assistant driller ojt module

Assistant Driller OJT Module

Program Guide Sheet

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Page: 1.1Rev. 02: January 2005

INTRODUCTIONThe OJT training system is designed to help you do your job more safely and effectively and to progress in your careerwith Transocean. It is a rig-based system and focuses on the specific tasks of each job. The OJT system allows you toprogress at your own pace, with the help of your supervisor. Don’t hesitate to ask if there’s anything you don’t understand.

PREREQUISITEBefore you start this module, you must complete the HSE OJT Module.

OBJECTIVESUpon completion of this module, you should be able to:

1. demonstrate a clear understanding of the role and responsibilities of an assistant driller, and2. perform basic assistant driller tasks safely and competently.

TRAINING MATERIALThe Assistant Driller OJT Module includes:

1. a mandatory task list, which is a list of jobs you must be able to perform;2. a tool list, which is a list of supporting reference DVDs, CD-ROMs, and books in the training room of your rig;

and3. review questions.

TRAINING PROCEDUREYou can expect to complete this module in about thirteen working weeks, depending on the effort put into it. Please try tocomplete the module in the scheduled time.

The Assistant Driller OJT Module task list is the measure of progress in your training. As you prove competence, yoursupervisor will sign off each specific task. Completion of the task list is mandatory.

When you finish the requirements on the task list to your supervisor’s satisfaction, you will have to successfully completea final test. The final test is intended to verify your knowledge of topics in the module.

On successful completion of the task list and final test, your supervisor will fill out a Completion Notification Form (CNF).The CNF will be forwarded to the regional training center for module certificate processing. The completed task list is tobe kept on file at the location of your work assignment.

The DVDs, CD-ROMs, reference books, and workbook questions are provided to support the task list topics. This self-study content is not mandatory; however training participants may find it helpful when learning the tasks.

Program Guide Sheet

Competence / Task List

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Supv.Initials Supervisor CommentsDateTask # Task

General Topics

Describe how the OJT system works and the supervisor’s role init. Required reference: eOJT Assessor’s Guide

Explain the energy isolation system as it applies to theassistant driller.

Explain the role of the assistant driller during such emergenciesas H2S, hydrocarbon discharge, fire, man overboard, andabandon rig.Show how to conduct a THINK drill at the site where the taskwill be performed.

Explain the zone classification system on your rig.

Show how to communicate and work with other departments andthird party personnel.

Assist the driller in filling out the IADC drilling report.

Explain the assistant driller’s role in managing crew’s productivityand drill floor housekeeping.

Explain and show how to align the standpipe manifold and thechoke manifold for testing, cementing, drilling, and reversecirculating.Show how to manitain the fastline guide system on the drillingline.

General Rig Floor Topics

Show how to inspect and change drawworks turnback rollers.

Working With The Drill String

Show how to adjust the drawworks brake band equalizing bar orcalibrate disc brake.

Show how to adjust and reset the crown block saver (Crown-O-Matic) or how to adjust and reset floorsavers, if applicable.

Show how to visually inspect drilling line.

Explain and show how to calculate drilling line ton miles (tonneKilometres) while drilling and/or tripping and how to use thisinformation.

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Working With The Drill String (cont.)

Explain and demonstrate a wear bushing retrieval operation.

Explain drilling line slip and cut procedures.

Explain how to identify washouts in drill string components.

Show how to prepare BHA sheets and pipe tally.

Explain and show how to prepare and fill out a trip sheet.

Show how to check for bit wear and assist with dull bit gradingfor fixed cutter and roller cone bits.

Show how to install, redress, and remove a bit sub float valve.

Show how to install and remove jets in typical bits.

Show how to supervise a BHA handling operation on the drillfloor.

Identify and explain the use of typical fishing tools used on yourrig.

Explain and demonstrate how to dress an overshot.

Show how to calculate drill string capacity, annular capacity, bitdepth at any given time, and the number of stands from surfaceto shoe, surface to bottom, and bottom to shoe.

Show how to use a gauge ring for typical bits and stabilizersused on your rig.

Show how to identify and measure typical downhole tools andtublars (including collars, stabilizers, jars, subs, crossovers, anddrill bits).

Explain and show how to organize the drill floor for a casing job.

Running and Cementing Casing

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Show how to compound tong lines for making up or breaking outtubulars requiring high torque.




Show how to make up a casing shoe track.

Explain why and how to test the shoe and float collar whilerunning casing.

Show how to change power tong heads and tong dies.

Explain how to dress and install a cementing head, secure highpressure Chiksan lines or hose, and perform a pressure test.

Show how to perform daily checks on well control equipmentsuch as IBOP and crossover(s), choke manifold, andaccumulator unit.Explain Transocean shut-in procedures while drilling.

Explain Transocean shut-in procedures while tripping.

Explain the diverter control system and diverter procedures.

Explain and show how to change and service the BOP rams.

Explain how to change the annular BOP packing element.

Show how to do a complete BOP and choke manifold low-andhigh-pressure test.

Explain and show how to run and retrieve (or nipple up and nippledown) the BOP stack on your rig.

Well Control and Related Equipment

Show how to do a complete IBOP, standpipe manifold, top driveand pump room manifold low and high pressure test.

Show how to calculate the space out.

Working With The Drill String (cont.)

Explain accumulator system operation including nitrogenprecharge system and calculation of useable fluid, and assistwith routine maintenance.

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46. Show how to prepare a typical kill sheet and explain it’ssignificance.

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Equipment Maintenance

Visually inspect and identify typical problems associated withdrawworks.

Explain how to change out the swivel washpipe and show how toredress the spare.

Explain and assist in maintaining or repairing a choke manifoldgate valve.

Explain maintaining or repairing of a manual and a remoteoperated choke.

Show how to service and repair the hydraulic pressure load cellon the standpipe.

Explain and show how to visually inspect the deadline anchorand the load cell.

Explain and show how to replace cathead lines or E-Z torquelines and explain safety precautions, where applicable.

Visually inspect and identify typical problems associated with auto-mated pipe handling equipment such as pipe racker, Iron Rough-neck, conveyor, hydraulic/pneumatic finger board, and pipe spinner.

Show how to maintain and repair a standpipe gate valve.

Visually inspect and identify typical problems with the crown blockand traveling block assemblies including block retract systemswhere applicable.

Visually inspect and identify typical problems with mud treatmentequipment.

Visually inspect and identify typical problems with the top driveor kelly assembly.

Visually inspect and identify typical problems with mud pumpsand show how to replace expendable parts.

Explain and show how to inspect and repair drill string fullopening and non-return valves.

Show how to prepare the drill floor for a typical well testing orcompletion job.

Show how to change the mud pump’s pulsation dampenerbladder and explain the use of the oxygen tester, whereapplicable.

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Describe the assistant driller’s role in the PreventativeMaintenance System.

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Operations on Floating Rigs

Explain the function and show how to use drillinginstrumentation at the driller’s console on your rig.

Explain running and retrieving procedures for a hang off assemblyor RTTS.

Explain and show how to supervise the moon pool area when theBOP stack and riser system are being run or retrieved.

Assist in routine maintenance on the riser and guidelinetensioner systems or hydraulic riser tensioner cylinders andexplain how they work.Visually inspect and identify typical problems of the drill stringmotion compensator.

Explain and show how to supervise moon pool area operationswhen preparing and running a permanent and/or temporary guidebase, including monitoring of subsea TV cameras or ROV.Explain the maximum operating weather limits for drilling,tripping, logging, and other critical operations.

Explain and show how to supervise the drill floor for running orretrieving the riser system.

Operate the driller’s drawworks controls during routine drilling fora limited period and under close supervision.

Operate the driller’s drawworks controls during a routine trip in acased hole section for a limited period and under closesupervision.

Operate the driller’s drawworks control while running casinginside cased hole, under close supervision and for a limitedperiod.

Rig Operations

Show how to space out and shut in the well during a kick drill.

Top Drive Operations

Explain and show the general arrangement of the top drivepipehandler.

Explain which top drive system configuration is on this specificdrilling unit.

Explain the over all functioning of top drive system and systemloadpath during drilling.

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Top Drive Operations (cont.)

Describe the maximum RPM at maximum continuous torquerating on this specfic top drive.

Identify the model of pipe handler fitted to this specific top drive,and the maximum breakout capacity in Ft/Lbs.

Explain and show the operational sequence of pipe handlertorque wrench in drilling mode.

Describe the maximum continuous torque in Ft/Lbs on the rigspecific top drive.

Explain and show the operational sequence of pipe handlertorque wrench when changing out saver sub and / or IBOP valve.

Demonstrate the operation of the linktilt mechanism.

Demonstrate making a single connection with the top drive on atleast 5 occasions, where applicable.

Demonstrate making and breaking a stand connection with thetop drive using the pipe handler on at least 5 occasions.

Explain the counterbalance system on the top drive.

Demonstrate the actuation of the IBOP valves.

Explain and show the rotating head system on the top drive.

Explain and show the motor cooling system on this specific topdrive.

Explain and show the sequence of actions in the event of stringstall during drilling or reaming.

Explain and demonstrate the loadpath components inspection.

Explain and show the top drive alignment cylinder and shippingbracket.

Explain potential dropped objects and secondary retentionsystem.

