4. assistant driller module trainee booklet

8/19/2019 4. Assistant Driller Module Trainee Booklet

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ASSISTANT DRILLERM ODULE


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Section: TOC Page: 1

Issued: 31 December 2006

Assistant Driller

Module

Integrated Project Management

Modular Training Program Revision: 02

Table of Contents

1) Program Guide Sheet

2) Task List

3) Tool List

4) Workbook Questions

Workbook 1: Applied Mathematics

Workbook 2: Practical Well Control

Workbook 3: Kick Data and Gauges

Workbook 4: Drilling Line Care and Maintenance

Workbook 5: Drilling a Straight Hole

Workbook 6: Rig Hydraulics

Workbook 7: Drilling Muds

Workbook 8: Casing

Workbook 9: Cementing

5) Personal Notes

6) Completion Notification Form


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Assistant Driller Module

Program Guide Sheet


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Section: 1 Page: 1


Assistant Driller

Module



Program Guide Sheet- For the Participant

INTRODUCTION

The Modular Training Program is designed to help you do your job more safely and effectively, and to progressin your career with IPM. It is rig-based, and focuses on the tasks specific to each job.

The program allows you to progress at your own speed, with the help of your Supervisor. Don't hesitate to askif there's anything you don't understand.

PREREQUISITE

Before you start this module, you must complete the Derrickman Module.

OBJ ECTIVES

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

1) demonstrate a clear understanding of the role and responsibilities of the Assistant Driller in IPM.

2) perform basic Assistant Driller tasks safely and competently.

TRAINING MATERIAL

The Assistant Driller Module includes:

1) Task List, a list of tasks which you must be able to perform.

2) Tool List, a list of reference DVD and books in the Training Room on your rig.

3) Workbook exercises, a set of review quizzes.

4) Personal Notes, a section for note keeping.


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Assistant Driller

Module



Program Guide Sheet- For the Participant

TRAINING PROCEDURE

You can expect to complete this module in about 6 working weeks, depending on the effort put in. Please tryto complete the module in the scheduled time.

Completion of the Task List is mandatory, and will be checked periodically by your Supervisor. The movies,reference books and workbook questions will help your understanding of the tasks. Your Supervisor may ask youto re-study any workbook material not fully understood. The Notes section is for any sketches or notes you mayfind helpful.

You must first finish the Task List requirements to your Supervisors satisfaction. Once the Task List iscompleted you will need to take the computer generated test using QMP. On successful completion of the testyour supervisor can then mark your LMS record for Completion of the module. The signed CNF is thenforwarded to the HQ in Dubai for Module certificate processing. The completed Task List is kept on file at yourlocation of assignment.

Note: The Assistant Driller Module Task List is the main component for measuring your progress. Completionof the training is indicated when all of the topics on the Task List are checked off by the Supervisor and theassessment is successfully completed.

Thanks for your interest and part ic ipat ion in the IPM M odular Training Program.


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Task List


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Revision 02ASSISTANT DRILLER MODULE Task Lists

Page: 01

Supervisor N ame: Rig #: Training SourceEmployee Name: Position:

Date

Comp

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Sign

Task #

General Safety Topics

1 Explain the Permit To Work System as it applies to the A.D. QHSE

ü ü 2 Describe the Company accident analyses and alerts systems. QHSE

ü ü 3 Explain the role of the Assistant Driller during emergency (including H2S, fire, man

overboard, abandon rig).

QHSE

ü ü 4 Conduct a pre-job (tool box) meeting. QHSE

ü ü 5 Participate in the pre spud meeting. QHSE

ü ü General Rig Floor

6 Explain the Assistant Driller's role in managing drill floor housekeeping.

ü 7 Show how to align standpipe manifold for testing, cementing and drilling.

ü ü


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Date

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Task #

General Rig Floor (cont.)8 Show how to maintain the drilling line fastline guide system. 7.11000

ü ü

DVD02.016

ü ü 9 Show how to inspect and change drawworks turnback rollers. 7.11000

ü ü

DVD02.016

ü ü 10 Explain and show how to rig up and down rotary hose.

ü ü 11 Show how to make up the single-shot (Totco) survey tool and explain the methods to run and

recover it.

2.01210

ü ü ü 12 Show how to service and repair the tong torque load cell on the tong arm.

