3 - well control exercises

WELL CONTROL

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 surfaceb. 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 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 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

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 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 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 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 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 12 ppg, what is the casing pressure at the surface? (Hole TVD 7000ft)


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 at 7350ft. 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

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 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.D. The pressure loss in the annulus

WELL CONTROL

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/ftDP. Capacity = .01776 bbls/ftCasing Capacity = .0758 bbls/ftMud Weight = 10 ppg

A. 48 psiB. 483 psi C. 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 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/ftDP. Capacity = .01776 bbls/ftCasing Capacity = .0758 bbls/ftMud Weight = 12 ppg

A. 650 psiB. 6 psiC. 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 weightB. shut in drill pipe pressure and mud weightC. 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 Circulating Pressure?

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 weight D. slow circulating rate pressure, drilling mud weight and final circulating pressure

WELL CONTROL

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

A. one circulationB. two circulations C. 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 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

WELL CONTROL

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

Drill collar length: 700 ftDC - OH Capacity .0292 bbl/ftDP - 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 Answer800 720 11.5 400950 600 10.6 840680 550 10.2 350

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

SICP (psi) SIDPP (psi) Mud Wt (ppg) TVD (ft) Answer600 450 10 9500850 690 11 12000780 570 10.5 11200700 300 14 13000

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

BHCP (psi) Mud Wt (ppg) Depth TVD (ft) Answer6000 11.6 94502600 9.8 50005700 10 10000

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

Old pump pressure Old Mud weight New mud Weight Answer2500 16 17.51700 10 14

WELL CONTROL

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

Old SPM Old pressure New SPM Answer40 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 800010.2 114009.4 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 ?

Answer: ft/min

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 pipe are 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 pipe are 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 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/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

WELL CONTROL

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 mudb. Lower than the same kick in water – based mudc. 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 ftb. 1282 ftc. 9600 ftd. 2182 ft

WELL CONTROL

EXERCISE # 2

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

a. drill pipe gauge on driller’s panelb. casing gauge on driller’s 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 to 670 psi surface pressure. What is the formation fracture gradient calculated from the test?

a. 0.564 psi/ftb. 0.678 psi/ftc. 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. decreasec. 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 recipeg. An accurate surface pressure gaugeh. A long open hole section

WELL CONTROL

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


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 drilling practices? (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 the reduction in BHP?


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?


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 15 minutes? MW: 10.5 ppg MD: 7500 ft TVD:7000 ft

a. 366 ft/hrb. 455 ft/hrc. 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 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?


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 the open hole volume minus the influx volume?

a. trueb. false

WELL CONTROL

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

a. trueb. 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 driller’s 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. trueb. 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. trueb. false

WELL CONTROL

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

a. increaseb. 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 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 lbsc 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

WELL CONTROL

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


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


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.

WELL CONTROL

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.

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/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 e. All stack functions.

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 the well kicks and is closed in.

Shut in Drill Pipe Pressure : 750 psiShut in Casing Pressure: 1050 psi Kick 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 psib) 1600 psic) 1900 psi

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


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

WELL CONTROL

EXERCISE # 3

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

WELL DATA

Well Depth 10,000 ft TVD10,000 ft MD

Marine riser 800 ftChoke line 820 ft capacity = 0.0087 bbls/ftBit size 8.5”Drill 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 213/16” x 750 ft Capacity = 0.00768 bbls/ftCasing 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/ftDrill pipe - Open hole = 0.0459 bbls/ftDrill collars - Open hole = 0.0292 bbls/ftDrill pipe – riser = 0.336 bbls/ftActive surface volume = 320 bbls

WELL CONTROL DATA

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

WELL CONTROL

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

A. 150 bblsB. 162 bblsC. 197 bblsD. 180 bbls

2. Calculate the total annular capacity with the pipe on bottom while controling the 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 ppgB. 13.0 ppgC. 12.4 ppgD. 16.0 ppg

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

A. 270 psiB. 770 psiC. 990 psiD. 1200 psi

WELL CONTROL

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

A. approximately 800 psiB. approximately 390 psiC. 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 the original FCP value?

A. increase by about 225 psiB. decrease by about 225 psiC. remain constant because drill pipe pressure was not changedD. 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?


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?


WELL CONTROL

13. What is the approximate length of the influx?

A. 1027 ftB. 850 ftC. 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 minutesD. 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

WELL CONTROL

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?


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 the new kill weight be?