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Complete the final computer-generated test.(All tasks must be completed before this test is taken)

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Final Test




Additional Rig Specific Tasks

Tool List

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Module Specific Reference Library


Type Title


1.34030 Book Dictionary for the Petroleum Industry1.60030 Book Applied Mathematics for the Petroleum and Other Industries2.01210 Book Drilling Technology Series - Segment II: Drilling Operations2.30230 Book Open Hole Fishing2.30410 Book Marine Riser Systems and Subsea Blowout Preventers2.80040 Book Practical Well Control9.11000 Book Drilling Line Care and Maintenance

10.10010 Book IADC Drilling Manual20.02270 DVD #2 Drilling Line Care and Maintenance, Part 1: Inspection and Cutoff20.02280 DVD #2 Drilling Line Care and Maintenance, Part 2: Equipment and String-up20.02290 DVD #2 Drilling Line Care and Maintenance, Part 3: Cutoff Programs20.02300 DVD #2 Drilling Line Care and Maintenance, Part 4: Calculating Ton Miles20.04070 DVD #4 Installation and Operation of Diverter Systems61.10010 CD-ROM Inside BOP's, Kelly Cocks and Safety Valves61.10030 CD-ROM Annular Type BOP61.10050 CD-ROM Care and Maintenance of Marine Riser61.10110 CD-ROM Accumulator System Overview61.10130 CD-ROM Ram Type BOP

61.10140 CD-ROM Transocean eDocs- eOJT Assessor's Guide- HQS-HSE-PP-01: HSE Manual- HQS-OPS-HB-01: Well Control Handbook

61.10160 CD-ROM Introduction to Well Control61.20130 CD-ROM U-type BOP Rams and Packers - Cameron61.40010 CD-ROM Hycalog Product Reference61.50010 CD-ROM Reed Electronic Reference Guide

61.60010 CD-ROM Subsea Equipment Overview - Hydril

Workbook Questions

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10 ft

24 ft

7.5 ft10 ft

1. What is the capacity of a 121/4-inch hole in barrels per foot?A. 0.1222 bbl/ftB. 0.1326 bbl/ftC. 0.1457 bbl/ftD. 0.1547 bbl/ft

2. What is the annular capacity of a 171/2 inch hole with 5-inch drill pipe inside?A. 0.2732 bbl/ftB. 0.1968 bbl/ftC. 0.1743 bbl/ftD. 0.0895 bbl/ft

3. What is the volume in barrels of a rectangular mud tank with the following dimensions?Width = 61/2 ft, Length = 181/4 ft, Height = 10 ftA. 211 bblB. 316 bblC. 663 bblD. 1,048 bbl

4. What is the volume of a rectangular mud tank with the following dimensions?Width = 3.5 m, Length = 7.8 m, Height = 4.3 mA. 117 m3

B. 738 bblC. both A and BD. none of the above

5. What volume in barrels can the tank hold before fluid passes through the overflow pipe?A. 320 bblB. 230 bblC. 110 bblD. none of the above

12.25 in.

10 ft

6.5 ft

18.25 ft

5 in. 17.5 in.

4.3 m

3.5 m

7.8 m

Applied Mathematics - Workbook Questions



6. What is the area of an oval tank cover in square feet, with the following dimensions?Minor Axis = 4 ft, Major axis = 81/2 ftA. 106.8 ft2

B. 75.4 ft2

C. 49.3 ft2

D. 26.7 ft2

7. Using the dimensions in question number 6, calculate the volume in barrels, of an oval tank 271/2 feet high?A. 254 bblB. 162 bblC. 131 bblD. 85 bbl

8. What is the volume increase in barrels when raising the mud weight from 9.4 ppg to 10.6 ppg in a 1,400 barrelsystem?A. 256 bblB. 71 bblC. 110 bblD. 76 bbl

9. How much water needs to be added to reduce the mud weight from 10.8 ppg to 9.5 ppg in an 1,800-barrel mudsystem?A. 2,000 bblB. 1,500 bblC. 1,000 bblD. 500 bbl

8.5 ft

4 ft




Use the diagram information to answer questions 10 through 14.

10. What is the hydrostatic pressure at TD?A. 2,261 psiB. 2,661 psiC. 2,785 psiD. 5,357 psi

11. What is the string capacity in barrels?A. 161 bblsB. 121 bblsC. 101 bblsD. 81 bbls

12. What is the annular volume in litres?A. 11,789 litresB. 98,864 litresC. 102,030 litresD. 198,468 litres

13. What is the annular volume in barrels with no string?A. 780 bblsB. 745 bblsC. 130 bblsD. 957 bbls

14. What is the height of the influx with a 20-barrel pit gain?A. 392 ftB. 239 ftC. 223 ftD. 199 ft

5118 ft5 in. drill pipeID 4 in.

239 ft8 in. drill collarID 2!/2 in.

12!/4 in. hole with 10 ppg mud


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1. 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.

2. 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.

3. At the start of a trip out of the hole for a bit change, the first 20 x 93 foot stands of pipe are pulled from the holewet with no fill up. Using the following data, calculate the reduction in bottomhole pressure.

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

A. 48 psiB. 483 psiC. 600 psiD. 683 psi

4. At the start of a trip out of the hole for a bit change, the first 10 x 93 foot stands of pipe are pulled from the holedry with no fill up. Using the following data, calculate the reduction in bottomhole pressure.

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

A. 650 psiB. 6 psiC. 65 psiD. 130 psi

5. Select the two things that are needed to accurately determine 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

6. Select the three things that are needed to accurately determine final circulating pressure.A. Drilling pump pressure, drilling mud weight, and kill mud weightB. Shut-in drill pipe pressure, drilling mud weight, and kill mud weightC. Slow circulating rate pressure, drilling mud weight, and kill mud weightD. Slow circulating rate pressure, drilling mud weight, and final circulating pressure

7. The driller's method of well control normally requires how many circulations to kill a well?A. One circulationB. Two circulationsC. Three circulationsD. Four circulations

Practical Well Control - Workbook Questions



8. The driller's method of well control will normally result in ______A. a higher bottomhole pressure than the wait-and-weight method.B. a lower bottomhole 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.

9. During a well-killing operation, a common way to bring the pump up to kill rate without changing bottomholepressure is to ______A. keep SIDPP constant at the original shut-in value by opening the choke.B. keep SIDPP 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.D. ensure that casing pressure and standpipe pressure rise consistently together.

10. The usable accumulator fluid for a 10 gallon accumulator bottle on a 3,000 psi system with 1,000 psi prechargeis approximately ______A. 9 gallons.B. 7 gallons.C. 5 gallons.D. 3 gallons.

Practical Well Control - Workbook Questions



WELL DATAWell Depth 10,000 ft TVD

11,500 ft MD

Bit size 8.5 in.

Drill Pipe 5 in. OD. 19.5 lbs/ftCapacity = 0.01776 bbls/ft

Drill Collars 61/2 in. x 213/16 in. x 750 ftCapacity = 0.00768 bbls/ft

Casing 95/8 in., 47 lb/ft. P110 8.681 in. ID100% Internal yield = 10,900 psiSet at 7,000 ft TVD

Mud weight in use 12 ppg

Pumps National triplex 12-P-160With 61/2 in. LinersCapacity = 0.117 bbls/stk

PUMP PRESSUREWhile Drilling 2,500 psi at 80 spm (APL = 260 psi)

Slow Pump Rate 250 psi at 30 spm (APL = 75 psi)

ANNULAR VOLUMESDrill pipe - Casing = 0.0505 bbls/ftDrill pipe - Open hole = 0.0459 bbls/ftDrill collars - Open hole = 0.0292 bbls/ft

WELL CONTROL DATASIDPP = 520 psiSICP = 720 psiGAIN = 12 bblsFRACTURE GRADIENT AT SHOE = .91psi/ft

Kick Data and Gauges - Workbook Questions



1. What is the total capacity of the drill string?A. 150 bblsB. 160 bblsC. 197 bblsD. 180 bbls

2. Calculate the total annular capacity with the pipe on bottom.A. 482.2 bblsB. 457.5 bblsC. 547.5 bblsD. 627.6 bbls

3. What is the surface to bit time with the pump running at 80 spm?A. 21 minsB. 25 minsC. 32 minsD. 39 mins

4. Calculate bit to surface time (bottoms up) at 80 spm.A. 58.5 minsB. 49.7 minsC. 60.3 minsD. 51.5 mins

5. What kill mud is required to balance formation pressure?A. 13.4 ppgB. 13.0 ppgC. 12.4 ppgD. 16.4 ppg

6. The ICP (initial circulating pressure) at 30 spm will be approximately ______A. 270 psi.B. 770 psi.C. 990 psi.D. 1,200 psi.

7. The FCP (final circulating pressure) at 30 spm will be ______A. approximately 800 psi.B. approximately 390 psi.C. approximately 500 psi.D. approximately 270 psi.