ü ü Working With The Drill String

13 Show how to adjust the brake band equalizing bar.

ü ü 14 Show how to adjust and reset the crown block saver (Crown-O-Matic ).

ü ü ü


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Working With The Drill String (cont.)15 Show how to visually inspect drilling line. 7.11000

ü ü

DVD02.015

ü ü 16 Explain and show how to calculate ton-miles for the drilling line. 7.11000

ü ü ü 17 Explain drill ing line slip and cut procedures. 10.10010

ü ü ü 18 Explain how to identify washouts in drill string components.

ü ü 19 Show how to prepare BHA sheets and pipe tally.

ü ü 20 Explain and show how to prepare and fill out a trip sheet.

ü

DVD05.01

ü ü 21 Show how to compound tong lines for making up or breaking out tubulars requiring

high torque.

10.10010

ü ü ü 22 Show how to use a gauge ring for typical bits and stabilizers used on your rig.

ü ü


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Task #

Working With The Drill String (cont.)23 Show how to check for bit wear and assist with dull bit grading. 10.10010

ü ü ü 24 Show how to install, re-dress and remove a bit sub float valve.

ü ü 25 Show how to install and remove jets in typical bits.

ü ü 26 Show how to supervise a BHA handling operation on the drill floor.

ü ü 27 Identify and explain the use of typical fishing tools used on your rig.

ü ü

28 Explain and demonstrate how to dress an overshot.ü ü

29 Show how to identify and measure typical downhole tools and tubulars (including collars,stabilizers, jars, subs crossovers and, bit).

2.01210

ü ü ü


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Page: 05


Date

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Task #

Running and Cementing Casing30 Explain and show how to organize the drill floor for a casing job. 2.01210

ü ü ü 31 Explain and demonstrate the wear bushing retrieval operation.

ü ü 32 Show how to make up the casing shoe and float collar. 2.01210

ü ü ü 33 Explain and show how to test the shoe and float collar while running casing. 2.01210

ü ü ü 34 Show how to change power tong heads and tong dies.

ü ü 35 Explain how to dress and install the cementing head and secure high-pressure

chiksan lines or hose and test.

2.01210

ü ü ü Well Control and Related Equipment

36 Show how to perform daily checks on well control equipment such as IBOP and crossover(s),choke manifold, accumulator unit.

2.80040

ü ü ü


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Task #

Well Control and Related Equipment (cont.)37 Explain IPM shut in procedures while drilling. 2.80040

ü ü

DVD05.005

ü ü 38 Explain IPM shut in procedures while tripping. 2.80040

ü ü

DVD05.006

ü ü 39 Explain the diverter control system and diverter procedures . 2.80040

ü ü

DVD06.012

ü ü 40 Explain and show how to change and service BOP rams. 2.80040

ü ü ü 41 Explain and show how to change an annular BOP packing element. 2.80040

ü ü

ü

42 Explain and show how to nipple-up or nipple-down a surface BOP stack. 2.80040

ü ü ü 43 Show how to do a complete BOP and choke manifold pressure test. 2.80040

ü ü ü 44 Show how to do a complete IBOP and standpipe manifold pressure test 2.80040

ü ü ü


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Task #

Well Control and Related Equipment (cont.)45 Show how to calculate the space out.

ü

DVD02.004

ü ü 46 Show how to prepare a typical kick sheet and explain its significance.

ü

DVD02.004

ü ü 47 Explain the accumulator system operation (nitrogen precharge, useable fluid) and

assist with routine maintenance.

2.80040

ü ü

DVD02.004

ü ü Equipment Maintenance

48 Describe the Assistant Driller's role in the PM S system.

ü ü 49 Visually inspect and identify typical problems assoc iated with drawworks.

ü ü 50 Explain how to change out the swivel washpipe and show how to re-dress the spare.

ü ü 51 Show how to maintain and repair a standpipe gate valve.

ü ü


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Task #

Equipment Maintenance (cont.)52 Explain and assist in maintaining or repairing a choke manifold gate valves.

ü ü 53 Explain and assist in maintaining or repairing a manual and a remote operated choke.

ü ü 54 Show how to service and repair the hydraulic pressure load cell on the standpipe.

ü ü 55 Explain and show how to visually inspect the deadline anchor and the load cell. 7.11000

ü ü ü 56 Explain and show how to replace cathead lines and explain safety precautions.