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

A. 30 psi/100 stksB. 35 psi/100 stksC. 50 psi/100 stksD. 66 psi/100 stks

WELL CONTROL

Answer the following gauge questions as the well is killed using the Drillers method.

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

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

WELL CONTROL

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

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 while tripping 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 to be:


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 openb. Any time fluid is circulated through the mud pitc. When abnormal formation is expectedd. When drilling 12 ¼ hole

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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. increaseb. 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

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

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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 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 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.

17.What is the Maximum Allowable Annular Surface Pressure for 11.4 ppg mud used at

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6500 ft TVD.


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 ftTVD) 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.


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

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

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shut in?

a) Gas migrationb) 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.

29.Which two of the following cause swabbing?

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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 gasd) 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 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.e) Minimizing the time during a connection when the pumps are off.

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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 ¼” diameter hole. 25x92 ft. stand of 5” pipe havealready been pulled. There are 85 more stands to pull. The calculated metal displacement ofthe 9 ½” 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 to pull out of hole.d) Flow check, if negative run back to bottom and monitor returns.e) Pull remaining stands out of hole.

38.Prior to pulling out of the hole from 10485 ft. TVD, the pipe is full of 10.4 ppg. mud. The

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pipe 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 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 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

42.While tripping out of the hole a kick was taken and a full bore kelly cock was stabbed and

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closed. 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 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 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

46.While drilling along at a steady rate the derrickman asks to slow the mud pumps down so

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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 toreduce 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 thereturns 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 gaugeb) Choke console drill pipe pressure gaugec) Driller’s 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, 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) 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 pressurec) Equal to the shut in drill pipe pressured) 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 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 will happen to Bottom Hole Pressure?

a) Increasesb) Remains the samec) 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 on the 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 ½” hole at 11,000 ft. (TVD)with 5” drill pipe and 750 ft. of 6 ½” drill collarsAnnular capacities5" DP / 8 ½" Hole, = 0.0459 bbls / ft.DC /8 ½" Hole, =0.0292 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 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?


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


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 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. What should 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 outc) 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) Increasesb) Decreasesc) Remains approximately the same

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

a) Bottom hole pressureb) 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 drill pipe pressure remains unchanged but the casing pressure goes up. What is the probable cause 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 and choke 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 pressure is:

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 an offshore or land operation.d) The only difference is in the type of gauges used.

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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 following is 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 is no float in the drill string. What kill mud weight is required?

a) 10.3 ppgb) 11.3 ppgc) 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 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. yesb. no

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

a) Increaseb) Stay the samec) Decrease

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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 downb) 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 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 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 intervalsd) 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 methodb) 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 methodc) 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 pressureb) shut in casing pressurec) 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 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 chokeb) Add 400 psi to casing pressure and bring pump up to kill rate while using the choke to keep the casing pressure +400 constantc) Bring pump strokes up to kill rate while keeping casing pressure constant by manipulating 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 Driller’s Method, the well is shut in. Should casing 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 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) Increaseb) Decreasec) 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) Increasesb) Decreasesc) 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 mudb) 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 psi increments until a change is seen on casing gauged) 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 thenread :

Shut-in drill pipe pressure = 500 psiShut-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 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 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 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 manipulating the hydraulic choked) 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

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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 rigbut 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. 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 2Requires the use of key to closeMust not run in the hole in the close positionHas 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 keyEasier 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 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 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?

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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 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-4C- 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 FlangeABCD

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

a) Type RXb) Type BXc) Type AXd) Type R ovale) Type R octagonalf) 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 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 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 closeAnnular BOP 27 29Ram BOP 13 15

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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 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 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 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 pressurec) Accumulator pressured) Air pressure

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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 usable fluid volume when the minimum BOP operating pressure is 1,200 psi?

Answer: gal24.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.

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

a) openb) closec) 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

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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 8.5”Drill Pipe 5” OD. 19.5 lbs/ft Capacity = 0.01776 bbls/ftHeviwate 5” OD x 3” ID x 720 ft


100% Internal yield = 10,900 psi Set at 6,175 ft TVD / 6,800 MDFormation 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 61/2” Liners

Capacity = 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:

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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?

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9. Calculate MAASP after circulation of kill mud?

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

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EXERCISE # 8

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

WELL DATA


Marine riser 1700 ft capacity = 0.360 bbls/ftChoke line 1724 ft capacity = 0.0087 bbls/ftBit size 8.5”Drill 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 psi Set at 14,000 ft TVD – 14,200 ft MD RKBMud 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/ftDrill pipe – Riser = 0.336 bbls/ft

WELL CONTROL DATA


LEAK OFF TEST DATA

3650 PSI with 11 ppg mud

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


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 psid) approximately 1290 psi

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8. After reaching FCP it is decided to increase the pump speed to 50 spm. What would happen to BHP if the drill pipe pressure is held constant at the original FCP 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 decreased to 60 spm?


