73236775 3 Well Control Exercises

8/13/2019 73236775 3 Well Control Exercises

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WELL CONTROL

EXERCISE # 1

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

___________ppg

2. If the fluid level dropped 550 ft in a 9600 deep hole containing 10.6 ppg mud, what wouldthe 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 bottomc. The gas is about halfway up the well bored. 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 and300 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 encounteredb. The mud weight was not high enough to contain formation pressurec. It was swabbed in or the hole was not properly filled while pulling outd. It is impossible to tell

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

a. High pulling speedb. Mud properties with high viscosity and high gelsc. Tight annulus BHA/hole clearanced. 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 casingb. When the first few stands are being pulled off bottomc. About half way up the well


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WELL CONTROL

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

_________psi

9. You are pulling out of hole. Two x 93 ft stands of 8" drill collars have been stood back inthe derrick. The displacement is 0.0538 bbls. / ft. According to your Assistant Driller, 10bbls should be pumped into the well. It only takes 10 bbls to fill the hole. (Answer yes orno 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 250bbls. 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 thewell?

a) 0 bblsb) 25 bblsc) 50 bblsd) 275 bbls

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

a) 350 psib) 2275 psic) 630 psid) 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 12ppg, what is the casing pressure at the surface? (Hole TVD 7000ft)



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WELL CONTROL

Questions 13-14 are based on the following information:

13 3/8 surface casing is set and cemented at 4250 ft. (TVD). The cement is drilled outtogether 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 / ftb) 0.686 psi / ftc) 0.760 psi / ftd) 0.384 psi / ft

14. What is the maximum allowable annular surface pressure for 12.3 ppg mud in use at7350ft. TVD :


15. How often should the MAASP be recalculated?

a) After every bit changeb) After a change in mud weightc) After every 500 ft. drilled

16. Calculate the equivalent circulating density in the following circumstances:

Circulating pressure = 3100 psi

Pressure losses:Surface equipment = 20 psiDrill string = 930 psiNozzles = 1800 psiAnnulus = 350 psi

Drilled depth: 12,300 ft. (11,500 ft. TVD)Mud weight: 11.4 ppg

ECD is:

a) 10.8 ppgb) 12.0 ppgc) 11.4 ppgd) 12.3 ppg


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WELL CONTROL

17. Drill pipe capacity = 0.0178 bbls/ftDrill pipe metal displacement = 0.0082 bbls/ftAverage 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 kickin the well of 220 psi shut in drill pipe pressure. At 30 SPM your drill pipe circulatingpressure 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 andsediments.

b. the pressure exerted at any given depth by the weight of the sediments, orrocks 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 theborehole?

A. The pressure loss across the nozzles.B. The pressure loss in the surface lines.C. The pressure loss in the drill stem.D. The pressure loss in the annulus


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WELL CONTROL

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

DP. Metal Displacement = .00764 bbls/ftDP. Capacity = .01776 bbls/ftCasing Capacity = .0758 bbls/ftMud Weight = 10 ppg

A. 48 psiB. 483 psiC. 600 psiD. 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 arepulled from the hole dry with no fill up. Using the following data calculate the reduction inbottom hole pressure?

DP. Metal Displacement = .00764 bbls/ftDP. Capacity = .01776 bbls/ftCasing Capacity = .0758 bbls/ftMud Weight = 12 ppg


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

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

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

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

A. drilling pump pressure, drilling mud weight and kill mud weightB. shut in drill pipe pressure, drilling mud and kill mud weightC. slow circulating rate pressure, drilling mud weight and kill mud weightD. slow circulating rate pressure, drilling mud weight and final circulating pressure


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WELL CONTROL

25. The Drillers Method of Well Control normally requires how many circulations to killa well?

A. one circulation

B. two circulationsC. three circulationsD. 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 ratewithout 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 chokeand bringing the pump up to kill-rate speed.

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

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

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


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WELL CONTROL

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

Drill collar length: 700 ftDC - 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 9500850 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

1700 10 14


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WELL CONTROL

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

Old SPM Old pressure New SPM Answer

40 200 8020 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) DCOH 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/minand the DPOH capacity is .0459 bbl/ft ?

Answer: ft/min


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WELL CONTROL

39. At the start of a trip out of the hole for a bit change, the first 10 x 93 ft stands of drill pipeare pulled from the hole wet.Using the following data, calculate the reduction in bottom hole pressure.

Mud weight: 12 ppgCasing capacity: .0758 bbl/ftDP capacity: .01776 bbl/ftDP 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 pipeare pulled from the hole dry.Using the following data, calculate the reduction in bottom hole pressure.

Mud weight: 12 ppgCasing capacity: .0758 bbl/ftDP capacity: .01776 bbl/ftDP 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 whenthe 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/ftDC capacity: .00768 bbl/ftCasing capacity: .0758 bbl/ftMud 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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WELL CONTROL

42. Using the following data, calculate the loss in hydrostatic pressure if the casing was notkept 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 gasgoing 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 SICPwill be:

a. Higher than the same kick in waterbased mudb. Lower than the same kick in waterbased mudc. The casing pressure would read the same in oil or waterbased mud

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

TRUE or FALSE

46. When drilling a deep high pressure high temperature well using oil base mud, a gascondensate influx enters the well bore undetected.If the critical bubble pressure was about 800 psi, how far from the surface would it bewhen it started to break out and become free gas if the mud weight in use is 12 ppg.

a. 800 ftb. 1282 ftc. 9600 ftd. 2182 ft


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WELL CONTROL

EXERCISE # 2

1. Which gauge must be used to read drill pipe pressure while taking SCRs?

a. drill pipe gauge on drillers panelb. casing gauge on drillers panelc. drill pipe gauge at the choke paneld. 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 to670 psi surface pressure. What is the formation fracture gradient calculated fromthe test?

a. 0.564 psi/ftb. 0.678 psi/ft

c. 0.74 psi/ftd. 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 psib. 461 psic. 500 psid. 560 psi