ü ü

57 Visually inspect and identify typical problems associated with automated pipe handlingequipment (pipe racker, iron roughneck, pipe spinner). ü ü 58 Visually inspect and identify typical problems with crown block and traveling block assemblies.

ü ü 59 Visually inspect and identify typical problems with the top drive or kelly assembly.

ü ü


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Page: 09


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Task #

Working With The Drill String (cont.)60 Visually inspect and identify typical problems with mud treatment equipment.

ü ü 61 Visually inspect and identify typical problems with mud pumps.

ü ü 62 Show how to inspect and repair drill string full opening and non-return valves.

ü ü 63 Show how to inspect and repair a plug (lo-torq) valve.

ü ü 64 Show how to inspect and repair low-pressure mud system valves (butterfly, gate, and dump

valves). ü ü

65 Show how to prepare the drill floor for a typical completion job.ü ü

Operations on Floating Rigs66 Explain the running and retrieving procedures for the hang-off assembly.


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Operations on Floating Rigs (cont.)67 Explain and show how to supervise the drill floor for riser running / retrieving

operations. ü ü 68 Explain and show how to supervise moon pool area operations during BOP / riser

running or retrieval. ü ü 69 Assist in routine maintenance on the riser / guideline tensioner systems and explain

how it works. ü ü 70 Visually inspect and identify typical problems with drill string motion compensator.

ü ü Moving Operations on Land Rigs

71 Explain and show how to prepare for heavy lifts.

ü

ü

72 Show how to disassemble and reassemble the mast and substructure.

ü ü 73 Show how to reeve the drilling line over blocks, drawworks drum and deadline anchor.

ü ü


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Moving Operations on Land Rigs (cont.)74 Show how to rig down / up the standpipe manifold assembly and choke manifold.

ü ü 75 Show how to rig down / up the drawworks, rotary table, and drill floor sections.

ü ü 76 Show how to rig down / up Driller's console instrument panel.

ü ü 77 Explain and show how to supervise the rig down/up of mud pumps, discharge and suction

lines. ü ü 78 Explain and show how to supervise the rig down/up of mud tanks, low-pressure lines and solids

control equipment. ü ü

79 Explain and show how to supervise the rig down/up of the swivel and kelly or top drive.ü ü

Supervisory Skills 80 Show how to communicate and work with other departments and third party personnel.

ü ü


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Supervisory Skills

81 Assist the Driller in filling out the IADC drilling report.

ü ü 82 Explain the Assistant Driller's role in training crew members.

ü ü 83 Operate the Driller's drawworks controls during a routine trip, and under close supervision, for a

limited period. (cased hole sect ion)

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

ü ü


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Date

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Task #

Additional Rig Specific Topics


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Page: 14

Training Source Legend

Modular Training Reference Books & IPM Documents

Practical Hands-On

DVD Viewing

Instructions by Supervisors or Traveling Instructors

Computer Based Training

Referencing Required: ü

Referencing Not Required:

For the most effective learning it is better to use as many training sources as possible


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Tool List


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Section: 3 Page: 1


Assistant Driller

Module



Tool List

Reference Reference DVD In Trainin Room Date

Prerequisite: mandatory complet ion of Derrickman M odule

DVD 03.022 Solids Control Seminar Part -1

DVD 03.023 Solids Control Seminar Part- 2



DVD 06.012 Installation and Operation of Diverter Systems [Offshore Only]

DVD 02.015 Drilling Line Care and Maintenance part 1: Inspection and Cutoff

DVD 02.016 Drilling Line Care and Maintenance part 2: Equipment and String-up

DVD 02.017 Load Cells Care and Maintenance part 1: Field Servicing the Sensator

DVD 02.018 Load Cells Care and Maintenance part 2: Maintenance of Weight Indicator Head

DVD 05.001 Well Out Of Control Disaster

DVD 05.002 Anatomy of a Kill

DVD 05.003 OilWell Blowouts

DVD 05.004 Well Control - Early warnings of a Kick

DVD 05.005 Well Control - Kicks while Drilling

DVD 05.006 Well Control - Kicks while Tripping

DVD 05.007 Kicks : A Formula for Control

DVD 05.008 Well Control Calculations - Drillers Method .

DVD 05.009 Well Control Calculations- Wait & Weight Method .