8. After reaching FCP it is decided to increase the pump speed to 40 spm. What would happen to BHP if the drillpipe pressure is held constant at the original FCP value?A. Increase by about 210 psiB. Decrease by about 210 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?A. 5,800 psiB. 6,800 psiC. 7,800 psiD. 6,240 psi




10. What is the ECD on bottom while drilling?A. 15.0 ppgB. 12.5 ppgC. 12.0 ppgD. 13.5 ppg

11. At 80 spm what is the annular velocity around the drill collars?A. 412 ft/minB. 210 ft/minC. 506 ft/minD. 321 ft/min

12. What is the maximum allowable mud weight?A. 17.5 ppgB. 16.5 ppgC. 18.0 ppgD. 19.0 ppg

13. What is the approximate length of the influx?A. 1,027 ftB. 850 ftC. 653 ftD. 410 ft

14. The gradient of the influx is about ______A. .137 psi/ft.B. .320 psi/ft.C. .465 psi/ft.D. .433 psi/ft.

15. How many strokes to go from ICP to FCP?A. 1,282 strokesB. 1,368 strokesC. 1,680 strokesD. 1,538 strokes

16. How many strokes will it require to go from bit to shoe?A. 5,364 strokesB. 4,122 strokesC. 1,658 strokesD. 874 strokes

17. How long will it take to go from bit to shoe at a pump speed of 30 spm?A. About 214 minsB. About 29 minsC. About 157 minsD. About 55 mins

18. At 30 spm what is shoe to surface travel time?A. About 101 minsB. About 34 minsC. About 214 minsD. About 76 mins




19. If the casing shoe is tested with 12 ppg mud in the hole, how much pressure is applied at the surface to give afracture gradient of .91 psi/ft?A. 1,250 psiB. 1,500 psiC. 2,000 psiD. 1,950 psi

20. What would be the new MAASP once the well has been killed?A. 685 psiB. 1,638 psiC. 700 psiD. 585 psi

21. At 30 spm how long will it take to pump kill mud to the bit?A. 157 minsB. 214 minsC. 56 minsD. 76 mins

22. If a 100 psi safety margin is included in the kill mud weight, what would the new kill weight be?A. 15.5 ppgB. 16.0 ppgC. 15.4 ppgD. 13.2 ppg

23. What would be the approximate pressure step down from ICP to FCP in psi/100 strokes?A. 30 psi/100 stksB. 46 psi/100 stksC. 50 psi/100 stksD. 66 psi/100 stks

24. The kill operation has started. What should you do?A. Open the choke a little.B. Close the choke a little.C. Increase the pump speed.D. Decrease the pump speed.E. Nothing, everything looks okay.


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400 1600500 1500

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900 11001000

PSI

PUMP SPEED

TOTAL STROKES

DRILLPIPE PRESSURE CASING PRESSURE

OPEN CLOSECHOKEPOSITION

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400 1600500 1500

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700 1300800 1200

900 11001000

PSI

770 72030

60



25. The operation has been going for 10 minutes. What should you do?A. Open the choke a little.B. Close the choke a little.C. Increase the pump speed.D. Decrease the pump speed.E. Nothing, everything looks okay.

26. The pit levels are reported to be increasing slightly. What are you going to do now?A. Open the choke a little.B. Close the choke a little.C. Increase the pump speed.D. Decrease the pump speed.E. Nothing, everything looks okay.

27. Casing pressure is still slowly increasing. What are you going to do now?A. Open the choke a little.B. Close the choke a little.C. Increase the pump speed.D. Decrease the pump speed.E. Nothing, everything looks okay.


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PSI

PUMP SPEED

TOTAL STROKES



0 19001001800200

300 1700

400 1600500 1500

600 1400

700 1300800 1200

900 11001000

PSI

770 75030

300

0 19001001800200

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900 11001000

PSI

PUMP SPEED

TOTAL STROKES



0 19001001800200

300 1700

400 1600500 1500

600 1400

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PSI

750 85030

1000

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PSI

PUMP SPEED

TOTAL STROKES



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PSI

770 95030

3000



28. The casing pressure has been reducing for the last few hundred strokes. How are things going?A. Open the choke a little.B. Close the choke a little.C. Increase the pump speed.D. Decrease the pump speed.E. Good, everything looks okay.


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400 1600500 1500

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900 11001000

PSI

PUMP SPEED

TOTAL STROKES



0 19001001800200

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PSI

770 52030

4750



Part I1. Sharp corners, bad drum winding, loops in the line, or operating over small diameter sheaves will cause what

type of damage?A. Crossover wearB. Drum crushC. DoglegsD. Tension breaks

2. How does drum crush occur?A. Extreme pressure is brought down on the wire by an additional wrap on the drawworks.B. The line passes over sharp corners or small diameter sheaves.C. It occurs at the crossover points as the line hits the turnback roller and starts a new layer.D. The line is overloaded.

3. Where does crossover wear occur?A. At the deadman anchorB. At the top of the crown block sheavesC. At the bottom of the travelling block sheavesD. At the new layer position on the drawworks

4. What is a ton-mile?A. The weight of the drill string multiplied by the depth of the holeB. The work needed to move one ton over a one-mile distanceC. The maximum drawworks capacityD. The depth of the hole divided by the weight of the string

5. What always takes precedence over ton-miles when it comes to drilling line replacement?A. Visual inspectionB. Depth of trip to be performedC. Weight of assembly to be trippedD. How long until the end of the shift

6. What does 6 x 19 IWRC mean?A. The number of wires allowed to be damaged over a given lengthB. 6 strands, at 19 wires per strand, wrapped around an independent wire rope coreC. 19 strands, at 6 wires per strand, wrapped around an independent wire rope coreD. 19 strands of size 6 wire, wrapped around an independent wire rope core

7. Why do we cut the line rather than spooling more and more onto the drawworks?A. To prevent spooling problemsB. To avoid damage to the line of other wrapsC. To avoid accumulating too much line on the drawworksD. all of the above

8. If we keep ton-mile records why do we inspect the drilling line?A. To check for damage caused by jarring, fishing, or other operation.B. To ensure the slip-and-cutoff program is adequate.C. both A and BD. none of the above

9. Maintenance of what equipment has a direct bearing on the condition of a drilling line?A. Crown block, travelling block, drawworks, Crown-O-Matic, deadline stabilizer, deadline anchor, wireline

turnbacksB. Crown block, travelling block, drawworks, Crown-O-Matic, deadline stabilizer, wireline turnbacksC. Crown block, travelling block, drawworks, deadline anchor, wireline turnbacksD. Crown block, travelling block, Crown-O-Matic, deadline stabilizer, deadline anchor

Drilling Line Care and Maintenance - Workbook Questions



10. How should wireline clips be attached to a line?A. With the U-bolts over the dead end of the lineB. With the U-bolts over the live end of the lineC. With the base of the clip against the dead end of the lineD. both B and C

Part II11. What needs to be reset after string-up or cutoff?

A. The driller’s brakeB. The drawworks auxiliary brakeC. The Crown-O-MaticD. none of the above

12. How much gap should the load cell sensator have without a load on the hook?A. 5/8 in.B. 3/8 in.C. 4/16 in.D. none of the above

13. How often should the crown block sheaves be greased?A. Every 8 hoursB. After tripping onlyC. After 200 ton-milesD. Daily

14. What is likely to be the effect of a damaged sheave?A. Stuck pipeB. Slow rate of penetrationC. Higher rotary torqueD. Damaged or broken drilling line

15. What should be inspected on the drawworks?A. Damaged groovingB. Wear platesC. Wireline turnbacksD. all of the above

16. What should be attached to the derrick above the drawworks to prevent fastline flopping?A. A wireline guideB. A deadline stabilizerC. A deadline anchorD. A turnback roller

17. Brass inserts can be replaced in what piece of equipment?A. A wireline guideB. A deadline stabilizerC. A deadline anchorD. A turnback roller

18. How many wraps of line should be put on the drawworks with the travelling block at the lower pick up point?A. 18B. 16C. 12D. 8




Part III

19. What is the standard operating safety factor for drilling line?A. SevenB. SixC. FiveD. Four

20. Where are the critical points of wear on the drilling line?A. At the top of the crown block sheaves on pickup pointsB. At the bottom of the travelling block sheaves on pickup pointsC. At crossover points on drawworks and at the deadline anchorD. all of the above

21. What two things does slipping and cutting of drilling line accomplish?A. It moves worn line away from critical wear points and continuously replaces worn line.B. It removes old line from service and moves points of heavy wear to non-critical points.C. It moves less worn line to the critical wear points and adds new line into the system.D. all of the above

22. When should visual inspection of drilling line take precedence over ton-mile goals?A. AlwaysB. After jarring operationsC. Prior to running a heavy casing stringD. During an end of well inspection

23. What does the wire rope service curve explain?A. The required safety factorB. The number of days between slip and cutC. The relationship between safety factor and ton-mile goalsD. How much line to be cut off after slipping

Part IVRefer to the ton-miles tables in the IADC Drilling Manual to answer questions 24–26.

You have just completed a round trip to a depth of 14,000 feet with the following tubulars:18 x 30 foot (92 lbs/ft) 61/2-in. x 23/4-in. drill collars, 5 in. 19.50 lbs/ft. drill pipe. (31 ft average length)The travelling assembly weighs 20,000 lbs and the crown block weighs 10,000 lbs. Mud weight = 10 ppg

24. What is the excess weight allowance?A. 45,900 lbsB. 35,900 lbsC. 25,900 lbsD. 15,900 lbs

25. How many ton-miles were incurred tripping?A. 600B. 547C. 494D. 464

26. The trip before this involved 444 ton-miles tripping. How many ton-miles were used in drilling between trips?A. 468B. 309C. 150D. 60




TON-MILES FORMULA – Calculator MethodRefer to the IADC Drilling Manual: Ton-Mile Calculations Section and use the calculation below to answer questions27–29.