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

a. 11.56 ppgb. 12.69 ppgc. 11.85 ppgd. 12.21 ppg

5. What happen to MAASP as MW increases?

a. increaseb. decrease

c. stay the samed. impossible to say

6. What do you consider as essential for an accurate formation test? (4 answers)

a. a list of mud additivesb. a known mud yield pointc. accurate TVD for the casing shoed. Small volume, high pressure pumpe. The same known mud weight in and outf. Cement recipe

g. An accurate surface pressure gaugeh. A long open hole section


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WELL CONTROL

7. What is the mud weight that we would expect to use to balance normal formationpressure?

a. 7.56 ppg

b. 8.00 ppgc. 8.94 ppgd. 10.2 ppg

8. What is primary well control?

a. the use of drilling fluid to balance formationb. the use of BOP to secure the wellc. the use of annular preventer to close the welld. the use of cement plug

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

a. trueb. false

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

a. ROP will be maximisedb. MW must be with .5 ppg of planc. Pump out of hole while trippingd. Drill a pilot holee. Pump a slug before trippingf. Control ROPg. 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 thereduction in BHP?

a. 364 psib. 244 psi

c. 448 psid. 732 psi

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



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WELL CONTROL

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

a. trueb. false

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

a. truec. false

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

a. 366 ft/hrb. 455 ft/hr

c. 244 ft/hrd. 575 ft/hr

16. What is the casing pressure when a 5 bbl gas bubble at 2200 psi in 11.6 ppg mudreaches 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 ifOMW is 11.6 ppg?


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

a. trueb. false

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

a. trueb. false


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WELL CONTROL

20. Surface pressures are always lower if the W&W method is used compared to theDrillers 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. trueb. false

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

a. trueb. false

23. Surface annulus pressure is lower than with the drillers method

a. trueb. false

24. Bottom hole pressure is maintained constant

a. trueb. false

25. The well is dead when you have reached FCP

a. trueb. 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. trueb. false

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

a. true

b. false


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WELL CONTROL

29. The choke operator maintain drill pipe pressure constant while circulating KMWfrom surface to bit. What happen to BHP?

a. increase

b. decreasec. stay the same

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


31. The poorboy degasser (mud/gas separator) is identified by its design

dimensions. Which twoof the given dimensions determine the operatinglimit 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 testerwhen a 3000 psi test pressure is applied.

a 267,000 lbs

b 167,500 lbsc 67,500 lbs

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

a. Trueb. Maybec. Sometimesd. Falsee. Always


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WELL CONTROL

34. A larger pit gain will result in higher SIDPP and SICP.

a. Trueb. Maybe

c. Sometimesd. Falsee. Always

35. A larger pit gain will result in a higher SICP, but theSIDPP will remain the same ifthe kick is big or small.

a. Trueb. Maybec. Sometimesd. False

e. Always

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

a. Only if the influx is a fluid.b. Neverc. Yesd. Noe. Only if the influx was gas.

37. When killing a well using the wait and weight method, what will happen to the mudpit 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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WELL CONTROL

39. When killing a well using the driller's method, what would happen to the mud pitvolume 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 speedthe 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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WELL CONTROL

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

What is the gradient of the influx?

a. .1520 psi/ftb. .1502 psi/ftc. .1205 psi/ftd. .1025 psi/fte. .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/ftWhat is the SICP?

a. 642 psi

b. 945 psic. 573 psid. 580 psie. 752

46. SIDPP increases with the size of the kick.

a. Trueb. False

47. A driller is circulating a kick out and has reached hisfinal circulating pressure of 850psi with 30 SPM. If this driller speeds the pump up to 35 SPM, and thetoolpusher keeps 850 psi on the drillpipe by adjusting the choke, the bottom holepressure will:

a. Decrease by 307 psib. Increase by 253 psic. Stay constant at 850 psid. Increase by 140 psie. Decrease by 405 psi

48. Which of the following functions is activated by the manifold pressure of theaccumulator 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 preventerse. All stack functions.


19/98

WELL CONTROL

A deviated hole has a measured depth of 12,320 ft. (TVD 10429 ft). 9 5/8, 47 lb/ft.casing in set at a measured depth of 9750 ft. (9200 ft. TVD). 11.4 ppg mud is in use when thewell kicks and is closed in.

Shut in Drill Pipe Pressure : 750 psiShut in Casing Pressure: 1050 psiKick volume: 15 bbls.

Pre- recorded information is as follows :Fracture mud weight = 14.4 ppgCapacity 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 :


50. The kill mud weight required to balance the formation pressure is:


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


52. The initial circulating pressure is:

a) 1400 psi

b) 1600 psic) 1900 psi

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



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WELL CONTROL

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


55. In the area where local legislation requires that BOP equipment must be rated so thatmaximum 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 NormallyPressured Formation to 16,000 ft. TVD?

a) 2,000 psi BOP Equipment

b) 3,000 psi BOP Equipmentc) 5,000 psi BOP Equipmentd) 10,000 psi BOP Equipmente) 15,000 psi BOP Equipment


21/98

WELL CONTROL

EXERCISE # 3

Use the Well Data to answer the questions. Each question has only one correctanswer.

WELL DATA

Well Depth 10,000 ft TVD10,000 ft MD

Marine riser 800 ftChoke line 820 ft capacity = 0.0087 bbls/ftBit size 8.5Drill Pipe 5 OD. 19.5 lbs/ft

Capacity = 0.01776 bbls/ftHWDP 5 OD. 50 lbs/ft x 850 ft

Capacity = .0088 bbls/ftDrill Collars 61/2 x 2

13/16 x 750 ftCapacity = 0.00768 bbls/ft

Casing 95/8, 47 lb/ft. P110 8.681 ID100% Internal yield = 10,900 psiSet 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/ftDrill pipe - Open hole = 0.0459 bbls/ftDrill collars - Open hole = 0.0292 bbls/ftDrill pipe riser = 0.336 bbls/ft

Active surface volume = 320 bbls

WELL CONTROL DATA

SIDPP SIDPP = 500 psiSICP = 720 psiGAIN = 10 bblsFRACTURE GRADIENT AT SHOE = .91psi/ft


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WELL CONTROL

1. What is the total capacity of the drill string?

A. 150 bblsB. 162 bbls

C. 197 bblsD. 180 bbls

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

A. 482.2 bblsB. 446.5 bblsC. 547.5 bblsD. 627.6 bbls

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

A. 17 minutesB. 25 minutesC. 32 minutesD. 39 minutes

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

A. 58.5 minutesB. 46.8 minutesC. 60.3 minutesD. 51.5 minutes

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

A. 13.4 ppg

B. 13.0 ppgC. 12.4 ppgD. 16.0 ppg

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



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WELL CONTROL

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

A. approximately 800 psiB. approximately 390 psi

C. approximately 500 psiD. 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 theoriginal FCP value?

A. increase by about 225 psiB. decrease by about 225 psiC. 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?


10.What is the ECD on bottom while drilling?

