DRILLING FLUIDS PROCESSING HANDBOOK free download

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CONTENTS
Biographies xvii
Preface xxiii
1 Historical Perspective and Introduction 1
1.1 Scope 1
1.2 Purpose 1
1.3 Introduction 2
1.4 Historical Perspective 4
1.5 Comments 11
1.6 Waste Management 13
2 Drilling Fluids 15
2.1 Drilling Fluid Systems 15
2.1.1 Functions of Drilling Fluids 15
2.1.2 Types of Drilling Fluids 16
2.1.3 Drilling Fluid Selection 17
2.1.4 Separation of Drilled Solids from Drilling Fluids 20
2.2 Characterization of Solids in Drilling Fluids 25
2.2.1 Nature of Drilled Solids and Solid Additives 25
2.2.2 Physical Properties of Solids in Drilling Fluids 26
2.3 Properties of Drilling Fluids 31
2.3.1 Rheology 32
2.4 Hole Cleaning 38
2.4.1 Detection of Hole-Cleaning Problems 38
2.4.2 Drilling Elements That Affect Hole Cleaning 40
2.4.3 Filtration 45
2.4.4 Rate of Penetration 47
2.4.5 Shale Inhibition Potential/Wetting Characteristics 51
2.4.6 Lubricity 52
2.4.7 Corrosivity 53
2.4.8 Drilling-Fluid Stability and Maintenance 54

2.5 Drilling Fluid Products 54
2.5.1 Colloidal and Fine Solids 54
2.5.2 Macropolymers 55
2.5.3 Conventional Polymers 56
2.5.4 Surface-Active Materials 57
2.6 Health, Safety, and Environment and Waste Management 58
2.6.1 Handling Drilling Fluid Products and Cuttings 58
2.6.2 Drilling Fluid Product Compatibility and Storage
Guidelines 58
2.6.3 Waste Management and Disposal 62
References 66
3 Solids Calculation 69
3.1 Procedure for a More Accurate Low-Gravity Solids
Determination 70
3.1.1 Sample Calculation 73
3.2 Determination of Volume Percentage of Low-Gravity Solids
in Water-Based Drilling Fluid 77
3.3 Rig-Site Determination of Specific Gravity of Drilled
Solids 78
4 Cut Points 81
4.1 How to Determine Cut Point Curves 85
4.2 Cut Point Data: Shale Shaker Example 90
5 Tank Arrangement 93
5.1 Active System 94
5.1.1 Suction and Testing Section 94
5.1.2 Additions Section 95
5.1.3 Removal Section 95
5.1.4 Piping and Equipment Arrangement 96
5.1.5 Equalization 98
5.1.6 Surface Tanks 99
5.1.7 Sand Traps 100
5.1.8 Degasser Suction and Discharge Pit 102
5.1.9 Desander Suction and Discharge Pits 102
5.1.10 Desilter Suction and Discharge Pits (Mud Cleaner/
Conditioner) 103
5.1.11 Centrifuge Suction and Discharge Pits 103
5.2 Auxiliary Tank System 104
5.2.1 Trip Tank 104
5.3 Slug Tank 105
5.4 Reserve Tank(s) 105

Scalping Shakers and Gumbo Removal 107
7 Shale Shakers 111
7.1 How a Shale Shaker Screens Fluid 113
7.2 Shaker Description 116
7.3 Shale Shaker Limits 118
7.3.1 Fluid Rheological Properties 119
7.3.2 Fluid Surface Tension 120
7.3.3 Wire Wettability 120
7.3.4 Fluid Density 120
7.3.5 Solids: Type, Size, and Shape 120
7.3.6 Quantity of Solids 121
7.3.7 Hole Cleaning 121
7.4 Shaker Development Summary 121
7.5 Shale Shaker Design 122
7.5.1 Shape of Motion 123
7.5.2 Vibrating Systems 133
7.5.3 Screen Deck Design 134
7.5.4 g Factor 136
7.5.5 Power Systems 140
7.6 Selection of Shale Shakers 143
7.6.1 Selection of Shaker Screens 145
7.6.2 Cost of Removing Drilled Solids 145
7.6.3 Specific Factors 146
7.7 Cascade Systems 148
7.7.1 Separate Unit 150
7.7.2 Integral Unit with Multiple Vibratory Motions 150
7.7.3 Integral Unit with a Single Vibratory Motion 152
7.7.4 Cascade Systems Summary 152
7.8 Dryer Shakers 153
7.9 Shaker User’s Guide 154
7.9.1 Installation 155
7.9.2 Operation 156
7.9.3 Maintenance 157
7.9.4 Operating Guidelines 158
7.10 Screen Cloths 159
7.10.1 Common Screen Cloth Weaves 160
7.10.2 Revised API Designation System 167
7.10.3 Screen Identification 174
7.11 Factors Affecting Percentage-Separated Curves 174
7.11.1 Screen Blinding 176
7.11.2 Materials of Construction 177
7.11.3 Screen Panels 178