Tr = D(Ls+ D ) Wm + D(M + 1/2 C)

10,560,000 2,640,000

You have just completed a round trip to a depth of 12,000 feet with the following tubulars:15 x 30 ft (101 lbs/ft) 6 3/4-in. x 2 3/4-in. drill collars, 5 in. 19.50 lbs/ft. drill pipe. (31 ft average length)The travelling assembly weighs 25,000 lbs and the crown block weighs 10,000 lbs. Mud weight = 10 ppg

27. What is the excess weight allowance?A. 60,000 lbsB. 50,000 lbsC. 40,000 lbsD. 30,000 lbs

28. How many ton-miles were incurred while tripping?A. 537B. 493C. 411D. 386

29. The trip before this involved 245 ton-miles. How many ton-miles were used in drilling between trips?A. 876B. 744C. 498D. 423




Section: Hole Angle Change and Causes of Hole Deviation

1. Straight-hole drilling should result in ______A. a perfectly straight hole.B. a trouble-free hole with no sharp edges or changes in direction.C. a wellbore that has no changes in angle.D. true vertical depth.

2. Use figure 1.4 to determine the true vertical depth and the horizontal drift in a hole drilled to 5,000 feet with aconstant inclination from the vertical of 6°30'.A. True vertical depth = 4,968 ft; horizontal drift = 566 ftB. True vertical depth = 5,000 ft; horizontal drift = 0 ftC. True vertical depth = 99.36 ft; horizontal drift = 11.32 ftD. True vertical depth = 993.6 ft; horizontal drift = 113.2 ft

3. Doglegs are likely to develop when ______A. the rate of hole angle change is greater than 3° per 100 feet of hole.B. the total hole angle change is greater than 3°.C. weight on bit is suddenly and drastically reduced.D. the penetration rate is too high.

4. Use the table in figure 1.7 to determine the dogleg severity with the following data:First Survey Second SurveyVertical angle: 8° 15' Vertical angle: 2° 45' (8 1/4°) (2 3/4°)Direction: S 34° E Direction: S 9° EDepth: 6,400 feet Depth: 6,475 feet

A. Dogleg severity = 7.82°/100'B. Dogleg severity = 6.12°/100'C. Dogleg severity = 5.87°/100'D. Dogleg severity = 7.82°

5. Doglegs are always more dangerous when they occur ______A. low in the hole, close to total depth.B. near a key seat.C. in the middle of the wellbore where compression is greatest.D. in the top part of the hole.

6. Which of the following factors will increase the amount of fatigue damage to drill pipe?A. Corrosive drilling fluidsB. Low tensile load in the pipe at a doglegC. A severe doglegD. none of the above

7. Hole deviation is likely to occur in ______A. laminar formations with dips up to 45°.B. uniform formations with dips up to 25°.C. formations with alternating hard and soft layers.D. laminar formations with dips more than 45°.

8. When drilling in shale with a formation dip of 40°, the bit is most likely to ______A. climb downdip.B. drill parallel to the bedding planes.C. be unaffected and drill vertical.D. climb updip.

Drilling a Straight Hole - Workbook Questions



9. Key seats are formed when ______A. the drill pipe penetrates the point of a dogleg.B. the bit drills through soft formations.C. the surface location is offset.D. total hole angle change exceeds the cone specifications.

10. In the figure to the right, maximum tension is occurring at ______A. point A.B. point B.C. points A and B simultaneously.D. point C.

11. Keeping a hole straight is difficult in ______A. dipping formations.B. folded formations.C. stratified formations.D. uniform formations.

12. Drilling a straight hole is generally considered easier in soft formations because ______A. less weight is required.B. more weight is required.C. the drill stem will bend less in soft formations than in hard ones.D. fewer joints of drill pipe are needed in soft formations than in hard.

13. Which of the following contribute to unwanted deviation of the wellbore?A. Dull bitsB. Low bit weightC. Minimum clearance between the drill collars and the wall of the holeD. Undersized drill collars

14. A spiraled and undersized hole can result from ______A. low penetration rates in soft formations.B. a limber and unstabilized BHA.C. abrupt reduction of bit weight.D. exceeding the total hole angle change limit.

Section: Controlling Hole Deviation15. When formation characteristics cause the wellbore to drift upstructure, the surface location can be offset. This

drifting has the result that ______A. the surface location will be moved downstructure and the natural tendency of the formation will guide the bit

to the target area.B. the well will be drilled with a packed-hole BHA to ensure a vertical borehole.C. penetration rate will be sacrificed because weight on bit must be reduced in order to keep the hole straight.D. the borehole must be plugged back and redrilled so that the contract deviation requirements are met.

16. In an inclined hole, the most important influence working to keep the hole vertical is ______A. the formation reaction.B. the axial load.C. a fulcrum stabilizer.D. gravity.

17. The pendulum effect is ______A. the force of gravity pulling on an unsupported length of drill collar.B. equivalent to the equilibrium condition.C. never greater than the formation reaction.D. increased by a high point of tangency.

A B

C




18. In drill collars, the areas most likely to bend are ______A. those between the tool joints.B. the pin and the box.C. the body of the collar.D. the first 2 feet on either side of the tool joint.

19. In the IADC Hole Inclination-Weight Tables (fig. 1.22), a class A formation ______A. has severe crooked-hole tendencies.B. is the easiest to drill.C. has mild crooked-hole tendencies.D. can be easily drilled with a slick assembly.

20. It is best to use a pendulum assembly ______A. as a corrective measure to reduce angle.B. in soft and unconsolidated formations.C. in a class B formation.D. when alternating hard and soft strata are expected.

21. Use the table in figure 1.22 to determine which of the following statements are true with the following drillingconditions:

Hole size: 81/8 in. Hole angle: 4°Hole class: R Drill collar size: 7 in.Formation dip: 15°

A. The driller can run 39,162 lbs on the bit with the 7-in. drill collars and maintain hole angle.B. Bit weight can be increased to 68,500 lbs if 7 1/2-in. drill collars are used and a stabilizer run

at 60 ft above the bit without changing hole angle.C. Hole angle can be reduced to 2° by reducing bit weight by 7,362 lbs and adding a stabilizer 80 ft above

the bit.D. The driller can increase weight on bit to 46,200 lbs with the same BHA and not affect hole angle.

22. A sharp and drastic reduction in bit weight is the best way to reduce hole angle.A. TrueB. False

23. The best stabilizer arrangement in a pendulum assembly is composed of ______A. placement of a second stabilizer 30 feet above the fulcrum stabilizer.B. a single stabilizer placed immediately above the bit.C. a single stabilizer placed immediately above the first drill collar.D. two stabilizers run immediately above the bit.

24. In the figure to the right, the tangency point is ______A. point A.B. point B.C. point C.D. point D.

25. The term "gun barrel approach" is sometimes used to refer to a ______A. perfectly straight hole.B. pendulum assembly.C. packed-hole assembly.D. fulcrum stabilizer.


A

D

C

B



26. Moment of inertia, I, is used to express ______A. weight on bit.B. rotary speed.C. drill collar stiffness.D. stabilizer weight.

27. A properly designed packed-hole BHA will ______A. minimize the rate of hole angle change.B. eliminate any bending in the drill string.C. reduce the possibility of doglegs.D. improve bit life and performance.

28. A good packed-hole BHA will require ______A. adequate clearance (at least 11/2 in.) between the bottom stabilizer and the wall of the hole.B. three stabilizer points.C. the largest-diameter collars that can safely be run in the hole.D. a large-diameter collar immediately above the bit that is at least of standard length, if not longer.

29. A packed-hole BHA with three stabilizers in zone 1, one stabilizer in zone 2, and one stabilizer in zone 3 wouldbe most suitable for ______A. mild crooked-hole conditions.B. moderate crooked-hole conditions.C. severe crooked-hole conditions.D. none of the above

30. Increasing the size of the drill collar will ______A. slightly increase the stiffness.B. slightly decrease the weight.C. greatly increase the stiffness.D. increase weight and stiffness in the same proportions.

31. It is usually necessary to reduce weight on bit when changing from a packed-hole assembly to pendulum orpacked pendulum BHA.A. TrueB. False

32. If a driller reduces the bit weight in order to straighten the hole, he must ______A. also change the bit so that the weight will be properly distributed on the cones.B. also decrease rpm.C. reduce the weight quickly so that penetration rate is not lost.D. reduce the weight gradually so that a dogleg will not develop.

33. Advantages of using downhole motors in straight-hole drilling operations include ______A. reduced drill pipe wear.B. lower speeds.C. higher bit weight, allowing for increased penetration rates.D. increased penetration rates because of the higher bit speeds.

Section: Bottomhole Assembly Tools34. The buoyancy factor for 12.8 ppg mud is ______

A. 12.8 ppg.B. 95.75 lb/cu ft.C. 0.804.D. 8.04 lbs.




35. How much does a standard-length drill collar weigh if it has a 51/2-inch OD and 21/4-inch ID?A. 67 lbsB. 2,010 lbsC. 6,700 lbsD. 201.0 lbs

36. What total weight of drill collars in air is required with the following drilling conditions?

Bit weight required: 68,500 lbsSafety factor: 15%Drilling mud density: 12.2 ppgVertical hole: 0° inclination

A. 6,457 lbsB. 68,500 lbsC. 78,775 lbsD. 96,775 lbs

37. How many 71/4-inch OD x 21/4-inch ID standard-length drill collars will be needed with the following drillingconditions?