A. 15.0 ppgB. 15.5 ppgC. 16.0 ppgD. 16.5 ppg

11.At 80 spm what is the annular velocity around the drill collars?

A. 412 ft/minB. 210 ft/minC. 506 ft/minD. 321 ft/min

12.What is the maximum allowable mud weight?

A. 17.5 ppgB. 16.5 ppgC. 18.0 ppg

D. 19.0 ppg


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WELL CONTROL

13.What is the approximate length of the influx?

A. 1027 ftB. 850 ft

C. 653 ftD. 342 ft

14.The gradient of the influx is about?

A. .137 psi/ftB. .320 psi/ftC. .465 psi/ftD. .433 psi/ft

15.How many strokes to go from ICP to FCP?

A. 1282 stksB. 1363 stksC. 1680 stksD. 1538 stks

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

A. 5364 stksB. 4122 stksC. 1658 stksD. 858 stks

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

A. about 214 minutesB. about 29 minutesC. about 157 minutes

D. about 55 minutes

18.At 30 spm what is shoe to surface travel time?

A. about 96 minutesB. about 34 minutesC. about 214 minutesD. about 76 minutes


25/98

WELL CONTROL

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

A. 1250 psi

B. 1500 psiC. 2000 psiD. 1950 psi

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


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

A. 157 minsB. 214 minsC. 45 minsD. 76 mins

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

A. 15.5 ppgB. 16.0 ppgC. 15.4 ppgD. 16.2 ppg

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

A. 30 psi/100 stks

B. 35 psi/100 stksC. 50 psi/100 stksD. 66 psi/100 stks


26/98

WELL CONTROL

Answer the following gauge questions as the well is killed using the Drillersmethod.

10 0

20 0

30 0

40 0

50 0

60 0

70 0

80 0

90 0 1 0 0 0

1 1 0 0

1 2 0 0

1 3 0 0

1 4 0 0

1 5 0 0

1 6 0 0

1 7 0 0

1 8 0 0

19 0 0 1 0 0

20 0

30 0

40 0

50 0

60 0

70 0

80 0

90 0 1 0 0 0

1 1 0 0

1 2 0 0

1 3 0 0

1 4 0 0

1 5 0 0

1 6 0 0

1 7 0 0

1 8 0 0

1 9 0 0

O P E N C L O S EC H O K E

P O S I T I O N

P S I P S I

T O T A L S T R O K E S

D R I L L P I P E P R E S S U R E

P U M P S P E E D

C A S I N 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 littleB. close the choke a littleC. increase the pump speedD. decrease the pump speedE. nothing everything looks alrightF. Possible plugged nozzleG. Possible choke wash outH. Possible choke plugging

10 0

20 0

30 0

40 0

50 0

60 0

70 0

80 0

90 0 1 0 0 0

1 1 0 0

1 2 0 0

1 3 0 0

1 4 0 0

1 5 0 0

1 6 0 0

1 7 0 0

1 8 0 0

1 90 0 1 0 0

20 0

30 0

40 0

50 0

60 0

70 0

80 0

90 0 1 0 0 0

1 1 0 0

1 2 0 0

1 3 0 0

1 4 0 0

1 5 0 0

1 6 0 0

1 7 0 0

1 8 0 0

1 9 0 0


P O S I T I O N

P S I P S I


D R I L L P IP E P R E S S U R E

P U M P S P E E D

C A S I N G P R E S S U R E3 0

6 0 0

5 8 0

6 0 0

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

A. open the choke a littleB. close the choke a little

C. increase the pump speedD. decrease the pump speedE. nothing everything looks alright


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WELL CONTROL

10 0

20 0

30 0

40 0

50 0

60 0

70 0

80 0

90 0 1 0 0 0

1 1 0 0

1 2 0 0

1 3 0 0

1 4 0 0

1 5 0 0

1 6 0 0

1 7 0 0

1 8 0 0

1 9 0 0 1 00

200

30 0

40 0

50 0

60 0

70 0

80 0

90 01 0 0 0

1 1 0 0

1 2 0 0

1 3 0 0

1 4 0 0

1 5 0 0

1 6 0 0

1 7 0 0

1 8 0 0

1 9 0 0

O PE N C L O S EC H O K E

P O S I T I O N

P S I P S I



P U MP S P E E D


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 seeon the panel.

A. open the choke a littleB. close the choke a littleC. increase the pump speedD. decrease the pump speedE. nothing everything looks alright


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WELL CONTROL

EXERCISE # 4

1. Most kicks have been caused by the failure of drilling crews to:

a. Properly install and test BOP equipmentb. Keep mud weight high enoughc. 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 whiletripping out of the hole?

a. Observe, watch for flow, and if there is none, pull out of holeb. Stop, spot a high viscosity pill, then pump out of holec. Go back to bottom, circulate bottoms up and evaluate the problemd. 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 stringb. Shut the well in quickly and properly with the least amount of gainc. Circulate the kick out using constant circulating pressure and pump strokesd. 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 formationsb. People not reacting or handling situations properlyc. BOP equipment failured. Lost circulation

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


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

a. Any time the well is openb. Any time fluid is circulated through the mud pit

c. When abnormal formation is expectedd. When drilling 12 hole


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WELL CONTROL

7. Every kick should be handled as a gas kick

a. Trueb. False

8. The first reliable indication that a kick is in progress is:

a. No warningb. An increase in pump pressurec. An increase in mud flow, mud volume and a decrease in pump pressured. Reduced drilling rate

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

a. increase

b. decreasec. stay the same

10. Final circulating pressure is reached when:

a. The influx is circulated outb. Kill mud has made a complete circulationc. Kill mud has made a bottom-upd. Kill mud reaches the bit

11. Mark the statements below "true" or "false" when drilling with a float valve in the string.

a) Surge pressure is reduced.