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

a) 412 ft/minb) 210 ft/minc) 506 ft/mind) 300 ft/min

13.What is the maximum allowable mud weight?

a) 17.5 ppgb) 16.0 ppg

c) 18.0 ppg d) 19.0 ppg

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14.What is the approximate length of the influx?

a) 1027 ftb) 850 ftc) 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 low causing 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 riser – annulus

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

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


Answer the following gauge questions as the well is killed using the Drillers method.

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

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

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

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

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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 do now?

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

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

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27.Shut back in. What should you do?

a) Check MW = 13.3 ppgb) Check MW = 16 ppgc) Reset stroke counterd) Bleed off pressure to 0e) nothing everything looks alright

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

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

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

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

a) open the choke a littleb) close the choke a littlec) increase the pump speedd) possible choke wash oute) good everything looks alright

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31.Had to shut in because of a pump. What do you thing?

a) Drill pipe pressure is too lowb) Casing pressure is too highc) Drill pipe pressure is too highd) Casing pressure is too lowe) Everything looks alright

32.Back up to kill speed. Company man wants to know how things are going. What do you tell him?

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

WELL CONTROL

EXERCISE # 9

1. A driller needs to close in a flowing well with drill pipe in a subsea BOP stack. HePushes the “Annular Close” button and the pilot light changes, but all gauges and the flow meter remain static. What is his best option?

a) Change pod and try again.b) Call and wait for the subsea engineer.c) Send assistant driller to manually operate the 4-ways valve on the Hydraulic Control Manifold to close the annular.d) Close the lower annular preventer.

2. While drilling, an alarm goes off indicating low accumulator pressure and the flow meterIndicates a rapid loss of fluid. The best course of action is:

a) Stop drilling and shut the well in.b) Stop drilling and call subsea engineer.c) Stop drilling and put all function in block one at a time until the flow stops.d) None of the above.

3. When a function is operated, which of the following is true?

a) SPM valve will operate in both pods.b) SPM valve will operate only on the active pod.c) The SPM valve will operate after the function is complete.

4. How much time is allowed for subsea ram type preventer to close in API RP53?

a) 30 secondsb) 45 secondsc) 60 secondsd) 50 seconds

5. From which position in the hydraulic circuit is readback pressure taken?

a) Upstream of the regulator in the pod?b) The regulator itself?c) Down stream of the regulator in the pod?

6. What is the principal reason for fitting ram locking devices such as wedgelocks orPoslocks to a subsea stack?

a) To give additional force when closing in, thus reducing delay times.b) To lock the ram in the closed position and maintain the shear rams locked during disconnect.c) To lock the BOP stack to the well head and lock the lower Marine Riser Package to the BOP stack.

WELL CONTROL

7. The subsea hydraulic BOP control system is divided into a Control System and a PilotSystem. Which two statements are true with respect to the Pilot System?

a) The fluid in the Pilot System flows continuously while a function on the BOP takes place.b) The Pilot System dumps fluid to the sea at every operation of BOP functions.c) The Pilot System controls the position of all shuttle valves on the BOP stack directly.d) The Pilot system is a closed dead-end system.e) Pilot fluid consists of potable water, water-soluble concentrate and glycol.

8. Which two statements are true with respect to shuttle valves on a subsea stack?

a) The shuttle valves automatically seal any hydraulic leaks in the selected pod.b) The shuttle valves prevent communication between the selected system and the redundant system.c) The shuttle valves are pilots operated.d) The shuttle valves allow the retrieval of a malfunctioning pod without losing hydraulic BOP control.

9. What is the purpose of the "Memory Function" on electric control panels?

a) Memory Function indicates a malfunction by giving permanent light on the alarm panel after an alarm has been acknowledged and the audible alarm has stopped.b) Memory Function reminds the driller to add anti-freeze fluid when the temperature drops below a set level.c) Memory Function indicates the previous position before “Block position” of three position functions.d) Memory Function reminds the driller to engage Wedge Locks before hanging off.

10.Which of the following statements is true regarding to the use of “manipulator” type 4-Ways valve used in subsea hydraulic BOP control systems.

a) If the valve is shifted to the center or “block” position, pressure will be vented from the line previously pressurised.b) If the valve is shifted to the center or “block” position, pressure will be trapped in the line previously pressurised.