Bit weight required: 32,440 lbsDrilling mud density: 9.8 ppgSafety factor: 15%

A. 14B. 12C. 8D. 7

38. If seven standard-length 6-inch OD x 213/16-inch ID drill collars are used, how many standard-length71/2-inch OD x 213/16-inch ID collars will be needed with the following conditions?

Bit weight required: 46,129 lbsDrilling mud density: 12 ppgSafety factor: 17%

A. 24B. 14C. 13D. 7

39. The point at which the drill collar string changes from compression to tension is called the _____A. neutral point.B. equilibrium condition.C. point of tangency.D. fatigue damage.

40. Large drill collars are the best tools for combating crooked-hole problems. In fact, the largest drill collarsavailable should be used because drill collars cannot be too large in crooked-hole country.A. TrueB. False

41. A general rule of thumb that can be used in selecting drill collars for a transition zone is to _____A. install the largest-OD, thickest-walled collars possible.B. always use square drill collars.C. reduce drill collar size not more than 2 inches at any crossover.D. use only one drill collar for each size reduction.




42. Square drill collars _____A. should be gauged at every trip and replaced if worn more than 1/4 inch.B. are most effective in soft formations.C. should be only 1/16 inch smaller than the hole when new.D. should be used with a reamer run above the bit for protection.

43. A properly stabilized BHA should _____A. use fewer bits.B. maintain a straight course.C. allow lateral movement of the bit.D. allow use of optimum drilling weight.

44. A nonrotating sleeve stabilizer is best suited for ______A. holes with rough walls.B. hard formations.C. holes with temperatures higher than 250°F.D. holes with temperatures less than 250°F.

45. An appropriate stabilizing tool for a hard formation is ______A. one with a large wall contact area.B. a welded-blade stabilizer.C. an integral-blade stabilizer.D. a replaceable-blade stabilizer.

46. A sleeve stabilizer ______A. can be used in soft, medium, and some hard formations.B. can be used in various hole sizes, depending on the sleeve.C. is assembled with high temperatures (up to 750°F).D. allows for blades to be easily changed, as the sleeve can be replaced on the rig floor.

47. The primary purpose of a roller reamer in the BHA is to ______A. stabilize the bit.B. increase bit weight.C. reduce hole angle.D. maintain full gauge hole.

48. Which of the following tools would most probably be used in a hard formation?A. Integral-blade stabilizerB. Rolling cutter reamerC. Go-devilD. Welded-blade stabilizer

49. In very severe crooked-hole conditions, a vibration dampener should be run ______A. between zones 1 and 2 in place of a short drill collar.B. immediately above the bit.C. above zone 3, with an additional stabilizer 30 feet above it.D. immediately above zone 2.

50. Inaccurate recordings from deviation-recording instruments may result from ______A. drill pipe movement.B. movement of the drilling fluid.C. inadequate resting time on bottom.D. running and retrieving the barrel assembly on ordinary sandline.




Section: Introduction and The Hydraulic System1. A properly designed hydraulic system will ______

A. gouge out new hole in all formations by powerful jet nozzle action.B. deliver adequate power to the bit nozzles for bottomhole cleaning.C. provide enough pressure to the drilling mud to transport cuttings out of the annulus.D. not influence other drilling variables such as bit weight and rotary speed.

2. In using prepared tables to determine pressure losses in the hydraulic system, the ______ must be takenaccount of if it differs from that used in preparing values for the table.A. mud viscosityB. rotary speedC. bit weightD. mud weight

3. Reducing the amount of pump input power will not have any effect on the drilling rate if the proper bit has beenselected for the drilling operation.A. TrueB. False

4. Use the 10D2 rule to determine the input pump power for properly cleaning an 8 1/2-inch hole.A. 80 hpB. 800 hpC. 810 hpD. 810 hhp

5. If necessary, two pumps can be compounded in a series to increase ______A. fluid output.B. fluid velocity.C. fluid pressure.D. all of the above

6. Which of the following conditions will result in the largest increase in hydraulic horsepower?A. Increasing fluid pressure and decreasing fluid volumeB. Increasing fluid pressure and keeping fluid volume constantC. Increasing both fluid pressure and the fluid volumeD. Decreasing both fluid pressure and fluid volume at a slow but constant rate

7. What is the hydraulic horsepower produced by a pump that delivers 419 gpm at 2,330 psi? (Answers arerounded to the nearest whole number.)A. 570 hhpB. 1,714 hhpC. 2,749 hhpD. 976,270 hhp

8. Determine the input power needed to deliver the amount of hydraulic horsepower in question 7, if the pump is90% efficient.A. 90 hhpB. 570 hhpC. 518 hhpD. 633 hhp

Rig Hydraulics - Workbook Questions



9. What is the approximate standpipe pressure for a pump that delivers 590.4 hhp with a circulation rate of 460gpm?A. 1,714 psiB. 2,200 psiC. 2,729 psiD. 590.4 psi

10. What hydraulic horsepower is produced by a pump that delivers drilling fluid at a rate of 12 bbl/min with 2,100 psi?A. 14.7 hhpB. 560 hhpC. 617.5 hhpD. 721.2 hhp

Section: Pressure Losses in the System11. The greatest pressure loss in the hydraulic system occurs ______

A. in the surface equipment.B. across the bit.C. in the annulus.D. at the surface in the mud tank.

12. Use figures 2.6 and 2.7 in the lesson to determine the pressure loss for the following equipment:standpipe–45 ft with 4-in. ID; hose–55 ft with 3-in. ID; swivel–5 ft with 21/4-in. ID; kelly–40 ft with31/4-in. ID. Circulation rate is 570 gpm with 10-ppg mud.A. 254 psiB. 91 psiC. 56 psiD. 38 psi

13. If the surface equipment given in question 12 were used with 12.2 ppg mud and circulated at 540 gpm, whatpressure loss would occur?A. 82 psiB. 61 psiC. 50 psiD. 44.6 psi

14. The best way to determine pressure losses in the drill string is to tabulate losses in the drill pipe and drill collarsseparately and then add them together.A. TrueB. False

Use figures 2.9 and 2.10 with the following drilling conditions to answer questions 15, 16, and 17.Drill pipe: Drill collar size:Size: 41/2-in. OD 2-in. bore, 8-in. ODWeight: 16.6 lbs/ft Circulation rate:Tool joint type: XH 490 gpm

15. With 10-ppg mud, the pressure loss through 7,500 feet of drill pipe is ______A. 96 psi.B. 490 psi.C. 720 psi.D. 720,00 psi.




16. If a 10-ppg mud is used, what is the pressure loss through 330 feet of drill collars?A. 151.2 psiB. 211 psiC. 490 psiD. 696.3 psi

17. If 9-ppg mud is used, what is the total pressure loss occurring through 7,500 feet of drill pipe and 330 feet of drillcollars?A. 307 psiB. 1,274.6 psiC. 1,416.3 psiD. 1,573.6 psi

18. The amount of pressure available for the bit should be ______ percent of the total pressure from the pump.A. 33–47B. 50–75C. 100D. none of the above

19. Pressure losses in the drill string will be increased by ______A. large-diameter drill pipe.B. low-weight mud circulated at a slow flow rate.C. plastic-lined drill pipe.D. none of the above

20. If a properly designed hydraulics program delivers a total of 685 hhp at the surface, what is the minimum hhpneeded at the bit (bhhp)?A. 342.5B. 547.6C. 685D. 1,027.5

21. The drilling fluid undergoes a large pressure decrease and a great velocity increase at the bit nozzles.A. TrueB. False

22. Pressure losses in the annulus are affected by the ______A. size of the drill string.B. circulation rate.C. size of the hole.D. all of the above

23. Generally, the velocity of the drilling fluid in the annulus should be as high as possible and, in any case, neverless than the rate in the drill string.A. TrueB. False

24. Which one of the following drilling fluids would give the highest pressure losses?A. Clear waterB. Oil-based mudC. High-density mudD. High-viscosity mud




Section: Bit Hydraulics25. Generally, the amount of horsepower needed at the drilling face is ______

A. less than 3 hp per square inch of hole bottom.B. 3 to 5 hp per square inch of hole bottom.C. at least 10 hp.D. equal to the hole diameter squared.

26. Bit hydraulic horsepower, bhhp, is ______A. the total fluid power available at the bit.B. the total fluid power available to and used by the hydraulic system.C. decreased by high pressure losses in the drill string.D. increased by high pressure losses in the annulus.

27. What is the bhhp in a system with the following drilling conditions?Pressure losses in surface equipment and drill string–680 psi; circulation rate–460 gpm; total hhp–564; surfacepressure–2,100 psi.A. 377.8B. 685C. 247.1D. 381

28. A jet nozzle that measures 8/32 in. in diameter of nozzle opening is called a size ______A. 0.25.B. 32.C. 8.D. none of the above

29. In a tricone bit, nozzle velocity can be increased by ______A. increasing the circulation rate.B. doubling the size of the nozzles and blanking off one jet.C. using smaller nozzles.D. all of the above

30. Use the table in figure 2.16 to determine the best nozzle combination for a hydraulics program that has acirculation rate of 820 gpm and pressure available at the bit of 1,560 psi (assume 10-ppg mud). Theappropriate nozzle combination is ______A. one 16 and two 18s.B. two 16s and one 18.C. three 16s.D. one 15 and two 16s.