True

False

b) Reverse circulation is possible.

True

False

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

True

False

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

True

False


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WELL CONTROL

12. What is the primary function of the choke in the overall BOP system?

a) To divert contaminant to burning pit.b) To hold back pressure while circulating up kick.

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

13. While testing the BOP stack, it is noticed that hydraulic oil is leaking from the weep holeon 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 asurface 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 theMAASP during the well kill operation?

a) Long open hole section.b) Large difference between formation breakdown pressure and mud hydrostaticpressure.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 outtogether with 15 ft. of new hole, using a 10.2 ppg. mud. A Leak Off Pressure of 670 psi isdetermined.

16. What is the formation fracture gradient?a) 0.619 psi/ftb) 0.837 psi/ftc) 0.745 psi/ftd) 0.530 psi/ft.


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WELL CONTROL

17. What is the Maximum Allowable Annular Surface Pressure for 11.4 ppg mud used at6500 ft TVD.

a) 865 psi

b) 474 psic) 449 psid) 563 psi

18. How often should the MAASP be recalculated?

a) After every bit changeb) After a change in mud weightc) 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 11.6ppg.What is the casing pressure at surface.


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


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 normallypressure formation.c) High density mud used to create a large overbalance.d) Formation fluid pressure that exceeds normal water hydrostatic pressure.


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WELL CONTROL

23. Which factors most influence the rate at which shut in pressures stabilize after the well isshut in?

a) Gas migration

b) Friction lossesc) Permeabilityd) Type of influx

24. While running pipe back into the hole, it is noticed that the normal displacement of mudinto 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 theopen hole. Select two correct actions which can be taken to minimize pressure in the annulusduring 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 ofalertness by the driller?

a) Lost circulation.b) Gas cut mud.c) Not keeping hole full.d) Abnormal Pressures.


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WELL CONTROL

29. Which two of the following cause swabbing?

a) Pulling the pipe too fast.b) Insufficient trip margin.

c) Improper circulating density.d) Going into the hole too fast.e) Failure to slug pipe prior to pulling out of hole.

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

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

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

a) Pumping a low viscosity pill around bit to assist in reduction of balled bit orstabilizers.b) Control drilling rate so that only one slug of connection gas is in the hole at any onetime.c) Pulling out of the hole to change the bit.d) Raising Mud yield point.e) Minimizing the time during a connection when the pumps are off.


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WELL CONTROL

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

a) flow line temperature increase.b) increased rotary torquec) flow rate increase.d) decrease drill string weighte) pit volume gainf) 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 pitscontains 20 bbls. After having a kick the tank contains 240 bbls. What is the size of theinflux?.

a) 260 bblsb) 20 bblsc) 40 bblsd) 240 bbls.

37.The driller is tripping pipe out of a 12 diameter hole. 25x92 ft. stand of 5 pipe havealready been pulled. There are 85 more stands to pull. The calculated metal displacement ofthe 9 collars is 0.08 bbls/ft. The capacity of the drill pipe is 0.01776 bbls/ft and the metaldisplacement 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 topull out of hole.d) Flow check, if negative run back to bottom and monitor returns.e) Pull remaining stands out of hole.


35/98

WELL CONTROL

38. Prior to pulling out of the hole from 10485 ft. TVD, the pipe is full of 10.4 ppg. mud. Thepipe capacity is 0.01776 bbls/ft. A 25 bbls slug weighting 12.0 ppg is pumped into the drillpipe 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 psib) 0 psi.c) 117 psid) 135 psi.

39. Which of the following possible indications suggest that mud hydrostatic pressure andformation 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 thancalculated. What action must be taken?

a) Flow check, if negative displace a 100 ft. heavy slug into annulus and continue topull 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 inthe 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 5bbls to fill the hole. (Answer Yes or No to each question.)

a) Are the calculations correct?

Yes No

b) Have you taken a 5 bbls influx?

Yes No

c) All OK, keeps going?

Yes No


36/98

WELL CONTROL

42. While tripping out of the hole a kick was taken and a full bore kelly cock was stabbed andclosed. A non return type safety valve was made up on top of the kelly cock prior to strippingin. (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 drillstring?

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 apreventer.

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 upfor Hard Shut-in while drilling?

BOP Side Outlet HydraulicValve(HCR) Auto ChokeA open closed closedB open open closedC closed open openD closed closed open


37/98

WELL CONTROL

46. While drilling along at a steady rate the derrickman asks to slow the mud pumps down sothat the shakers can handle the increase in cuttings coming back in the returns. Whichone 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 insand traps which can be dumped later.b) Pick up off bottom and check for flow, if there is not any then circulate bottoms up toreduce rate so shakers can handle cutting volume, flow check periodically duringcirculation.c) Slow down the mud pump until the shakers can handle the volume of cuttings in thereturns as requested by derrickman.d) Slow down the drilling rate and the pump rate until the shakers clear up then go back tothe original parameters.


38/98

WELL CONTROL

EXERCISE # 5

1. When a kick occurs, why is it important to get the well shut in as soon as possible

a) A larger pit gain will result in a higher SIDPP resulting in a heavier kill mud weight

True or False.

b) A larger pit gain will result in higher SIDPP and SICP

True or False.

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

True or False.