13.3.5 Running Centrifuges in Series 318
13.3.6 Centrifuging Drilling Fluids with Costly Liquid
Phases 320
13.3.7 Flocculation Units 320
13.3.8 Centrifuging Hydrocyclone Underflows 321
13.3.9 Operating Reminders 321
13.3.10 Miscellaneous 321
13.4 Rotary Mud Separator 321
13.4.1 Problem 1 322
13.5 Solutions to the Questions in Problem 1 324
13.5.1 Question 1 324
13.5.2 Question 2 324
13.5.3 Question 3 324
13.5.4 Question 4 325
13.5.5 Question 5 325
13.5.6 Question 6 325
13.5.7 Question 7 325
13.5.8 Question 8 325
13.5.9 Question 9 326
13.5.10 Question 10 326
14 Use of the Capture Equation to Evaluate the Performance
of Mechanical Separation Equipment Used to Process
Drilling Fluids 327
14.1 Procedure 330
14.1.1 Collecting Data for the Capture Analysis 330
14.1.2 Laboratory Analysis 330
14.2 Applying the Capture Calculation 331
14.2.1 Case 1: Discarded Solids Report to Underflow 331
14.2.2 Case 2: Discarded Solids Report to Overflow 331
14.2.3 Characterizing Removed Solids 331
14.3 Use of Test Results 332
14.3.1 Specific Gravity 332
14.3.2 Particle Size 332
14.3.3 Economics 333
14.4 Collection and Use of Supplementary Information 334
15 Dilution 335
15.1 Effect of Porosity 337
15.2 Removal Efficiency 338
15.3 Reasons for Drilled-Solids Removal 339
15.4 Diluting as a Means for Controlling Drilled Solids 340
15.5 Effect of Solids Removal System Performance 341

WELL LOGGING AND FORMATION EVALUATION free download pdf

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INTRODUCTION

The purpose of this book is to provide a series of techniques which will
be of real practical value to petrophysicists in their day-to-day jobs. These
are based on my experience from many years working in oil companies.
To this end I have concentrated wherever possible on providing one recommended
technique, rather than offer the reader a choice of different
options.
The primary functions of a petrophysicist are to ensure that the right
operational decisions are made during the course of drilling and testing a
well—from data gathering, completion and testing—and thereafter to
provide the necessary parameters to enable an accurate static and dynamic
model of the reservoir to be constructed. Lying somewhere between
Operations, Production Geology, Seismology, Production Technology and
Reservoir Engineering, the petrophysicist has a key role in ensuring the
success of a well, and the characterization of a reservoir.
The target audience for this book are operational petrophysicists in their
first few years within the discipline. It is expected that they have some
knowledge of petroleum engineering and basic petrophysics, but lack
experience in operational petrophysics and advanced logging techniques.
The book also may be useful for those in sister disciplines (particularly
production geology and reservoir engineering) who are using the interpretations
supplied by petrophysicists.