DVD 05.010 Well Control Operations - Instructions on BOP Equipment

DVD 05.011 Koomey Control System, Identifying the Components

DVD 05.012 Koomey Control System, How it Works

DVD 05.025 Hydraulic Gate Valve

DVD 05.026 Manual Gate Valve

DVD 05.027 Fail Safe Closed Hydrulic Gate Valve

DVD 05.028 Maintaining The Hydril Annular BOP

DVD 05.029 Cameron Type D Annular BOP

DVD 05.030 NL Shaffer Spherical Type BOP

DVD 05.031 NL Shaffer Ram Type BOP’s

DVD 05.032 Hydril Ram Type BOP

DVD 05.033 Cameron Type U BOP

DVD 05.034 Cameron Type U BOP Inspection & MaintenanceDVD 05.035 Cameron Type U BOP Replacement of Leaking Seals

PETEX Cat.

Nos.

Reference Books In Training Room Date

2.80040 Practical Well Control

10.10010 IADC Drilling Manual

2.01210 Drilling Technology Series – Segment II : Drilling Operations

1.60040 Applied Mathematics for the Petroleum and Other Industries

2.30330 Rotary Drilling Blowout Prevention

7.11000 Drilling Line Care and Maintenance


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PETEX Cat.Nos.

Interactive CD-ROM Software In Training Room Date

7.30010 Oilwell Drilling: An Introduction, Vol.1, Rig Types and Basic Drill String Components

7.30020 Oilwell Drilling, Vol.2, Basic BOP Equipment

7.30030 Oilwell Drilling, Vol.3, Introduction to Drilling Fluids

7.30040 Oilwell Drilling, Vol.4, Mud Circulation and Treating Equipment

7.30050 Oilwell Drilling, Vol.5, Hoisting Equipment

7.30060 Oilwell Drilling, Vol.6, Rotating Equipment, Mast and Substructure

7.30070 Oilwell Drilling, Vol.7, Pipe Handling Equipment

7.30080 Oilwell Drilling, Vol.8, Casing and Cementing

7.30090 Oilwell Drilling, Vol.9, Well Logging, Mud Logging, and DST

7.30100 Oilwell Drilling, Vol.10, Power Systems and Instrumentation

71.10010 Inside BOP’s, Safety Valves and Kelly Cocks


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Workbook Questions


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Section: 4 Page: 1



Workbook 1


Modular Training ProgramRevision: 02

Applied Mathematics

W orkbook Quest ions

Refer to Applied Mathematics for the Petroleum and Other Industries. Each question has only one correct answer.

1. What is the capacity of a 12 ¼” hole in barrels per foot?

A. 0.1222 bbl/ftB. 0.1326 bbl/ ft 12.25”C. 0.1457 bbl/ftD. 0.1547 bbl/ft

2. What is the annular capacity of a 17 ½” hole with 5” Drill Pipe inside?

A. 0.2732 bbl/ftB. 0.1968 bbl/ftC. 0.1743 bbl/ftD. 0.0895 bbl/ft 5” 17.5”

3. What is the volume in barrels of a rectangular mud tank with the following dimensions?

Width =6 ½ feet, Length =18 ¼ feet, Height =10 feet

A. 211 bbl 6.5 ftB. 316 bblC. 663 bbl 10 ftD. 1048 bbl

18.25 ft

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 m

A. 117 m3 3.5mB. 738 bblC. answer A or BD. none of the above 4.3 m

7.8 m


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Workbook 1



Applied Mathematics

Workbook Quest ions

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

10 feet

10 feet 7.½ feet

24 feet

6. What is the area of an oval tank cover in square feet, with the following dimensions?Minor Axis =4 feet, Major axis =8 ½ feet

A. 106.8 ft2 8.5 feetB. 75.4 ft2 C. 49.3 ft2 D. 26.7 ft2 4 feet

7. Using the dimensions in question number 5, calculate the volume in barrels, of an oval tank 27 ½ feet

high?