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

a) BOP manifold pressure gaugeb) Choke console drill pipe pressure gaugec) Drillers console drill pipe pressure gauged) Choke console casing pressure gauge

3. A kick is being circulated out at 30 SPM. The drill pipe pressure reads 550 psi, andcasing pressure 970 psi. It is decided to slow the pumps to 20 SPM while maintaining970 psi on the casing gauge. How will this affect bottom hole pressure (exclude anyEquivalent Circulating Density [ECD] effect)? Pick one answer.

a) Increaseb) Decreasec) Stay the samed) 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 changeb) Casing pressure should be allowed to rise during SPM changec) Casing pressure should be allowed to fall during SPM change

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

a) Equal to the slow circulating rate pressureb) At least equal to the formation pressure

c) Equal to the shut in drill pipe pressured) At least equal to the shut in casing pressure


39/98

WELL CONTROL

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

a) At initial shut inb) When kill mud reaches the bitc) When kill mud reaches the shoed) When top of gas reaches the shoe

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

a) Increasesb) 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 pressureb) Increase in drill pipe pressure with no change in casing pressurec) Continually having to open choke to maintain drill pipe and casing pressured) 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 thegradual closing of the choke have on the bottom hole pressure?

a) Decreasesb) Increasesc) Stays the same

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

a) Trueb) 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 hole at 11,000 ft. (TVD)with 5 drill pipe and 750 ft. of 6 drill collarsAnnular capacities5" DP / 8 " Hole, = 0.0459 bbls / ft.DC /8 " Hole, =0.0292 bbls / ft


40/98

WELL CONTROL

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


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

a) Increaseb) Decreasec) Remain approximately the same

13. What will happen to Bottom hole Pressure?


14. What will happen to Shut in Casing Pressure?


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


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?



41/98

WELL CONTROL

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

a) Increaseb) Decrease

c) Remain approximately the same

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


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


21.A kick is being circulated from a well using the Drillers Method; Pumping pressurehaving been established as 1000 psi at 30 SPM. During the operation, pressure suddenlyincreases to 1350. You are reasonably sure that a Nozzle of the Bit is plugged. Whatshould you do?

a) Reduce pump pressure to 1000 psi by adjusting the chokeb) Shut the well in and re-establish the pumping pressurec) Hold casing pressure constant at the value recorded just before the bit pluggedd) (a) and (b) are acceptable courses of action

22. During the well kill operation, slowly but regularly you have had to reduce choke sizebecause 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 outb) The choke is washing out

c) You have a washed out pump swab

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

constant.What happens to Bottom Hole Pressure?

a) Increasesb) Decreasesc) Remains approximately the same


42/98

WELL CONTROL

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

a) Bottom hole pressure

b) Kick tolerancec) Formation fracture pressured) 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 drillpipe pressure remains unchanged but the casing pressure goes up. What is the probablecause for this?

a) Choke is plugging offb) Bit is plugging offc) Hole in drill piped) Choke is washing out

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

a) a washed out bit nozzleb) a washed out chokec) a pump failure

27. How can a washout at the adjustable choke be recognized?

a) Drill pipe and casing pressures both fallingb) Drill pipe and casing pressures both risingc) Rapid rise in casing pressure with no change to drill pipe pressured) 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 pressureis:

a) The cuttings in the annulus are lighter, therefore creating a lighter hydrostatic in theannulus.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 anoffshore or land operation.d) The only difference is in the type of gauges used.


43/98

WELL CONTROL

29. After shutting in on a kick, the SIDPP and SICP are observed to be stable for fifteenminutes. Both, then, start rising slowly by the same amount. Which one of the followingis the probable cause?

a) A further influx is occurringb) The influx is migrating up the well borec) The gauges are faultyd) 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 isno float in the drill string. What kill mud weight is required?

a) 10.3 ppgb) 11.3 ppg

c) 10.7 ppgd) No way of knowing

31. Shut in casing pressure is used to calculate

a) Kill weight mudb) Influx gradient and type when influx volume and well geometry are knownc) Maximum Allowable Annular Surface Pressured) 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 gaugeb) Pump at kill rate into the drill string with the well shut in. When casing pressurestarts 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 pumpingpressure 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 openingthe choke. The pressure shown when the pump is at kill rate is the SIDPP.

33.After circulating out a kick using the drillers method (no weight up), are the SICP andSIDPP about the same?

a. yesb. no

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

a) Increase

b) Stay the samec) Decrease


44/98

WELL CONTROL

35. On a surface stack, what would happen if when bringing the pumps up to kill speed, thecasing 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 borec) It would have no effect on anything

36. For each of the following statements, note whether it relates to the Drillers Method orthe 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 maintainan acceptable bottom hole pressure?

a) Pumping a volume of mud into the well, equal to the drill pipe closed enddisplacement at regular intervalsb) Bleeding off the drill pipe steel displacement at regular intervalsc) Pumping a volume of mud into the well, equal to the drill pipe steel displacement, atregular 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 Weightmethodb) If the kill mud is being circulated up the annulus before the kick has reached theshoe then Wait and Weight method will reduce the risk of breaking down the formationcompared to using the Drillers methodc) The Wait and Weight method should always be used because the pressure againstthe open hole will always be lower when using the Drillers method


45/98

WELL CONTROL

39. Mud weight increase required to kill a kick should be based upon :

a) shut in drill pipe pressureb) shut in casing pressure

c) original mud weight plus slow circulation rate pressure lossesd) 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 slowpump 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 psiback pressure on drill pipe side with chokeb) Add 400 psi to casing pressure and bring pump up to kill rate while using the choketo keep the casing pressure +400 constant

c) Bring pump strokes up to kill rate while keeping casing pressure constant bymanipulating the choke, observed pump pressure is ICPd) Add 1000 psi to shut in drill pipe pressure and circulate out the kick

41.Having completed the first circulation of the Drillers Method, the well is shut in. Shouldcasing pressure be:

a) Less than Shut in Drill Pipe Pressureb) Equal to Shut in Drill Pipe Pressurec) Greater than Shut in Drill Pipe Pressure

42.On the second circulation of the Drillers method, if the casing pressure was heldconstant until the kill mud reached Surface, what would happen to the bottom holepressure?

a) Increaseb) Decreasec) Stay the same

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

a) Increasesb) Decreasesc) Stays the same


46/98

WELL CONTROL

44. You have taken a kick with a non-return valve (float) in the drill string. After shutting thewell 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 deadc) Use either the rig pump or cementing unit pump to increase pressure in 100 psiincrements until a change is seen on casing gauged) Pump slowly into the drill pipe. When the pump pressure stabilizes, the float isopen. The pumping pressure is the SIDPP used to calculate kill mud

45.A well is being killed using the Drillers Method.Original shut-in drill pipe pressure = 500 psiOriginal 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 psiShut-in casing pressure = 650 psi

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

a) Prepare to use the Wait and Weight methodb) Bull-head the annulus until shut-in casing pressure is reduced to 500 psic) Reverse circulate until shut-in casing pressure is reduced to 500 psid) Continue with second circulation of Drillers Method (holding casing pressureconstant until mud reaches the bit)

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

a) Bring pump up to the desired rate, while holding the casing pressure 150 psi abovethe original SICPb) Bring pump up to desired rate, but hold 200 psi back pressure on the drill pipec) Bring pump up to the desired rate holding casing pressure constant by manipulatingthe 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 manifoldb) the drill pipe pressure gauge on the drillers consolec) the casing gauge on the drillers consoled) the drill pipe gauge on the remote auto choke panele) the casing gauge on the remote auto choke panel


47/98

WELL CONTROL

EXERCISE # 6

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

b) To show that the primary mud seal on the piston rod is leaking.c) To show that the Bonnet seals are leaking.d) To show that the closing chamber operating pressure is too high.