CONTENTS
Introduction ix
1 Basics 1
1.1 Terminology 1
1.2 Basic Log Types 3
1.3 Logging Contracts 9
1.4 Preparing a Logging Programme 11
1.5 Operational Decisions 14
1.6 Coring 16
1.7 Wellsite Mud Logging 21
1.8 Testing/Production Issues 24
2 Quicklook Log Interpretation 29
2.1 Basic Quality Control 29
2.2 Identifying the Reservoir 30
2.3 Identifying the Fluid Type and Contacts 32
2.4 Calculating the Porosity 34
2.5 Calculating Hydrocarbon Saturation 37
2.6 Presenting the Results 40
2.7 Pressure/Sampling 42
2.8 Permeability Determination 45
3 Full Interpretation 49
3.1 Net Sand Definition 49
3.2 Porosity Calculation 51
3.3 Archie Saturation 53
3.4 Permeability 54
4 Saturation/Height Analysis 59
4.1 Core Capillary Pressure Analysis 60
4.2 Log-Derived Functions 64
5 Advanced Log Interpretation Techniques 67
5.1 Shaly Sand Analysis 67
5.2 Carbonates 73
5.3 Multi-Mineral/Statistical Models 74
5.4 NMR Logging 76
5.5 Fuzzy Logic 85
5.6 Thin Beds 87
5.7 Thermal Decay Neutron Interpretation 93
5.8 Error Analyses 96
5.9 Borehole Corrections 101
6 Integration with Seismic 103
6.1 Synthetic Seismograms 103
6.2 Fluid Replacement Modelling 108
6.3 Acoustic/Elastic Impedance Modelling 110
7 Rock Mechanics Issues 115
8 Value Of Information 119
9 Equity Determinations 125
9.1 Basis for Equity Determination 126
9.2 Procedures/Timing for Equity Determination 127
9.3 The Role of the Petrophysicist 129
10 Production Geology Issues 137
10.1 Understanding Geological Maps 140
10.2 Basic Geological Concepts 147
11 Reservoir Engineering Issues 155
11.1 Behavior of Gases 155
11.2 Behavior of Oil/Wet Gas Reservoirs 159
11.3 Material Balance 162
11.4 Darcy’s Law 163
11.5 Well Testing 166
12 Homing-in Techniques 171
12.1 Magnetostatic Homing-in 171
12.2 Electromagnetic Homing-in 185
13 Well Deviation, Surveying, and Geosteering 193
13.1 Well Deviation 193
13.2 Surveying 195
13.3 Geosteering 197
13.4 Horizontal Wells Drilled above a Contact 203
13.5 Estimating the Productivity Index for Long
Horizontal Wells 205
Appendix 1 Test Well 1 Data Sheet 207
Appendix 2 Additional Data for Full Evaluation 215
Appendix 3 Solutions to Exercises 218
Appendix 4 Additional Mathematics Theory 251
Appendix 5 Abbreviations and Acronyms 264
Appendix 6 Useful Conversion Units and Constants 268
Appendix 7 Contractor Tool Mnemonics 271
Bibliography 309
About the Author 313
Acknowledgments 314
Index 315

lecture 7 ( Downhole Motors)

 Downhole Motors

About this chapter

The positive-displacement mud motor (PDM) is the most indispensable tool at the DD’s

disposal. It is vital that the DD understand how to utilize the PDM to best advantage. The

basics of PDM design are covered in this chapter.

With the PowerPak mud motor, Anadrill has added a reliable and high-quality tool to its

range.

It is recommended that, in the short term, the DD be aware of the exact specifications of

"third party" PDMs which he may have to use.

PDM design, specifications, operating procedures, etc., are covered in this chapter. The

basics of steerable PDMs and steerable BHA design are also covered in this chapter.

Objectives of this Chapter

On completing this chapter the directional driller should be able to do the following

exercises:

1. Draw a diagram of a PDM, showing the major components. Describe the function

and purpose of each component.

2. Explain the main differences in construction between 1:2 lobe and multilobe PDMs.

3. Explain the uses of a rotor nozzle.

4. Describe what is meant by hydraulic thrust when using a PDM.

5. Explain the procedure involved in making up a PDM with a bent sub in a kickoff

BHA.

6. Describe the basic service which is done to a PDM after POOH, prior to laying it

down. Assume water-base mud.

7. Describe what precautions are necessary when drilling with a PDM.

8. Explain what surface indication(s) the driller has of PDM operation (and possible

problems) downhole.

9. Explain the main difference(s) in design between a straight PDM and a steerable

PDM.

10. Explain how an estimate is made of the buildup rate achievable with a bent-housing

steerable BHA.

11. Give examples of typical steerable BHAs designed to build inclination from vertical

to maximum angle and to hold this inclination until the next casing point.

12. Explain the effect the upper (string) stabilizer has on steerable BHA performance.