31. Doubling the flow rate and doubling the size of the nozzle will double the nozzle velocity at the bit.A. TrueB. False

Section: Annular Hydraulics and Designing the Rig Hydraulics Program32. In the annulus, the drilling fluid ______

A. will be in turbulent flow at all times.B. should be maintained at high-velocity laminar flow.C. should remove the cuttings as quickly as possible without causing hole washout.D. can change from laminar flow to turbulent flow in constricted passages.




33. Slip velocity is decreased by ______A. small cutting size.B. high-density mud.C. high-viscosity mud.D. all of the above

34. Use tables 1 and 2 to determine the annular velocity for the following drilling conditions: circulation rate–420gpm; drill pipe size–4-in. OD and 3.34-in. ID; hole size– 7.875 in.A. 96.75 ft/minB. 14 ft/minC. 5 ft/minD. 230.4 ft/min

35. The main objectives in planning an efficient hydraulics program are to ______A. select the correct nozzle combination for bottomhole cleaning.B. project the final depth of the hole.C. increase the effectiveness of bit weight and rotary speed.D. all of the above




Section: Introduction and Drilling Fluid Composition and Properties1. When added to water, a good drilling clay will ______

A. hydrate.B. react with the inert fraction.C. thin the mud.D. increase viscosity.

2. The reactive portion of the drilling mud is sometimes called the ______A. liquid phase.B. colloidal fraction.C. inert fraction.D. emulsion.

3. The plastic viscosity of a drilling mud depends on ______A. the strength of the electric charges on the solid particles in the mud.B. mechanical friction in the mud.C. high yield point.D. the concentration, size, and shape of solids in the mud.

4. According to the clay-yield curve shown in figure 3.6, roughly how many pounds of common drilling clay areneeded to produce 1 barrel of 15-centipoise mud?A. 100B. 20C. 10D. 200

5. A water-base mud can be deflocculated by ______A. increasing the viscosity.B. adding chemical thinners.C. neutralizing attractive charges in the mud.D. increasing the yield point.

6. The gel strength of a mud concerns its ability to ______A. temporarily thicken when mud flow stops.B. produce a good filter cake.C. flow after circulation is restarted.D. increase as yield point decreases.

7. Filtration rate is ______A. the amount of clay solids lost to a formation.B. increased by adding inert solids to the mud.C. increased by adding bentonite to the mud.D. the amount of liquid in the mud lost to a formation.

8. Bentonite, a clay often used in drilling muds, will hydrate greatly when added to the mud, regardless of what thecontinuous liquid phase is made up of.A. TrueB. False

9. Filter cake is ______A. made up of solids in the drilling mud.B. another name for cuttings.C. harmful to the hole wall and should be removed with deflocculants.D. none of the above

Drilling Muds - Workbook Questions



10. Inert solids in the drilling mud ______A. dissolve when they are added to the drilling mud.B. hydrate when wetted.C. are smaller than clay particles in the mud.D. have none of the above characteristics.

11. The colloidal fraction of a drilling mud can contain ______A. low-yield commercial clays.B. drilled solids.C. weight materials.D. all of the above

12. An unweighted mud will ______A. not contain barite or other weight materials.B. often contain drilled solids.C. generally have a density higher than 10.5 ppg.D. all of the above

Section: Functions of Drilling Fluids13. One function of drilling mud is to ______

A. fill new formations with bentonite.B. help enlarge the wellbore.C. deposit a wall cake on the wellbore.D. maintain high turbulent flow in the annulus.

14. Another function of the drilling mud is to ______A. dissolve limestone layers so that drilling through them is easier.B. cool and lubricate the bit and drill string.C. impose back-pressure on the bit.D. allow larger cuttings to settle to the bottom of the hole rather than clog up the annulus.

15. The density of a drilling fluid is important for ______A. cleaning used drill pipe.B. supporting some of the suspended weight of drill pipe or casing.C. increasing the weight of the drill string in the hole.D. controlling formation pressure.

16. Which of the following factors will cause inaccurate results in an electric log?A. The use of an oil-base mud as the drilling fluidB. Excessive water filtrate in the formationC. The use of seawater as the makeup water for the mudD. none of the above

Section: Water-Base Muds17. Mud-up operations may involve adding ______

A. premium clays.B. PAC.C. phosphates.D. all of the above




18. An additive that can be used to improve filtration in muds with salt contamination higher than 20,000 ppm is______A. barite.B. PAC.C. asbestos.D. CMC.

19. Water-back is an operation that ______A. increases the fluid-to-solids ratio.B. increases the solids-to-fluid ratio.C. increases viscosity.D. lowers the rate of water loss.

20. Bentonite is added to freshwater muds to ______A. decrease mud weight.B. increase viscosity.C. inhibit corrosion.D. lower water loss.

21. Thinning a mud may involve ______A. adding CMC.B. deflocculation.C. flocculation.D. increasing water loss.

22. Filtration control agents are added to a mud to ______A. increase the filtrate.B. decrease formation permeability.C. reduce water loss.D. lower cement contaminants.

23. Adding barite to mud will ______A. increase the mud weight.B. increase the inert solids content.C. increase the mud volume of the system.D. all of the above

24. High viscosity, yield point, and gel strength can be caused by ______A. a low concentration of drilled solids.B. insufficient deflocculation of clay solids.C. contamination from gypsum, cement, or salt.D. all of the above

25. Water loss from the mud can be lowered by adding ______A. PAC.B. gums.C. starch.D. shale.

26. A drilling mud with a pH of 9.5 is considered ______A. acidic.B. neutral.C. alkaline.D. none of the above




27. Which of the following additives could be used to reduce viscosity and gel strength in a mud with a pH of 10?A. LigniteB. QuebrachoC. CMCD. Lignosulfonate

28. With salt contamination, the best way to remove salt from the mud is by—A. adding a commercial flocculating agent.B. treating the mud returns with a large amount of barite at the shale shaker.C. adding a small amount of CMC.D. none of the above

29. The best procedure for drilling in thick salt beds or dome salt is to convert to clear water for the drilling fluid untilthe salt formation has been penetrated.A. TrueB. False

30. Adding lime to a spud mud will ______A. make it unusable for drilling through surface casing.B. increase the mud’s viscosity.C. require less clay for building viscosity.D. require more barite to increase density.

31. The viscosity of a good natural mud can be lowered by ______A. treating it with phosphates.B. adding premium drilling clay.C. adding large amounts of water.D. all of the above

32. A phosphate-treated mud can be effectively used ______A. with calcium contamination.B. for reducing viscosity, gel strength, and filtration rate.C. in shallow wells with freshwater formations.D. with saturated salt water as the makeup water.

33. A characteristic of lignosulfonate muds is that ______A. they actively interact with formation clays.B. they are effective with normal calcium and salt concentration.C. they can maintain low viscosity in heavily weighted muds.D. all of the above

34. A calcium-treated mud can be effectively used for ______A. controlling sloughing shales.B. reducing viscosity caused by drilled solids.C. controlling hole enlargement.D. all of the above

35. Which of the following muds would be most effective in a drilling operation that encounters bottomholetemperatures of 300°F?A. Phosphate-treated mudsB. Calcium hydroxide or lime mudC. Lignosulfonate mudD. all of the above




36. Which of the following additive-effect combinations is correct when used in a saltwater mud?A. CMC to increase filtrationB. Lignosulfonate as a thinnerC. Bentonite as the primary additive for the colloidal fractionD. Pin oil to reduce the effects of foaming

37. To function effectively as drilling fluids, clear fresh water and salt water frequently require ______A. additives for decreasing viscosity.B. additives for reducing flocculation.C. mechanical equipment for solids control.D. additives for controlling filtration rate.

38. Advantages of polymer muds include the following:A. They can be effectively used with salt water without additional chemical treatment.B. They allow the high viscosity in the annulus necessary for cutting removal.C. They have low viscosity at the bottom of the hole for rapid drilling.D. They require less bentonite to maintain proper viscosity.

39. Particular care should be exercised in adding chemicals to the mud because some ______A. are poisonous.B. cause burns to skin.C. are dangerous when inhaled.D. include all of the above characteristics.

Section: Oil-Base Muds40. Advantages of oil-base muds include ______

A. low initial costs.B. low density.C. ability to function effectively at high downhole temperatures.D. the fact that barite or other weight materials are not used in oil muds.

41. A mud with a continuous phase made up of 30% water and 70% diesel oil is called ______A. a true oil-base mud.B. a low-solids mud.C. a polymer mud.D. an invert-emulsion mud.

42. In an oil-base mud, the colloidal fraction is ______A. comprised of natural clays.B. comprised of bentonite, hectorite, or attapulgite.C. eliminated.D. replaced by defoamers.