2. You only have one inside BOP with an NC 50 (41/2 IF) lower pin connection on your rigbut the drill string consist of 5 HWDP, and 8 collars. Which one of the followingcrossovers would you have on the drill floor in case of kick while tripping?a) 6-5/8 reg. Box X 7-5/8 reg. Pinb) NC50 (4-1/2 IF) Pin X 6-5/8 reg. Pinc) NC50 (4-1/2 IF) Box X 7-5/8 reg. Pind) 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 BOPType 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 stringHas 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 andchoke lines are connected under the blind-shear rams. Is it possible to kill a well using theDriller'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 andchoke 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 andchoke 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?


48/98

WELL CONTROL

7. The kill line should enter a stack so that

a) The well can be circulated if the blind rams are in use.

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

8. Which of the following statements are true concerning Ram Packing Elements?

a) Reciprocating motion of the pipe increases the wear on seals.b) Closing pipe rams on open hole may damage the elements.c) The ram packer should normally be checked, and if worn, changed whenever thebonnet is opened.d) All of above.

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

a) serial numberb) pressure ratingc) typed) 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 ringgaskets. Each flange (1,2,3 and 4) mates with one of the ring gaskets (A,B,C or D). Write theappropriate flange number in the blanks.

Ring Gasket Marking Flange

A -CI API BX154 S304-4B -OES API R57 D-4

C- OES API RX66 S-4D -CI API BX153 S316-4

Flange Marking

1. OES API 16-3/4 3M RX66 6A 89 300F PSL3 05/912. CI API 3-1/16 15M BX154 CRA 6A 89 250F PSL2 PRL2 08/923. OES API 2-9/16 20M BX153 CRA 6A 89 350F PSL4 PRL4 01/944. OES API 13-5/8 2M R57 6A 89 250F PSL1 PRL1 11/93

Gasket Flange

AB

C

D


49/98

WELL CONTROL

12. From the list below, identify the ring gaskets that are pressure energized. (Pick fouranswers)

a) Type RXb) Type BX

c) Type AXd) Type R ovale) Type R octagonalf) Type CX

13.Which dimension from the list below is used to identify the Nominal Flange Sizea) 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 thatmaximum anticipated formation pressures do not exceed 75% of BOP equipment pressureratings, what is the minimum acceptable rating for equipment to be used in drilling normallypressure formation to 16000 ft TVD?

a) 2000 psi BOP equipmentb) 3000 psi BOP equipmentc) 5000 psi BOP equipmentd) 10000 psi BOP equipmente) 15000 psi BOP equipment

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

Component Volume to Open Volume to closeAnnular BOP 27 29Ram BOP 13 15


50/98

WELL CONTROL

17.The following statements relate to the drillers remote control BOP control panel locatedon 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 eachfunction 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 Falsed) 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 BOPssmaller 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 pressureb) Annular pressurec) Accumulator pressurec) Precharge pressure

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

a) Manifold pressureb) Annular pressure

c) Accumulator pressured) Air pressure


51/98

WELL CONTROL

22. In the case below, identify the most likely problem from the gauge readingsobserved on the remote control panel. The annular setting is 900 psi, the manifold setting is1,500 psi.

a) Everything is OK.b) Malfunction pressure regulating valve.c) Malfunction hydro-electric switchd) Leaking in hydraulic circuite) Precharge pressure is to low

23. A BOP operating unit has 8 accumulator bottles, each with a capacity of 10 gallons.Operating pressure is 3000 psi. Precharge pressure is 1000 psi. What is the total usablefluid volume when the minimum BOP operating pressure is 1,200 psi?

Answer: gal

24. On a 3000 psi accumulator system, what are the normal operating pressures seen on thefollowing gauges on the drillers remote control panel?

Air pressure = psi

Accumulator pressure, = psi

Manifold pressure, = psi

Annular pressure = psi

25. On which two gauges on the remote panel would you expect to see reduction in pressurewhen the annular preventer is being closed?

26. If the air pressure on the drillers panel reads 0 psi, which of the following statements istrue?

a) No stack function can be operated from the remote panel.b) All stack function can be operated from the remote panel.c) Choke and kill lines can still be operated from the remote panel.d) The annular preventer can still be operated from the remote panel.

27. Which of the problems below would not stop the BOP from closing?

a) Master control valve was not held down.b) Four-way valve did not shift position.c) Closing line in the BOP was blocked.d) Leak in the hydraulic line to the BOP or in the BOP closing chamber.e) Air pressure to the panel was lost.f) A bulb has blown on the remote panel.


52/98

WELL CONTROL

28. When drilling, which may be the correct position of the 4-way valves on the BOPaccumulator unit?

a) openb) close

c) neutrald) open or closed depending on BOP stack function

29. What is the normal precharge for the accumulator bottles on a 3000 psi accumulator unit?a) 1000 psib) 3000 psic) 1200 psid) 200 psi


53/98

WELL CONTROL

EXERCISE # 7

Use the Well Data to answer the questions.