A. 254 barrelsB. 162 barrelsC. 131 barrelsD. 85 barrels

8. What is the volume increase in barrels when raising the mud weight from 9.4 ppg to 10.6 ppg in a 1,400barrel system?

A. 256 bbl

B. 171 bblC. 110 bblD. 76 bbl


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Workbook 1



Applied Mathematics


9. How much water needs to be added to reduce the mud weight from 10.8 ppg to 9.5 ppg in a1,800 barrel mud system?

A. 2000 bblB. 1500 bblC. 1000 bblD. 500 bbl

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 bbls

B. 121 bbls 5118 feetC. 101 bbls 5” pipeD. 81 bbls ID 4 “

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? 239 feet8” drill collar

A. 780 bbls ID 2 ½ “B. 745 bblsC. 130 bblsD. 957 bbls

14. What is the height of the influx with a 20 bbl pit gain? 12 ¼ Hole w/ 10 ppg mud

A. 392 ftB. 239 ft

C. 223 ftD. 199 ft


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Workbook 2



Practical Well Control

Workbook Quest ions

Refer to PETEX Practical Well Control, Fourth Edition. Each question has only one correct answer.

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 ofthe fluids that fill the pore spaces in the rock. (Reference: Page 1-1)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. (Reference: Page 1-8)

3. 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 fromthe 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 (Reference: Page 2-5)C. 600 psiD. 683 psi

4. 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 holedry 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 (Reference Chapter 2 Page 2-5)D. 130 psi


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Workbook 2



Practical Well Control

Workbook Quest ions

5. 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 (Reference Page 4-2)

6. 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 (Reference Page 4-8)D. slow circulating rate pressure, drilling mud weight and final circulating pressure

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

A. one circulationB. two circulations (Reference Page 6-2)C. three circulations

D. four circulations

8. 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. (Reference Page 6-4)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 changingbottomhole 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. (Reference Page 9-6)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 psiprecharge is approximately:

A. 9 gallons.B. 7 gallons.

C. 5 gallons. (Reference Page 10-16)D. 3 gallons.


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Workbook 3



Kick Data and Gauges

Workbook Questions

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

WELL DATA

Well Depth 10,000 ft TVD11,500 ft MD

Bit size 8.5”

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

Drill Collars 61/2” x 213/16” x 750 ft

Capacity =0.00768 bbls/ft

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

Mud weight in use 12 ppg.

Pumps National triplex 12-P-160

With 61/2” LinersCapacity =0.117 bbls/stk

PUMP PRESSURE

While Drilling 2500 psi at 80 spm (APL =260 psi)

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

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/ft

WELL CONTROL DATA

SIDPP SIDPP =520 psiSICP =720 psiGAIN =12 bblsFRACTURE GRADIENT AT SHOE =.91psi/ft

Workbook Questions


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Workbook 3




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 bbls

B. 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 minutesB. 25 minutesC. 32 minutesD. 39 minutes

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

A. 58.5 minutesB. 49.7 minutesC. 60.3 minutesD. 51.5 minutes

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

A. 13.4 ppgB. 13.0 ppg

C. 12.4 ppgD. 16.4 ppg

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

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


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Workbook 3




Workbook Questions

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

A. approximately 800 psiB. approximately 390 psiC. approximately 500 psiD. approximately 270 psi

8. After reaching FCP it is decided to increase the pump speed to 40 spm. What would happen to BHP ifthe drill pipe 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?


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?



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Workbook 3




Workbook Questions

13. What is the approximate length of the influx?

A. 1027 ftB. 850 ftC. 653 ftD. 410 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. 1368 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. 874 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 108 minutesB. about 34 minutesC. about 214 minutesD. about 76 minutes


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Workbook 3




Workbook Questions

19. If the casing shoe is tested with 12 ppg mud in the hole, how much pressure is applied at the surface togive 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. 56 mins