11.Name 3 potential causes of riser collapse:

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12.What is the purpose of sub-sea stack mounted bottles?

a) to minimize the time to operate any BOP functionb) to maximize the time to operate any BOP functionc) to minimize the time to operate annular type preventerd) to optimize the time to operate ram type preventer

The drillers BOP panel has gauges for pilot and readback pressure for the manifold and annular pressure. Answer true or false to the following statements:

13. Pilot pressure and readback pressure should normally be the same.

a) trueb) false

14.Read back pressure is mesured at the output from the sub sea regulator

a) trueb) false

15.Pilot pressure is measured at the out put of the surface regulator

a) trueb) false

Answer true or false in each case to measure Choke Line Friction Loss (CLFL):

16. You can pump down the choke line taking return up the riser.

a) trueb) false

17.You need to know the length of the choke line.

a) trueb) false

18.You can pump down the drill string taking returns through the riser and then close the annular and take returns through the choke line.

a) trueb) false

19. While pumping down the choke line at 150 gpm taking returns through the riser with 9 ppg mud in 750 feet water with 60 feet air gap, a stand pipe pressure of 65 psi was recorded. Estimate CLFL:


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20.What would be the new CLFL if the mud weight is increased to 13.5 ppg (use data from Q-19)

a) 65 psib) 97.5 psic) 132 psid) 234 psi

21.While pumping down the drill string and up the riser, a circulating pressure of 375 psi was recorded.The annular was closed and returns taken through a wide open choke, circulating pressure was now 600 psi. What are the CLFL?


22. Calculate the Maximum Allowable Mud Weight with the following data:

Hole size 17 ½”, Air gap is 80 ft,

Water depth is 220 ft,Casing shoe is 600 ft RKB, Sea water is .455 psi/ft,Overburden is .65 psi/’ft, APL is 10 psi


23.A semi is in 650 ft of water (.445 psi/ft) drilling without a riser. Air gap is 60 ft and TD / TVD is 1350 ft RKB. What is the BHP during connections?


Air gap

Water depth Well depth

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24.What surface volume would 2 bbl of gas trapped in a sub sea BOP at 1900 ft water depth have if released and allowed to migrate through the riser filled with 12.9 ppg mud?


25.A semi is drilling top hole with a riser and diverter installed connected to 30” casing. Air gap is 70 ft, water depth is 1523 ft, sea water is .465 psi/ft, TVD / TD is 2250 ft RKB and MW is 9.7 ppg.What would be the reduction in BHP if the riser were lost or removed?

a) 30 psib) 65 psic) 95 psid) no reduction

26.hat increase in mud weight is required to offset this?


Air gap


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27.The recommended response time for sub sea BOP is:

Rams to close in less than: seconds

Annular should not exceed: seconds

Time to unlatch LMRP should not exceed: seconds

28.How can gas trapped in a subsea BOP be safely circulated out?

29.By how much would BHP change if a well was inadvertently opened before displacing riser to kill mud?MW=10.4 ppg KMW=10.9 ppg water depth=1342 ft


30.How many (.115bbl/st) strokes will it take to displace a 16” x 5” riser/drillpipe annulus (200 ft long)?

a) 290 strokesb) 390 strokesc) 490 strokesd) 190 strokes

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31.The following drawing shows components of a subsea hydraulic control system. Each component has a number. Place the number next to the component in the list provided.

WELL CONTROL

Using the schematic diagram of a hydraulic valve, answer the following question:

32.How many positions can the valve be placed in:

a. 2b. 3c. 4d. 8

33.How many active ports does the valve have?

a. 2b. 3c. 4d. 8

34.Can the valve be operated by:

a. manual function onlyb. remote function onlyc. air operated onlyd. manual or remote function

35.What is the name of this valve?

a. Terminatorb. Selectorc. Manipulator

36. In the center or block position, the valve vents fluid lines to tank.

a. Trueb. false

WELL CONTROL

WELL DATA:

Well depth: 10,657 ft TVD RKB 12,000 ft MD

Air gap: 60 ftWater depth: 2150 ftSea water gradient: .445 psi/ftMud weight: 13.3 ppg

37. What mud weight increase is required to balance the well if the riser is to be removed?


38.A BOP drill was conducted and the well shut in on the upper annular preventer. If the choke line is filled with sea water and the fail safe valves are opened, what would be the the casing pressure read?


39. if the riser is lost in bad weather, what would be the bottom hole pressure reduce by?