WELL DATA


Kick Off Point 4,000 TVD / 4,000 MDEnd Of Build 5,447 TVD / 5,667 MDBit size 8.5Drill Pipe 5 OD. 19.5 lbs/ft

Capacity = 0.01776 bbls/ftHeviwate 5 OD x 3 ID x 720 ft

Capacity = .00874 bbls/ftDrill Collars 61/2 x 2

13/16 x 820 ftCapacity = 0.0077 bbls/ft

Casing 95/8, 47 lb/ft. P110 8.681 ID100% Internal yield = 10,900 psiSet at 6,175 ft TVD / 6,800 MD

Formation strength test 1,270 psi w/ 10.4 ppgMud weight in use 11.5 ppg.Surface Volume 320 bblsPumps National triplex 12-P-160

With 6

1

/2 LinersCapacity = 0.117 bbls/stk

PUMP PRESSURE

Slow Pump Rate 520 psi at 40 spm

ANNULAR VOLUMES

Drill pipe/HW - Casing = 0.0478 bbls/ftDrill pipe/HW - Open hole = 0.0447 bbls/ftDrill collars - Open hole = 0.0292 bbls/ft

WELL CONTROL DATA

SIDPP = 750 psiSICP = 900 psiGAIN = 22 bbls

You are recommended to complete a kick sheet to answer the following questions:


54/98

WELL CONTROL

1. How many strokes to pump from surface to bit:

2. What is the Initial Circulating Pressure?

3. What is the Final Circulating Pressure?

4. How many strokes to pump from surface to KOP?

5. What is the circulating pressure when kill mud reaches the KOP?

6. How many strokes to pump from surface to the EOB?

7. What is the circulating pressure when kill mud reaches the EOB?

8. Calculate the pressure drop per 100 strokes of kill mud pumped inside the

string from the EOB to the bit?


55/98

WELL CONTROL

9. Calculate MAASP after circulation of kill mud?

10.What is the approximate time needed to kill the well?


56/98

WELL CONTROL

EXERCISE # 8

Use the Well Data to answer the questions. Each question has only one correctanswer.

WELL DATA


Marine riser 1700 ft capacity = 0.360 bbls/ftChoke line 1724 ft capacity = 0.0087 bbls/ftBit size 8.5Drill Pipe 5 OD. 19.5 lbs/ft

Capacity = 0.01776 bbls/ftDrill Collars 61/2 x 213/16 x 540 ft

Capacity = 0.008 bbls/ftCasing 95/8, 47 lb/ft. P110 8.681 ID

100% Internal yield = 10,900 psiSet at 14,000 ft TVD14,200 ft MD RKB

Mud weight in use 12.4 ppg.Pump output 0.117 bbls/stk

PUMP PRESSURE

While Drilling 3500 psi at 75 spm (APL = 270 psi)Slow Pump Rate Up Riser 980 psi at 40 spm (APL = 75 psi)

250 psi at 20 spm (APL = 20 psi)CLFL with 11 ppg mud 125 psi at 20 spm

500 psi at 40 spm

ANNULAR VOLUMES

Drill pipe - Casing = 0.0489 bbls/ftDrill pipe - Open hole = 0.0459 bbls/ftDrill collars - Open hole = 0.0292 bbls/ft

Drill pipe

Riser = 0.336 bbls/ft

WELL CONTROL DATA

SIDPP = 700 psiSICP = 1150 psiGAIN = 30 bbls

LEAK OFF TEST DATA

3650 PSI with 11 ppg mud


57/98

WELL CONTROL

1. What is the total capacity of the drill string?

a) 288 bblsb) 162 bbls

c) 335 bblsd) 456 bbls

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


3. What is the surface to bit time with the pump running at 40 spm?

a) 61 minutesb) 25 minutesc) 87 minutesd) 54 minutes

4. Calculate bit to surface time (bottoms up) at 40 spm?

a) 155 minutesb) 234 minutesc) 60.3 minutesd) 123 minutes

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


6. The ICP (initial circulating pressure) at 40 spm will be approximately?


7. The FCP (final circulating pressure) at 40 spm will be approximately?

a) approximately 1800 psib) approximately 1050 psic) approximately 1500 psi

d) approximately 1290 psi


58/98

WELL CONTROL

8. After reaching FCP it is decided to increase the pump speed to 50 spm. Whatwould happen to BHP if the drill pipe pressure is held constant at the originalFCP value?

a) increase by about 590 psib) decrease by about 590 psic) remain constant because drill pipe pressure was not changedd) increase by about 500 psi

9. What is formation pressure based on the shut in data?

a) 10,823 psib) 6800 psic) 7800 psid) 6240 psi

10.What is the ECD on bottom while drilling?


11.What would be the circulating pressure while drilling if the pump was decreasedto 60 spm?


12.At 75 spm what is the annular velocity around the drill collars?

a) 412 ft/minb) 210 ft/minc) 506 ft/min

d) 300 ft/min

13.What is the maximum allowable mud weight?



59/98

WELL CONTROL

14.What is the approximate length of the influx?

a) 1027 ftb) 850 ft

c) 653 ftd) 342 ft

15.The gradient of the influx is about?

a) 0.115 psi/ftb) 0.320 psi/ftc) 0.465 psi/ftd) 0.433 psi/ft

16.How many strokes to go from ICP to FCP?

a) 1282 stksb) 1363 stksc) 1680 stksd) 2461 stks

17.Calculate the MAASP?


18.Not following the the correct pressure schedule, the BHP could be high or lowcausing losses or another influx.

a) Trueb) False

19.What is the capacity of the choke line:


20.How many strokes are required to displace the riserannulus

a) 7034 strokesb) 4882 strokesc) 3453 strokesd) 1234 strokes


60/98

WELL CONTROL

21.If the well had been shut in with 0 psi on the drill pipe pressure and no float inthe string and a SICP of 300 psi, what mud weight would have required to killthe well?


Answer the following gauge questions as the well is killed using the Drillersmethod.

10 0

20 0

30 0

40 0

50 0

60 0

70 0

80 0

90 0 1 0 0 0

1 1 0 0

1 2 0 0

1 3 0 0

1 4 0 0

1 5 0 0

1 6 0 0

1 7 0 0

1 8 0 0

1 9 0 0 1 0 0

20 0

30 0

40 0

50 0

60 0

70 0

80 0

90 0 1 0 0 0

1 1 0 0

1 2 0 0

1 3 0 0

1 4 0 0

1 5 0 0

1 6 0 0

1 7 0 0

1 8 0 0

1 9 0 0


P O S I T I O N

P S I P S I


D R I L L P I P E P R E S S U R E

P U M P S P E E D

C A S I N G P R E S S U R E

1 20

4 0

1 6 80 5 9 0

22.The kill operation has started. This is what the choke control console shows.