D. 76 mins

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


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


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Workbook 3




Workbook Questions

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

100

200

300

400

500

600

700

800

9001000

1100

1200

1300

1400

1500

1600

1700

1800

1900 100

200

300

400

500

600

700

800

9001000

1100

1200

1300

1400

1500

1600

1700

1800

1900

OPEN CLOSECHOKE

POSITION

PSI PSI

TOTAL STROKES

DRILLPIPE PRESSURE

PUMP SPEED

CASING PRESSURE

60

30

770 720

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

A. open the choke a little

B. close the choke a littleC. increase the pump speedD. decrease the pump speedE. nothing everything looks alright

100

200

300

400

500

600

700

800

9001000

1100

1200

1300

1400

1500

1600

1700

1800

1900 100

200

300

400

500

600

700

800

9001000

1100

1200

1300

1400

1500

1600

1700

1800

1900

OPEN CLOSECHOKE

POSITION

PSI PSI

TOTAL STROKES

DRILLPIPE PRESSURE

PUMP SPEED

CASING PRESSURE30

770

300

750

25. The operation has been going for 10 minutes. What should you do?

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

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


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Workbook 3




Workbook Questions

100

200

300

400

500

600

700

800

9001000

1100

1200

1300

1400

1500

1600

1700

1800

1900 100

200

300

400

500

600

700

800

9001000

1100

1200

1300

1400

1500

1600

1700

1800

1900

OPEN CLOSECHOKE

POSITION

PSI PSI

TOTAL STROKES

DRILLPIPE PRESSURE

PUMP SPEED

CASING PRESSURE30

1000

750 850

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



100

200

300

400

500

600

700

800

9001000

1100

1200

1300

1400

1500

1600

1700

1800

1900 100

200

300

400

500

600

700

800

9001000

1100

1200

1300

1400

1500

1600

1700

1800

1900

OPEN CLOSECHOKE

POSITION

PSI PSI

TOTAL STROKES

DRILLPIPE PRESSURE

PUMP SPEED

CASING PRESSURE30

3000

770 950

27. Casing pressure is still slowly increasing. What are you going to do now?




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Workbook 3




Workbook Questions

100

200

300

400

500

600

700

80 0

9001000

1100

1200

1300

1400

1500

1600

1700

1800

1900 100

200

300

400

500

600

700

800

9001000

1100

1200

1300

1400

1500

1600

1700

1800

1900

OPEN CLOSECHOKE

POSITION

PSI PSI

TOTAL STROKES

DRILLPIPE PRESSURE

PUMP SPEED

CASING PRESSURE30

770

4750

520

28. The casing pressure has been reducing for the last few hundred strokes. How are things going?

A. open the choke a littleB. close the choke a littleC. increase the pump speedD. decrease the pump speed

E. good everything looks alright


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Workbook 4



Drilling Line Care and Maintenance

Workbook Questions

Refer to IPM Drilling Line Care and Maintenance workbook. Each question has only one correct answer.

Part I

1. Sharp corners, bad drum winding, loops in the line, or operating over small diameter sheaves, will cause whattype of damage?

A. crossover wearB. drum crush

C. 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 turn-back roller and starts a new layer.D. The line is overloaded.

3. Where does crossover wear occur?

A. at the dead man anchor

B. at the top of the crown block sheaves

C. at the bottom of the travelling block sheaves

D. 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 hole

B. the work needed to move one ton over a one mile distance

C. the maximum drawworks capacity

D. 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 inspection

B. depth of trip to be performed

C. weight of assembly to be tripped

D. how long until the end of the shift


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Workbook 4




Workbook Questions

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 cut off 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, dead line stabilizer, dead line anchor,wire line turn-backs

B. crown block, travelling block, drawworks, crown-o-matic, dead line stabilizer, wire line turn-backsC. crown block, travelling block, drawworks, dead line anchor, wire line turn-backsD. crown block, travelling block, crown-o-matic, dead line stabilizer, dead line anchor

10. How should wire line 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 line

C. with the base of the clip against the dead end of the lineD. both B and C

Part II

11. What needs to be reset after string up or cut off?

A. the Drillers brakeB. the drawworks auxilliary brakeC. the cown-o-maticD. none of the above


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Workbook 4




Workbook Questions

12. How much gap should the sensator have with empty blocks?

A. 5/8 inchB. 3/8 inchC. 4/16 inchD. none of the above

13. How often should the crown block sheaves be greased?

A. every 8 hoursB. after tripping onlyC. after 200 tonmilesD. daily

14. If you see a gap under the groove gauge, what is the most common cause?

A. The sheave is too smallB. The drilling line is too bigC. The sheave is worn too much, and should be replaced or re-groovedD. There is too much tar build-up on the sheave

15. 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

16. You should replace a turn-back when what wears out?

A. the drilling lineB. the rubber on the rollerC. the drawworks drumD. the crown block sheaves

17. What should be inspected on the drawworks?

A. damaged groovingB. wear platesC. wire line turn-backsD. all of the above


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Workbook 4




Workbook Questions

18. What should be attached to the derrick above the drawworks to prevent fast line flopping?

A. a wire line guideB. a dead line stabilizerC. a dead line anchorD. a turnback roller

19. Brass inserts can be replaced in what piece of equipment?

A. a wire line guideB. a dead line stabilizerC. a dead line anchorD. a turnback roller

20. How many wraps of line should be put on the drawworks with the travelling block at the lower pick uppoint?

A. 18.B. 16C. 12D. 8

Part III

21. What is the standard operating safety factor for drilling line?

A. SevenB. SixC. FiveD. Four

22. Where are the critical points of wear on the drilling line?

A. at the top of the crown block sheaves on pick up pointsB. at the bottom of the travelling block sheaves on pick up pointsC. at crossover points on drawworks and at the dead line anchorD. all of the above