43. In an invert-emulsion mud, water will ______A. dilute salts and asphalt materials.B. reduce the viscosity of the mud.C. lessen control of fluid loss.D. none of the above

44. The amount of soap formed in an oil-base mud must be controlled because excessive amounts of soap canreduce penetration rates.A. TrueB. False




45. Which of the following units are expressions of density?A. Pounds per gallonB. Gradient in psi per 1,000 feet of mud in the holeC. Pounds per 100 square feetD. Kilograms per litre

46. When calibrating a mud balance, fill the cup with pure water and set the movable weight to read ______A. zero.B. 8.1 ppg.C. 8.33 ppg.D. 10 ppg.

47. In a field test, the mud man would measure apparent viscosity of the mud ______A. in pounds per 100 square feet.B. in terms of specific gravity.C. with a Marsh funnel.D. in seconds per quart (946 cc).

48. The filtration test measures ______A. plastic viscosity over time.B. water loss under pressure.C. thickness of wall cake in 1/32-inch increments.D. specific gravity of the solids.

49. Procedures for testing oil-base and water-base muds are basically the same except that the funnel viscosity of awater-base mud varies greatly with temperature changes, while the apparent viscosity of an oil mud is notaffected by temperature.A. TrueB. False

50. The sand content determination test measures ______A. sand content by weight.B. precipitation rate of sand in solution.C. percent of sand by volume.D. none of the above




Section: Introduction and Types of Casing1. Each of the following is considered to be a primary function of casing in a well except ______

A. to provide a means of controlling well pressure.B. to confine production to the wellbore.C. to allow production from multiple producing formations.D. to permit installation of artificial lift equipment.E. to prevent the hole from caving.

2. One of the major differences between casing and drill pipe is that ______A. the length range of the casing most frequently used is shorter than the standard joint of drill pipe.B. the range of casing OD and wall thickness is much greater than that of standard drill pipe, accounting for the

larger diameter and increased weight of casing.C. the ID of most casing is smaller than the ID of drill pipe, accounting for the greater wall thickness of casing.D. drill pipe is threaded on each end and most casing is not.

3. The conductor pipe is almost always cemented in offshore wells.A. TrueB. False

4. A typical casing arrangement on land is made up in the following order ______A. conductor, structural, surface, and intermediate casing.B. surface, intermediate, production, and oil string casing.C. surface, conductor, intermediate, and production casing.D. conductor, surface, intermediate, and production casing.

5. The short string refers to the ______A. intermediate casing.B. conductor.C. oil string.D. liner settings.

6. Factors influencing the depth at which surface casing is set include ______A. state rules and regulations.B. depth of mineral deposits requiring protection.C. formation fracture gradient.D. all of the above

7. The casing string that seals off weak zones that might rupture with heavy muds needed to drill deeper andprotect against lost circulation in shallow formations is ______A. surface casing.B. conductor pipe.C. intermediate casing.D. oil string casing.

8. The main purpose of surface casing is to ______A. isolate the producing formation.B. provide an inexpensive means of testing lower zones.C. protect freshwater formations.D. all of the above

9. Surface casing and intermediate casing have entirely different functions, so in a well where surface casing is setto 5,000 feet, intermediate casing will not be needed.A. TrueB. False

Casing - Workbook Questions



10. Advantages of liner settings are that ______A. they are almost always cemented in place.B. their installation involves lower costs.C. they require a relatively short amount of time on bottom for installation.D. they can be used in place of surface casing.

11. Production casing is sometimes called ______A. oil string.B. long string.C. tie-back casing.D. all of the above

12. Frequently, the heaviest string of pipe set in the well is the ______A. intermediate string.B. tie-back string.C. conductor.D. production string.

Section: Casing Standards and Casing String Design13. The main difference in the various grades of steel used in API-rated casing is ______

A. length.B. minimum yield strength.C. outside diameter.D. type of thread.

14. The most frequently used casing is ______A. Range 1, 16–25 ft in length.B. Range 2, 25–34 ft in length.C. Range 3, 34–48 ft in length.D. shorter in length than Range 1.

15. A casing string for a particular well is usually made up of uniform grades of casing.A. TrueB. False

16. Casing that is shorter in length than the standard ranges is called ______A. short strings.B. couplings.C. joints.D. pup joints.

17. Factors that affect the design of a casing string for a well include ______A. tension.B. collapse pressure.C. burst pressure.D. all of the above

18. The minimum tensile strength for API Casing Grade J-55 is ______A. 55,000 psi.B. 80,000 psi.C. 75,000 psi.D. 100,000 psi.




19. When designing casing strings, designers need not consider couplings because the coupling strength equalsthe strength of the pipe body.A. TrueB. False

20. Failure of new casing can usually be attributed to ______A. damage while being handled.B. excessive pressures.C. improper grade.D. stress concentration cracks.

21. When couplings are screwed onto the casing hand tight, they are ______A. loose enough to be easily removed by hand.B. tight enough so that a wrench must be used to remove them.C. also tightened to the power-tight position.D. easily removed for cleaning and inspecting before the pipe is used.

22. Collapse pressures are ______A. generally disregarded for surface casing.B. a result of downward force pulling on the casing body and couplings.C. greatest at the bottom of the hole.D. important considerations for selecting some strings, such as the production string.

23. The casing strings that must withstand the greatest burst pressures are the ______A. conductor.B. surface.C. intermediate.D. production.

24. Use the most commonly employed tension factor to calculate the amount of weight that could be suspendedfrom a top joint with a tensile strength of 420,000 pounds.A. 756,000 lbsB. 75,600 lbsC. 233,334 lbsD. 23,334 lbs

25. Torsional stress ______A. is a result of forces pushing down on the pipe.B. often occurs because of hole deviation or marshy terrain.C. may be expected if rotating scratchers are used.D. occurs when portions of the pipe turn in opposing directions.

26. Factors affecting the selection of properly sized production casing for a well include ______A. method of production for the well.B. common practices in the area.C. rate of production for the well.D. none of the above

Section: Casing Accessories27. Installing casing accessories by welding is probably not desirable because ______

A. welding can cause stress concentrations in the metal that may result in pipe failure.B. welding can cause accessories to break off and fall to the bottom of the hole.C. welding will damage the accessories.D. welding prevents casing accessories from moving freely on the pipe.




28. Experience from the field has shown that some slurry contamination occurs below the top plug. To reduce thechance of slurry contamination in the annulus, an operator may practice ______A. not using a top plug.B. using a float collar near the casing shoe.C. using guide shoes.D. using a float collar a distance of one or more lengths above the casing shoe.

29. The device used to guide the casing around obstructions or ledges in the hole is a ______A. float collar.B. baffle collar.C. centralizer.D. guide shoe.

30. An automatic fill-up shoe will ______A. control the amount of fluid entering the bottom of the casing string as it is run into the hole.B. reduce the surge pressure.C. reduce the possibility for lost circulation.D. all of the above

31. Operators cementing very long casing strings in which the potential for formation damage is high may cementseparate sections with the use of ______A. high-pressured pumps.B. multistage cementing devices.C. baffle collars.D. any of the above

32. Casing strings cemented without centralizers are more likely to ______A. obtain a better bond between the casing and the formation.B. have less wall cake.C. have a uniform sheath of cement around the pipe.D. none of the above

33. Scratchers clamped to the casing can add strength to the cement sheath holding the casing in place becausethey lace the cement with steel cables.A. TrueB. False

Section: Setting Casing34. Powered casing tongs are beneficial in running casing because they ______

A. ensure proper makeup for each threaded joint.B. properly score the casing with die marks.C. eliminate the hazards of the spinning rope.D. save labor.

35. Thread protectors should be removed from the casing as it is ______A. removed from the truck.B. counted.C. stacked on the pipe rack.D. none of the above

36. In most cases, the regular rig crew will prepare for the casing operation by ______A. preparing the hole.B. checking the operating condition of rig machinery.C. making arrangements for filling casing as each joint is made up.D. all of the above




37. Preparing the hole includes ______A. going into the hole with one stand of drill collars and a used bit.B. removing any casing accessories that may have come loose and fallen to the bottom of the hole.C. maintaining circulation until all the cuttings have settled at the bottom of the hole.D. all of the above

38. Accurate casing measurement is essential on any casing job. The task of measuring casing for a given job maybe accomplished by ______A. electric logs.B. cement bond logs.C. measuring and counting joints of pipe delivered to the site.D. checking shipping papers.E. using casing tally sheets.

39. If a clean thread protector is in place as a joint of casing is picked up from the catwalk, it is not necessary toapply thread compound before stabbing.A. TrueB. False

40. Thread-locking compound hardens ______A. very slowly over a period of several days.B. to prevent joint back-off.C. to a point at which it is four times harder to break the connection than it was to make it up.D. according to all of the above statements.

41. Procedures for handling casing properly include ______A. gently rolling the casing off the delivery truck onto the ground.B. using a large heavy-duty hook in the ends of the threaded casing to lift the casing if thread protectors are in

place.C. neatly stacking the casing on the ground so that there is no danger of the pipe falling and becoming

damaged.D. none of the above

42. Correct procedures for stabbing casing include ______A. rolling the pin into the box or coupling if the pipe misses it on the first try.B. running at least three joints of casing at a time to ensure adequate weight for efficient stabbing.C. applying as much torque to the connection as possible to overcome any misalignment of threads.D. none of the above

43. Inadequate conditioning of the hole and improper mud treating may cause problems suchas ______A. poor cementing.B. stuck pipe.C. redrilling the hole.D. all of the above

44. During a casing job, it is a good practice to fill the casing periodically as the pipe is run in the hole because______A. large-diameter pipe may collapse because of unbalanced pressure outside the pipe.B. the pipe may stick.C. it aids in the cementing process.D. it helps prevent a blowout.