What should you do?

a) open the choke a littleb) close the choke a littlec) nothing everything looks alrightd) Possible plugged nozzlee) Possible choke plugging

10 0

20 0

300

40 0

50 0

60 0

70 0

800

900 1 0 0 0

1 1 0 0

1 2 0 0

1 3 0 0

1 4 0 0

1 5 0 0

1 6 0 0

1 7 0 0

1 8 0 0

1 90 0 1 00

20 0

30 0

40 0

50 0

60 0

70 0

80 0

90 0 1 0 0 0

1 1 0 0

1 2 0 0

1 3 0 0

1 4 0 0

1 5 0 0

1 6 0 0

1 7 0 0

1 8 0 0

1 9 0 0


P O S I T I O N

P S I P S I



P U M P S P E E D


1620

5 0 0

7 0 0


61/98

WELL CONTROL

23.Pit room calls up to confirm a .5 bbl rise in the level. What should you do?

a) open the choke a littleb) close the choke a little

c) increase the pump speedd) decrease the pump speede) nothing everything looks alright

10 0

20 0

30 0

40 0

50 0

60 0

70 0

80 0

90 01 0 0 0

1 1 0 0

1 2 0 0

1 3 0 0

1 4 0 0

1 5 0 0

1 6 0 0

1 7 0 0

1 8 0 0

1 90 0 1 00

200

30 0

40 0

50 0

60 0

70 0

80 0

9001 0 0 0

1 1 0 0

1 2 0 0

1 3 0 0

1 4 0 0

1 5 0 0

1 6 0 0

1 7 0 0

1 8 0 0

1 9 0 0


P O S I T I O N

P S I P S I



P U M P S P E E D


4 5 5 0

1 6 80 1 4 80

24.The pit levels are still reported to be increasing slightly. This is what you see onthe panel.

a) open the choke a littleb) close the choke a littlec) possible choke washoutd) possible choke plugginge) nothing everything looks alright

100

200

30

400

500

00

700

80 0

90 0 1000

1100

1 2 0 0

13 0

1 4 0 0

1 00

1 6 0 0

1 7 0 0

1 8 0 0

1 90 0 10 0

20 0

30 0

400

50 0

600

00

800

90 01 0 0 0

1 1 0 0

1 2 0 0

1 3 0 0

14 0

1 5 0 0

1 6 0 0

1 7 0 0

18 0

1 9 0 0

O P E N CL O S EC H O K E

P O S I T I O N

P S I P S I

T OT A L S T ROK E S

DRI L L P I P E P RE S S URE

P U M P S P E E D

CA S I NG P RE S S URE4 0

5600

14 00 1720


62/98

WELL CONTROL

25.Experienced a sudden increase in casing pressure over the last 100 strokes.Gas is venting and pit levels are reported to be falling. What are you going to donow?

a) open the choke a littleb) close the choke a littlec) possible nozzle pluggingd) possible choke plugginge) nothing everything looks alright

100

200

300

400

500

600

700

800

9001000

1100

1200

1300

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 C LOSEC H OKE

POSITION

P S I P S I


D R I L LP I P E P R E S S U R E

P U M P S P E E D


1680

6 2 2 0

1 4 0

26.Not hearing anymore gas. How are things going?

a) open the choke a littleb) close the choke a littlec) casing pressure should be 0d) possible choke wash oute) good everything looks alright

10 0

20 0

30 0

40 0

50 0

60 0

70 0

80 0

90 0 1 0 0 0

1 1 0 0

1 2 0 0

1 3 0 0

1 4 0 0

1 5 0 0

1 6 0 0

1 7 0 0

1 8 0 0

1 9 0 0 1 0 0

20 0

30 0

40 0

50 0

60 0

70 0

80 0

90 01 0 0 0

1 1 0 0

1 2 0 0

1 3 0 0

1 4 0 0

1 5 0 0

1 6 0 0

1 7 0 0

1 8 0 0

1 9 0 0


P O S I T I O N

P S I P S I



P U M P S P E E D


7 0 0

6300

7 0 0


63/98

WELL CONTROL

27.Shut back in. What should you do?

a) Check MW = 13.3 ppgb) Check MW = 16 ppg

c) Reset stroke counterd) Bleed off pressure to 0e) nothing everything looks alright

10 0

200

30 0

40 0

50 0

60 0

70 0

80 0

900 1000

1100

1200

1300

1400

1500

1600

1700

1800

1900 100

200

300

400

500

600

70 0

80 0

900 1000

1100

1200

1300

1400

1500

1600

1700

1800

1900

O P E N C LOS EC H O K E

PO SI T I O N

P S I P S I



P U M P S P E E D


0 0 0 0

1 7 80 2 3 6

28.Got the pump to kill speed and have just reset the stroke counters having

pumped the surface line. What should you do?

a) open the choke a littleb) close the choke a littlec) increase the pump speedd) decrease the pump speede) nothing everything looks alright

100

20

300

400

500

00

700

00

9001 00

1100

1200

1300

14 0

1500

1600

1700

180

1900 1 0

200

300

400

500

600

700

800

9001000

110

1200

1300

1400

1500

1600

1700

1800

19 0

OP EN CL OSECHO K E

POSITION

PS I P SI

T O T A L S T R O E S

D I LL P IP E P R S S R E

P U M P S P E E D

C A S N G P RE S S U E40

25 0

1620 140


64/98

WELL CONTROL

29.Pump room is on the phone saying pit levels are OK. What are you going to donow?

a) open the choke a little

b) close the choke a littlec) possible nozzle pluggedd) possible choke pluggede) nothing everything looks alright

100

200

300

400

500

600

700

800

9001000

1100

1200

1300

1400

1500

1600

1700

1800

1900 100

200

300

400

500

600

700

800

9001000

1100

1200

1300

1400

1500

1600

1700

1800

1900

O PEN CLOSECHOK E

POSITION

P S I P S I



P U M P S P E E D


1430

9 8 0

1 4 0

30.Drill pipe pressure is falling but casing pressure stay constant. How are things

going?

Documents

73236775 3 Well Control Exercises