23. 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


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Workbook 4




Workbook Questions

24. 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

25. What does the wire rope service curve explain?

A. the required safety factorB. the number of days between slip and cutsC. the relationship between safety factor and ton-mile goalsD. how much line to be cut off after slipping

Part IV

Refer to the ton-miles tables in the IADC Drilling Manual to answer questions 26 - 28.

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) 6 ½” x 2 ¾” Drill Collars, 5” 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

26. What is the excess weight allowance?

A. 45,900 lbsB. 35,900 lbsC. 25,900 lbsD. 15,900 lbs

27. How many ton-miles were incurred tripping?

A. 600B. 547C. 494D. 464

28. The trip before this involved 444 ton-miles tripping. How many ton-miles were used in drilling betweentrips?

A. 468B. 309C. 150D. 60


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Workbook 4




Workbook Questions

TON-MILES FORMULA – calculator method

Refer to the IADC Drilling Manual: Ton-Mile Calculations Section and use the calculation below to answer questions29 - 31.

T r = D ( Ls + D ) W m + D ( M + ½ 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 foot (101 lbs/ft) 6 ¾” x 2 ¾” Drill Collars, 5” 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

29. What is the excess weight allowance?

A. 60,000 lbsB. 50,000 lbsC. 40,000 lbsD. 30,000 lbs

30. How many ton-miles were incurred tripping?

A. 537B. 493C. 411D. 386

31. The trip before this involved 245 ton-miles tripping. How many ton-miles were used in drilling betweentrips?

A. 876

B. 744C. 498D. 423


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Workbook 5



Drilling a Straight Hole

Workbook Quest ions

Refer to PETEX Drilling Technology Series Segment II, Routine Drilling Operations: Drilling a Straight Hole. Somequestions have multiple answers.Sections: 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 5,000feet with a constant inclination from the vertical of 6°30'.

A. True vertical depth =4,968 feet; horizontal drift =566 feetB. True vertical depth =5,000 feet; horizontal drift =0 feetC. True vertical depth =99.36 feet; horizontal drift =11.32 feetD. True vertical depth =993.6 feet; horizontal drift =113.2 feet

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'

(8G°) (2I°)Direction: S 34° E Direction: S 9° EDepth: 6,400 feet Depth: 6,475 feet

A. Dogleg severity =7.82°/100 feetB. Dogleg severity =6.12°/100 feetC. Dogleg severity =5.87°/100 feetD. 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.


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Workbook 5




Workbook Quest ions

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 dogleg

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.

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 below, 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.


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Workbook 5




Workbook Quest ions

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 Deviation

15. When formation characteristics cause the wellbore to drift upstructure, the surface location canbe 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 requirementsare 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.

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.


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Workbook 5




Workbook Quest ions

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 thefollowing drilling conditions:

Hole size: 8I" Hole angle: 4°Hole class: R Drill collar size: 7"Formation dip: 15°

A. The driller can run 39,162 lb on the bit with the 7" drill collars and maintain hole angle.B. Bit weight can be increased to 68,500 lb if 7 1/2" 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 lb and adding a stabilizer 80 ft

above the bit.D. The driller can increase weight on bit to 46,200 lb 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 below, 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.


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Workbook 5




Workbook Quest ions

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 1 1/2" inches) 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 inzone 3 would be 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 topendulum or packed 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.


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Workbook 5




Workbook Quest ions

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 Tools

34. 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 lb.

35. How much does a standard-length drill collar weigh if it has a 5 1/2" OD and 2 1/4" ID?A. 67 lbB. 2,010 lbC. 6,700 lbD. 201.0 lb

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

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

A. 6,457 lbB. 68,500 lbC. 78,775 lbD. 96,775 lb

37. How many 7 ¼’" OD x 2 ¼” ID standard-length drill collars will be needed with the following drillingconditions?

Bit weight required: 32,440 lbDrilling mud density: 9.8 ppgSafety factor: 15%A. 14B. 12C. 8D. 7


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Workbook 5




Workbook Quest ions

38. If seven standard-length 6" OD x 2 13/16" ID drill collars are used, how many standard-length 7 ½”OD x 2 13/16” ID collars will be needed with the following conditions?