45. The volume of mud gain by the pits when a 15,000 foot, 51/2-in. OD casing is run in a well and completely filledup (assume no fluid loss) is ______A. 100 bbls.B. 10.9 bbls.C. 109.0 bbls.D. 190.0 bbls.

46. Operators can reduce the chance of losing circulation while running casing by ______A. lowering the casing more slowly.B. installing additional casing accessories.C. increasing the mud viscosity.D. none of the above

47. Circulating the casing string after reaching bottom produces some desirable effects, including ______A. flushing out cuttings and wall cake before cementing.B. conditioning the mud.C. testing the surface piping system.D. all of the above

48. It is not considered good practice to move the casing either by rotating or reciprocating when scratchers areinstalled.A. TrueB. False

49. Landing practices recommended by API include ______A. slacking off weight when landing casing because the casing hanger cannot withstand the same amount of

weight as the elevator.B. landing casing with the same weight on the casing hanger as that supported by the elevator.C. landing casing at the wellhead in the exact position it had when cemented.D. picking up weight on the casing hanger when landing the casing.

50. Changes in temperature as well as other operational changes in a well require that casing withstand severaltypes of loads, including ______A. burst.B. collapse.C. buckle.D. tension.E. all of the above




Section: Mixing Cement1. In addition to providing support for casing, primary cementing is essential to the well because it ______

A. prevents casing corrosion.B. allows formation fluids from different zones to mix and flow to the surface.C. prevents the hole from caving below the casing.D. makes drilling the well easier.

2. If a well has a high-quality casing job, cement is usually not needed.A. TrueB. False

3. A cementing crew may not wish to use water from a stock tank near a well site because ______A. the water might contain organic chemicals that affect the setting properties of cement.B. the water might foul pumping equipment.C. the water supply might be inadequate.D. all of the above

4. The use of seawater with cement will ______A. decrease the early strength of the cement.B. result in a stronger cement over a long period (say 28 days) of time.C. prevent the cement from setting.D. increase the early strength of the cement.

5. The best temperature range for slurry is ______A. below 60°F to prevent water loss from evaporation.B. between 60°F and 90°F as it goes into the well.C. between 90°F and 100°F as it goes into the well.D. higher than 100°F to ensure proper viscosity.

6. Experience from the field suggests that the best water-cement ratio is approximately ______A. 101/2 gallons per sack of cement.B. 111/4 gallons per sack of cement.C. 5 1/2 gallons per sack of cement.D. 8 gallons per sack of cement.

7. Given water requirements of 500 gallons per cementing unit and 500 gallons for safety and error and assumingthat two cementing units dispatched to a location require 1,500 sacks of cement, the minimum amount of waterneeded to safely complete the job would be ______A. 9,250 gallons.B. 9,750 gallons.C. 10,250 gallons.D. 10,000 gallons.

8. The recirculating mixer is the most widely used cement mixer because ______A. it employs a partial vacuum in the hopper, which is a desirable element for cement mixing.B. cement and water are blended by a stream of air, and this produces a smoother slurry.C. it was the first system widely used, and repair parts are easy to obtain.D. it produces a smooth and homogeneous cement slurry due to the process of mixing the wet cement with

recirculated slurry.

Section: Pumping Cement and Cement Volume Requirements9. The purpose of using a preflush in cementing operations is to ______

A. accelerate the setting time.B. remove some of the wall cake.C. provide a spacer between the drilling mud and the slurry.D. increase the density of the slurry.

Cementing - Workbook Questions



10. Slurry density can be checked with ______A. a mud balance.B. a Marsh funnel.C. an automatic recorder.D. all of the above

11. Each of the following is considered a benefit derived by pumping water as a flushing agent ahead of the cementexcept ______A. it reduces cement contamination.B. it can be put into turbulent flow at a low circulation rate.C. it decreases cement setting time.D. it is easy to obtain.

12. In order to achieve the maximum amount of mud removal and also some reduction in the amount of filter cake,operators should ______A. obtain turbulent flow while pumping cement.B. obtain laminar flow while pumping cement.C. obtain plug flow while pumping cement.D. add friction-reducing chemicals to the cement.

13. Slurry density should be carefully controlled by the cementer because ______A. it is a direct indication of the water-cement ratio that affects hydration.B. it should always be kept lower than 12 ppg.C. it indicates slurry volume.D. it may be particularly important when lost circulation is a factor.

14. The bottom plug is ruptured by pump pressure, but the solid top plug is not.A. TrueB. False

15. An improved cement job results if the operator pumps the slurry ______A. at the lowest rate possible with no delays.B. at the highest rate possible with intermittent delays.C. at a moderate rate, changing frequently from the highest rate possible to the lowest rate possible with no

delays.D. at the highest rate possible with no delays.

16. Benefits derived from using a bottom plug in the cementing operation include ______A. wiping mud film from inside casing.B. reducing slurry contamination.C. preventing entry of air into slurry.D. all of the above

17. Pressure should be bled off the casing before ______A. the top plug ruptures.B. the cement sets, so the pipe will not bulge.C. the valve in the float collar closes.D. none of the above

18. Which of the following substances can be used as displacement fluid?A. SeawaterB. Fresh waterC. Drilling fluidD. all of the above




19. Using the rule-of-thumb method to calculate the capacity of a 15,000-ft open hole, the diameter of which is 8 5/8in., the amount of fluid needed to fill the hole is approximately ______A. 1,350 barrels.B. 1,000 barrels.C. 1,500 barrels.D. 1,215 barrels.

20. Using the information in question 19, assume that 7-in. OD casing, J-55, 26 lb/ft, was run in the hole. Using therule-of-thumb method, the volume (cubic feet) of fluid required to fill the annular space is ______A. 3,400 cu ft.B. 2,688 cu ft.C. 2,500 cu ft.D. 2,000 cu ft.E. none of the above

21. To ensure effective cement bonds to casing strings, operators usually cement each casing string from thebottom to the top.A. TrueB. False

22. In determining the volume of an open hole with the diameter-squared method, a slightly larger figure for diametershould be used to allow for ______A. larger casing OD.B. hole enlargement.C. errors in calculation.D. an extra amount of cement slurry as a safety factor.

23. Using the rule-of-thumb method, determine the amount of fluid needed to cement a 9 7/8-inch hole with 7-inchcasing over a 5,000-foot interval.A. 255 cu ft.B. 1,428 cu ft.C. 1,714 cu ft.D. 14,280 cu ft.

24. The casing string most often cemented from the shoe to the surface is the ______A. intermediate string.B. oil string.C. surface string.D. conductor pipe.

Section: Considerations after Cementing and Oilwell Cement and Cement Additives25. Operators who bleed off some of the pressure on the casing following pump shutdown gain some desirable

results, including:A. positive or negative feedback on holding condition of back-pressure valve in the string.B. possibility of immediate nippling-up.C. minimized risk of loosening cement bond after cement hardens.D. all of the above

26. Since regulations leave waiting on cement (WOC) time open when there is a float valve in the string, an operatorwill probably start drilling out ______A. immediately after a reasonable WOC time expires.B. about 8 hours after WOC time starts.C. about 12 hours after WOC time starts.D. at his own discretion.




27. WOC time generally begins ______A. when surface returns are seen around the surface casing.B. after the cement plug is drilled out.C. at a time designated by the operator.D. when the plug bumps the float collar.

28. A problem concerning the height of cement in the annulus may best be solved, shortly after the slurry isdisplaced, by conducting ______A. bond logs.B. radioactive tracers.C. temperature surveys.D. any of the above

29. An operator desiring to lower the density of cement slurry may do so by adding all of the following except ______A. perlite.B. bentonite.C. barite.D. salt.

30. A temperature survey may be used to determine the top of cement because ______A. cement absorbs heat as it sets.B. the empty spaces above the cement are of a higher temperature than the cement.C. cement gives off heat as it sets.D. none of the above

31. Cement additives may be used to ______A. increase setting time.B. decrease setting time.C. increase density.D. all of the above

Section: Secondary Cementing32. Plug-back cementing is used for each of the following except ______

A. repairing leaks in casing.B. sealing off a dry hole.C. shutting off depleted formation so that production can be taken from a higher zone.D. repairing primary cementing failure.

33. The packer squeeze technique differs from the bradenhead technique in that ______A. high-squeeze pressure may be achieved.B. greater control over squeeze operation is available.C. the zone to be treated is not isolated from the surface.D. tubing and casing pressures are not tested for leaks.

34. Squeeze cementing is considered a method of ______A. primary cementing.B. plug-back cementing.C. secondary cementing.D. none of the above

35. It is generally not necessary to move the pipe (by either rotation or reciprocation) when setting a cement plug.A. TrueB. False


Completion Notification Form

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Position : Rig :(Day / Month / Year)

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I certify that this training participant has completed to my satisfaction all of the mandatory tasks on theAssistant Driller OJT Module task list. Also, this individual has successfully completed the workbookexercises.

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