40. If the riser had a collapse pressure of 500 psi, how far could the mud level fall before seawater collapses the riser?

a. 1083 ftb. 1183 ftc. 1283 ftd. 1383 ft

Air gap


WELL CONTROL

41. If a function is made to close the hang off rams and your fluid counter continues to register fluid movement after the correct closing volume has gone passed, what would you consider doing? (1 answer)

a. Call the subsea engineer and let him sort it outb. Close another set of ramsc. Put the operating unit into block positiond. Everything is OK, continue

42.To find ICP, you must add the choke line friction to the slow circulating rate:

a. Trueb. False

43.The hydraulic fluid system used to operate the subsea BOP’s consist of potable water and additives.

a. Trueb. False

44.The rig has an air gap of 80 ft. If the riser has a collapse pressure of 450 psi, how far would the mud level fall before it collapse if you are working in 1600 ft of .445 psi/ft of sea water?


45.Using the following data, calculate the expanded gas volume that would be at surface if 2 barrels of gas had remained trapped under the rams and was released into the riser when the well was opened back up after a successful operation?

Well data:Choke line length: 1500 ftRiser length: 1480 ftKill mud weight: 12.5 ppgDrilling mud: 11.2 ppgAtmospheric pressure: 14.7 psi

a. 113 bblsb. 123 bblsc. 133 bblsd. 143 bbls

WELL CONTROL

46.Calculate the usable fluid in a 10 gallons bottle if the maximum pressure is 3000 psi, the mimimum is 1500 psi and the pre charge is 1000 psi?

a. 5.00 galsb. 3.34 galsc. 6.63 galsd. 1.73 gals

47. If accumulator bottles were taken to the seabed with the same precharge as surface bottles, what effect would this have on the usable fluid?

a. Increaseb. Decreasec. Same volume as surface volume

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EXERCISE # 10

1. When using the choke to adjust pressure it is the Casing (Annulus) gauge that reacts to the adjustment before the Drill Pipe Gauge.

a) Trueb) False

2. The choke is used to adjust Casing (Annulus) pressure, but to adjust the Drill Pipe pressure you have to change the pump rate.

a) True b) False

3. The Casing (Annulus) gauge is always slower to react to any choke adjustment then the Drill Pipe Pressure.

a) Trueb) False

4. The wait and weight method will always result in lower casing shoe pressures.

a) True b) False

5. The wait and weight will result in lower casing shoe pressure if the open hole volume is less than the drill pipe capacity.

a) Trueb) False

6. The Driller’s method of well control will result in higher casing shoe pressures if the open hole volume is less than the drill pipe capacity.

a) Trueb) False

7. The Driller’s method of well control will result in the same pressure on the casing shoe if the open hole volume is less than the drill pipe capacity.

a) Trueb) False

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8. Place the following statements in the correct order if you are using the Driller’s Method. The well is already shut in.

NOTE : There are 3 INCORRECT statements in the list.

a) Bring pump up to kill speed holding casing pressure constant.

b) Maintain casing pressure constant until kill mud is at the bit.

c) Maintain pumping pressure constant until influx is out.

d) Maintain drill pipe pressure constant until kill mud reaches surface.

e) Shut-in the well and check both SICP and SIDPP are approximately equal.

f) Bring pump up to kill speed holding casing pressure constant.

g) Line up suction to kill mud.

h) Maintain casing pressure constant until kill mud is pumped to surface.

i) Maintain casing pressure constant for complete circulation.

j) Bring pump up to kill speed holding drill pipe pressure constant.

k) Shut in well and check for zero shut in pressure.

Place your answers in order below :

1st __________ 2nd ____________

3rd __________ 4th ____________

5th __________ 6th ____________

7th __________ 8th ____________

WELL CONTROL

9. Place the following statements in the correct order if you are using the Wait and Weight to kill a well. The well is already shut in.

NOTE : There are 3 INCORRECT statements in the list.

a) Bring pump up to speed holding drill pipe pressure constant.

b) Allow drill pipe pressure to fall from ICP to FCP as kill mud is pumped to bit.

c) Bring pump up to speed holding casing pressure constant

d) Maintain drill pipe pressure constant as kill mud pumped from bit to surface.

e) Allow drill pipe pressure to fall gradually from ICP TO FCP as kill mud is pumped from suction pit to shaker.

f) Shut down and check the well is dead.

