c) Bring pump up to the desired rate holding casing pressure constant by manipulating the hydraulic choke

d) Circulate at desired kill rate but hold casing pressure 100 psi below MAASP 47. The correct gauge to use for calculating the kill weight mud is :

a) the gauge on the choke and kill manifold

b) the drill pipe pressure gauge on the drillers console c) the casing gauge on the drillers console

d) the drill pipe gauge on the remote auto choke panel e) the casing gauge on the remote auto choke panel

(47)

EXERCISE # 6

1. What is the primary function of the weep hole (drain hole, vent hole) on a ram type BOP? a) To show that ram body rubber is leaking.

b) To show that the primary mud seal on the piston rod is leaking. c) To show that the Bonnet seals are leaking.

d) To show that the closing chamber operating pressure is too high.

2. You only have one inside BOP with an NC 50 (4”1/2 IF) lower pin connection on your rig

but the drill string consist of 5” HWDP, and 8” collars. Which one of the following crossovers would you have on the drill floor in case of kick while tripping?

a) 6-5/8” reg. Box X 7-5/8” reg. Pin b) NC50 (4-1/2” IF) Pin X 6-5/8” reg. Pin c) NC50 (4-1/2” IF) Box X 7-5/8” reg. Pin d) NC50 (4-1/2” IF) Box X 6-5/8” reg. Pin

3. Two types of valves may be used in the drill string:

Type 1 Non return, stab in safety valve or inside BOP

Type 2 Fully opening stab in Kelly cock valve or fully opening safety valve

Indicate in the table which statement describes the valves.

Type 1 Type 2

Requires the use of key to close

Must not run in the hole in the close position

Has to be pumped to read “shut-in drill pipe pressure” Will not allow wireline to be run inside the drill string Has potential to leak through the open/close key

Easier to stab if strong flow is encountered up the string

4. A BOP stack is configured: Pipe ram / Blind-Shear ram / Pipe ram / Annular, kill and choke lines are connected under the blind-shear rams. Is it possible to kill a well using the Driller's method if;

a) The upper pipe rams are closed? b) The blind shear rams are closed? c) The lower pipe rams are closed?

5. A BOP stack is configured: Pipe ram / pipe ram / Blind-Shear ram / Annular, kill and choke lines are connected under the blind-shear rams.

a) Can you repair the side outlets with pipe in the hole? b) Can you repair the outlets with no pipe in the hole?

c) Is it possible to shut in with drill pipe in the hole and circulate through the drill pipe? d) Can you change blind rams to pipe rams and kill the well?

6. A BOP stack is configured: Drilling spool / Pipe ram / Blind-Shear ram / Annular, kill and choke lines are connected to the drilling spool.

a) With drill pipe in hole, can we repair the side outlets?

b) With no drill pipe in the hole, can you shut in and repair the Drilling spool? c) With drill pipe in hole, can you circulate through the Drilling spool?

(48)

7. The kill line should enter a stack so that

a) The well can be circulated if the blind rams are in use. b) The well can be circulated if the pipe rams are being used. c) Both the above.

8. Which of the following statements are true concerning Ram Packing Elements? a) Reciprocating motion of the pipe increases the wear on seals.

b) Closing pipe rams on open hole may damage the elements.

c) The ram packer should normally be checked, and if worn, changed whenever the bonnet is opened.

d) All of above.

9. What do the term “6BX” stamped on a flange represent?

a) serial number b) pressure rating c) type

d) size

10. What is meant by the closing ratio for a ram type BOP? a) Ratio between closing & opening volume.

b) Ratio between closing & opening time.

c) Ratio of the wellhead pressure to the pressure required to close the BOP.

11. Study the two tables below which contain markings stamped on API flanges and ring gaskets. Each flange (1,2,3 and 4) mates with one of the ring gaskets (A,B,C or D). Write the appropriate flange number in the blanks.

Ring Gasket Marking Flange A -CI API BX154 S304-4 B -OES API R57 D-4 C- OES API RX66 S-4 D -CI API BX153 S316-4 Flange Marking 1. OES API 16-3/4 3M RX66 6A 89 300F PSL3 05/91 2. CI API 3-1/16 15M BX154 CRA 6A 89 250F PSL2 PRL2 08/92

3. OES API 2-9/16 20M BX153 CRA 6A 89 350F PSL4 PRL4 01/94

4. OES API 13-5/8 2M R57 6A 89 250F PSL1 PRL1 11/93 Gasket Flange A B C D

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12. From the list below, identify the ring gaskets that are pressure energized. (Pick four answers) a) Type RX b) Type BX c) Type AX d) Type R oval e) Type R octagonal f) Type CX

13. Which dimension from the list below is used to identify the “Nominal Flange Size”

a) Throughbore I.D. b) Flange O.D.

c) Diameter of raised face. d) O.D. of ring groove. e) Bolt circle diameter.

14. What is the main function of a diverter? a) To shut in a shallow kick.

b) To direct fluid a safe distance away from the rig floor.

c) To create a back pressure sufficient to stop formation fluids entering the wellbore. d) To act as a back up system if the annular preventer fails.

15. In an area where local legislation requires that BOP equipment must be rated so that maximum anticipated formation pressures do not exceed 75% of BOP equipment pressure ratings, what is the minimum acceptable rating for equipment to be used in drilling normally pressure formation to 16000 ft TVD?

a) 2000 psi BOP equipment b) 3000 psi BOP equipment c) 5000 psi BOP equipment d) 10000 psi BOP equipment e) 15000 psi BOP equipment

16. A BOP stack is configured Pipe Ram / Blind-Shear ram / Pipe Ram / Annular. Use the table below to calculate the required accumulator volume if company policy is to provide sufficient volume to close, open and close again all rams and the annular.

Component Volume to Open Volume to close

Annular BOP 27 29

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17. The following statements relate to the driller‟s remote control BOP control panel located on the rig floor. Decide if the statements are true or false.

a) If you operate a function without operating the master control valve that function will not work.

True or False

b) The master control valve on an air operated panel allows air pressure to go to each function in preparation for you operating the function.

True or False

c) The master control valve must be held depressed while BOP functions are operated. True or False

d) The master control valve must be depressed for five seconds then released before operating a BOP function.

True or False

18. The API RP53 states that closing time should not exceed X seconds for annular BOPs smaller than 18-3/4". What is the value of X?

a) 30 sec. b) 60 sec. c) 2 min. d) 45 sec.

19. Which is the correct definition of the HPU reservoir volume according to API RP53? a) 2 times usable accumulator volume.

b) 2 times accumulator volume. b) 5 times total accumulator volume .

20. Which two pressure readings decrease during normal operation of the pipe rams? a) Manifold pressure

b) Annular pressure c) Accumulator pressure c) Precharge pressure

21. When closing the annular preventer from the remote panel, which two gauges show a reduction in pressure?

a) Manifold pressure b) Annular pressure c) Accumulator pressure d) Air pressure