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

A. 24B. 14

C. 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

collars available 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.


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Workbook 5




Workbook Quest ions

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 hole out to gauge.

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 sand line.


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Workbook 6



Rig Hydraulics

Workbook Quest ions

Refer to PETEX Drilling Technology Series Segment II, Routine Drilling Operations: Rig Hydraulics. Some questionshave multiple answers.

Sections: Introduction and The Hydraulic System.

1. 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 betaken account 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 properbit has been selected for the drilling operation.

A. TrueB. False

4. Use the 10D2 rule to determine the input pump power for properly cleaning an 8 ½” hole.A. 80 hpB. 800 hpC. 810 hp

D. 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 constant

C. Increasing both fluid pressure and the fluid volumeD. Decreasing both fluid pressure and fluid volume at a slow but constant rate


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Workbook 6



Rig Hydraulics

Workbook Quest ions

7. What is the hydraulic horsepower produced by a pump that delivers 419 gpm at 2,330 psi? (Answersare rounded 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 is 90% efficient.A. 90 hpB. 570 hhpC. 518 hpD. 633 hp

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

D. 590.4 psi

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

Section: Pressure Losses in the System.

11. 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" ID; hose–55 ft with 3" ID; swivel–5 ft with 2 ¼” ID; kelly–40 ft with 3 ¼” ID.Circulation rate is 570 gpm with 10-ppg mud.A. 254 psiB. 91 psiC. 56 psi

D. 38 psi


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Workbook 6



Rig Hydraulics

Workbook Quest ions

13. If the surface equipment given in question 12 were used with 12.2-ppg mud and circulated at 540gpm, what pressure 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 collars separately 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: 4 ½ “ OD 2-inch bore, 8” ODWeight: 16.6 lb/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 and330 feet of drill collars?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 pressurefrom the pump.A. 33–47B. 50–75

C. 100D. none of the above


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Workbook 6



Rig Hydraulics


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 theminimum hhp needed at the bit (bhhp)?A. 342.5

B. 547.6C. 685D. 1,027.5

21. The drilling fluid undergoes a large pressure decrease and a great velocity increase at the bitnozzles.

A. TrueB. False

22. Pressure losses in the annulus are affected by—

A. size of drill string.B. circulation rate.C. size of 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 anycase, never less 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 Hydraulics.

25. 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.


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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 surfaceequipment and drill string–680 psi; circulation rate– 460 gpm; total hhp–564; surface pressure–2,100psi.

A. 377.8B. 685C. 247.1D. 381

28. A jet nozzle that measures 8/32 inch 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 thathas a circulation rate of 820 gpm and pressure available at the bit of 1,560 psi (assume 10-ppg mud). The appropriate 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

Sections: Annular Hydraulics and Designing the Rig Hydraulics Program.

32. 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.


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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: circulationrate– 420 gpm; drill pipe size–4" OD and 3.34" ID; hole size– 7 7/8”.

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. do all of the above.


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Drilling Muds

Workbook Quest ions

Refer to PETEX Drilling Technology Series Segment II, Routine Drilling Operations: Drilling Muds. Some questionshave multiple answers.

Sections: Introduction and Drilling Fluid Composition and Properties.

1. 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 commondrilling clay are needed 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.


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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 the continuous 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.

10. Inert solids in the drilling mud—A. .issolve 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. do all of the above.

Section: Functions of Drilling Fluids.

13. 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.


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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 Muds.

17. 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 than20,000 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.


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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 apH of 10?A. LigniteB. QuebrachoC. CMC

D. Lignosulfonate


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Workbook Quest ions

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 thedrilling fluid until the salt formation has been penetrated.

A. TrueB. False

Section: Water-Base Muds.

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 are true.

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


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35. Which of the following muds would be most effective in a drilling operation that encountersbottomhole temperatures 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 filtration

B. 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. Thev 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 Muds.

40. 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.


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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. do none of the above.

44. The amount of soap formed in an oil-base mud must be controlled because excessive amounts ofsoap can reduce 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).

4