1rst ________

2nd _________

3rd _________

4th _________

10.Which of the following statements are True or False concerning the Wait and Weight method?

a. In the Wait and Weight method the casing pressure should be kept constant during 2nd

circulation.

a) Trueb) False

b. In the Wait and Weight method , annulus pressures are kept lower than with the Driller’s method.

a) Trueb) False

c. In the Wait and Weight method there are less calculations compared to the Driller’s method.

a) Trueb) False

WELL CONTROL

d. Only the Wait and Weight method the drill pipe pressure is held constant throughout.

a) Trueb) False

e. In the Wait and Weight method the drill pipe pressure is held constant throughout.

a) Trueb) False

f. In the Wait and Weight method the well is dead when you reach FCP.

a) Trueb) False

g. In the Wait and Weight method the drill pipe pressure should read zero, after surface to bit strokes have been pumped if you shut in the well.

a) True b) False

h. The wait and weight method must be used if insufficient barite is on board.a) Trueb) False

i. The Wait and Weight method does not require you draw a graph or step down chart.

a) Trueb) False

j. The Wait and Weight is the preferred method if MAASP is critical and the open hole capacity is greater the drill string capacity.

a) Trueb) False

WELL CONTROL

11.Based on the following information :

a. Will the Wait and Weight method give lower shoe pressures than the Driller’s method?

TVD = 10,000 ftShoe Depth = 8,830 ftSurface to Bit Strokes = 1,629 stksBit to Shoe strokes = 1,304 stksBit to surface = 6,480 stksSIDPP = 500 psiSICP = 800 psiPresent Mud Wt. = 10.3 ppgKill Mud Wt. = 11.3 ppgMAASP = 1,300 psiPit Gain = 30 bbls

Answer – Yes or No

b. Based upon same information above :

Will the Wait and Weight Method give lower surface pressures than the Driller’s Method?

Answer – Yes or No

12.Company policy states “when killing a well you will always attempt to kill the well using a method that minimizes the pressure on the stack and upper casing”.

Which method would you choose?

DRILLERS OR WAIT AND WEIGHT

13.Link the following by matching up the correct number to the correct letter.

1. One circulation lower annulus pressures.2. Less calculations highest annulus pressures.3. Most calculations moderate annulus pressures.

A. Driller MethodB. Concurrent MethodC. Wait and Weight method

WELL CONTROL

14.Which of the following statements are true ?

a. Surface line volume will affect the point at which kill mud will increase mud hydrostatic on bottom.

b. Pump must be brought up to speed holding casing pressure constant

c. Surface line volume does not need to be considered when starting to kill a well

d. Maintain the drill pipe pressure constant when starting up the pump to kill speed.

TRUE STATEMENTS ARE____________________and ___________________________

15.Select one of the following statements that is TRUE concerning wellbore pressures when circulating a gas influx to surface. (Drillers Method)

a. So long as the correct kill procedures are followed that part of the wellbore which is above a gas influx will have a constant pressure.

b. So long as the correct kill procedures are followed that part of the wellbore which is below a gas influx will have a constant pressure.

c. So long as the correct kill procedures are followed that part of the wellbore which is below a gas influx will have an increasing pressure.

16.From the statements A to F below, place 3 of them correctly in the blanks provided :

A - Drillers

B - Bring pump up to speed holding drill pipe pressure constant

C - Constant bottom hole pressure

D - Concurrent

E - Bring the pump up to speed holding the casing pressure constant

F - Drill pipe pressure constant

The main principle of well killing methods is to maintain _____________________

The most common methods are the Wait and Weight and ____________________ method

In both methods you must ______________________ when starting up.

WELL CONTROL

17.Which one of the following statements is true concerning wellbore pressure during the 1st

circulation of the Driller’s method?

a. Pressure at any point above a gas influx is constant.

b. Pressure at any point above a gas influx is decreasing.

c. Pressure at any point above a gas influx is rising.

d. Pressure at any point below a gas influx is decreasing.

e. Pressure within a gas bubble remains constant.

18.A gas is being circulated up the hole during a kill operation what effect will this have on the pressures at the various locations listed.

EFFECT IN PRESSURE

LOCATIONS Increase Decrease Stays the same

Increase at firstThen remains

constant

Gas BubbleSurface CasingGauge

Casing shoe

Bottom HoleAt any point below gas bubbleAt any point above Gas bubble

WELL CONTROL

19.While killing the well on the 1st Circulation of the Driller’s method, the drill pipe pressure is 1,200 psi at 30 spm. Casing pressure is 1,000 psi. Very quickly the drill pressure increases to 1,500 psi but no change in casing pressures. Pump rate still holds at 30.

You decide to open the choke to bring the drill pipe pressure back to 1,200 psi with 30 spm.

What has happened to bottom hole pressure ?

a. Increaseb. Decreasec. Stay in the same.

20. In the previous example you decided to stop the pump and close the choke before making a decision. You think that the nozzles may be blocking. What would you do?

a. Start pump up to 30 spm and manipulate choke to get 1,200 psi on drill pipe.b. Start pump up to 30 spm holding the choke pressure constant. Once pump is up to

speed note the drill pipe pressure and hold that constant for rest of 1st circulation.c. Increase mud weight by an amount equal to 300 psi.d. By using the spm versus pump pressure equation the spm for 1,500 psi would be 34

spm. Therefore you bring pump up to 34 spm and adjust choke to obtain 1,500 psi drill pipe pressure.

21.During the second circulation of the Driller’s method you hold drill pipe pressure constant until kill mud is at the bit. What would happen to bottom hole pressure ?

a. Increaseb. Decreasec. Stay the same

22.During the first circulation of the Driller’s method you decided to hold casing pressure constant. What would happen to bottom hole pressure ?


23.During the second circulation of the Driller’s method you decide to hold casing pressure constant until kill mud is at the bit. What would happen to bottom hole pressure ?


WELL CONTROL

24.Below is a list of problems. Match the cause to the problem.

PROBLEM CAUSE

a. Both gauges falling 1. Choke pluggingb. Both gauges rising 2. Bit pluggingc. D.P. gauges rising 3. Choke washoutd. D.P. gauge falling 4. Nozzle / pipe washout

a. matches _____________________________

b. matches _____________________________

c. matches _____________________________

d. matches _____________________________

25. Which of the following pressures do not increase with gas migration ?

a. Bottom hole pressureb. Casing shoe pressurec. Shut in casing pressured. Gas bubble pressure

WELL CONTROL

25.The following graphical diagrams show the approximate changes in pressure at certain points in the well during the Wait and Weight method.

a. Surface casing pressureb. Casing shoe pressurec. Bottom hole pressured. Drill pipe pressure

NOTE / Pressure reading are not drawn to scale.

Answer:

Answer:

Answer:

WELL CONTROL

Answer;

WELL CONTROL

EXERCISE # 11

Well Data:

Measured depth: 15,500 ftTVD: 15,000 ftHole size: 8 ½ “Air gap: 70 ftWater depth: 1,000 ftDrill collars 6 ½: 1,000 ft

Capacities:

Drill pipe capacity: 0.01776 bbl/ftDrill pipe metal displacement: 0.00650 bbl/ftDrill pipe closed end displacement: 0.02426 bbl/ftHWDP (1000 ft) 0.0088 bbl/ftDrill collar capacity: 0.00768 bbl/ftChoke line (1100 ft): 0.006 bbl/ftMarine riser: 0.39 bbl/ft

Annular capacities:

Open hole / drill collar: 0.0292 bbl/ftOpen hole / drill pipe: 0.0459 bbl/ftCasing / drill pipe: 0.0505 bbl/ft

Pre-recorded data:

Current mud weight: 16.0 ppgCasing 9 5/8 – 47 ppf set at (MD/TVD): 9,000 ftFracture gradient at shoe: 0.91 psi/ftSCR @ 40 SPM ( riser) 500 psiSCR @ 40 SPM ( choke line) 750 psiPump output: 0.119 bbl/stkSurface lines: 17 bbls

Kick data:

SIDPP: 100 psiSICP: 350 psiPit gain: 10 bbls

WELL CONTROL

1. What is the MAASP?


2. What is the MAMW?


3. How many strokes does it take to pump from surface to bit?

a. 1954 strokesb. 2054 strokesc. 2154 strokesd. 2254 strokes

4. How many strokes does it take to pump from bit to shoe?


5. How many strokes does it take to complete one circulation through the choke line?


6. How many strokes are required to displace the riser?

a. 4382 strokesb. 6523 strokesc. 1363 strokesd. 3.506strokes

7. What kill mud weight is required?


WELL CONTROL

8. What is the ICP?


9. What is the FCP?


10.What is the MAASP after killing the well?


11.What is the initial dynamic pressure?


12.What informations are essential to calculate the fracture pressure of a leak off test?

a. The capacity of the drill stringb. The TVD of the casing shoec. The presence of a float in the stringd. The pore pressure of the formation being testede. The mud densityf. The TVD of the wellg. The Annular pressure lossesh. The MD of the casingi. The accurate hole capacity

WELL CONTROL

EXERCISE # 14


WELL DATA


Kick Off Point 4,000 TVD / 4,000 MDEnd Of Build 5,500 TVD / 7,000 MDBit size 8.5”Drill Pipe 5” OD. 19.5 lbs/ft Capacity = 0.01776 bbls/ftHeviwate 5” OD x 3” ID x 1500 ft


100% Internal yield = 10,900 psi Set at 5,050 ft TVD / 5,500 MDChoke Line 1,000 ft – Capacity: .008 bbls/ftRiser 1,000 ft – Riser / DP: .335 bbls/ftFormation strength test 1,800 psi w/ 11.5 ppgMud weight in use 12.5 ppg.Surface Volume 1,000 bblsPumps National triplex 12-P-160 With 51/2” Liners


PUMP PRESSURE

Slow Pump Rate Riser 700 psi at 40 spm CLFL 250 psi at 40 spm

ANNULAR VOLUMES


WELL CONTROL DATA



WELL CONTROL

1. What is the Initial Circulating Pressure at 40 spm?


3. What Kill Mud weight is required?

4. What is the Maximum allowable fluid density?

5. What is the MAASP with the current mud weight?

6. How many strokes are required to pump kill mud from surface to KOP?

7. What is the pressure reduction per 100 strokes surface to KOP?

8. How many strokes are required to pump kill mud from KOP to EOB?

WELL CONTROL

9. What is the pressure reduction per 100 strokes KOP to EOB?

10.How many strokes are required to pump kill mud from EOB to bit?

11.What is the pressure reduction per 100 strokes EOB to bit?

12.When kill mud reaches the KOP, what is the circulating pressure?

13.When kill mud reaches the EOB, what is the circulating pressure?

14. If the well had to be shut in when kill mud reaches the KOP, what would be the SIDPP?

15.What is the drill string volume?

16.What is the total strokes to pump kill kud to the bit?

WELL CONTROL

17.What is the marine riser – DP capacity?

18.Approximately, how many strokes are required to fill the choke line?

19.What should be the approximate pressure on the casing gauges when the pump reaches 40 SPM?

20.What is the MAASP with the current mud weight (dynamic conditions)?

WELL CONTROL

EXERCISE # 15


WELL DATA

Well Depth 10,000 ft TVD14 ,000 ft MD

Kick Off Point 3,500 TVD / 3,500 MDEnd Of Build 4,000 TVD / 4,500 MDBit size 8.5”Drill Pipe 5” OD. 19.5 lbs/ft Capacity = 0.01776 bbls/ftDrill Collars 61/2” x 213/16” x 500 ft Capacity = 0.007 bbls/ftCasing 95/8”, 47 lb/ft. P110 8.681” ID

100% Internal yield = 10,900 psi Set at 6,000 ft TVD / 7,000 MDChoke Line 580 ft – Capacity: .008 bbls/ftRiser 580 ft – Riser / DP: .335 bbls/ftFormation strength test 1,500 psi w/ 9.8 ppgMud weight in use 10 ppg.Surface Volume 274 bblsPumps National triplex 12-P-160 With 6” Liners


PUMP PRESSURE

Slow Pump Rate Riser 520 psi at 40 spm CLFL 100 psi at 40 spm

ANNULAR VOLUMES


WELL CONTROL DATA



WELL CONTROL

1. What is the Initial Circulating Pressure at 40 spm?


3. What Kill Mud weight is required?

4. What is the Maximum allowable fluid density?

5. What is the MAASP with the current mud weight?

6. How many strokes are required to pump kill mud from surface to KOP?

7. What is the pressure reduction per 100 strokes surface to KOP?

8. How many strokes are required to pump kill mud from KOP to EOB?

WELL CONTROL

9. What is the pressure reduction per 100 strokes KOP to EOB?

10.How many strokes are required to pump kill mud from EOB to bit?

11.What is the pressure reduction per 100 strokes EOB to bit?

12.When kill mud reaches the KOP, what is the circulating pressure?

13.When kill mud reaches the EOB, what is the circulating pressure?

14. If the well had to be shut in when kill mud reaches the KOP, what would be the SIDPP?

15.What is the drill string volume?

16.What is the total strokes to pump kill kud to the bit?

17.What is the marine riser – DP capacity?

WELL CONTROL

18.Approximately, how many strokes are required to fill the choke line?

19.What should be the approximate pressure on the casing gauges when the pump reaches 40 SPM?

20.What is the MAASP with the current mud weight (dynamic conditions)?

3 - well control exercises

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