Theory and Technology of Drilling Engineering 9811593264, 9789811593260

Table of contents :
Preface
About This Book
Introduction
I
II
III
Contents
1 Engineering Geological Conditions for Drilling Operations
Abstract
1.1 Characteristics of Subsurface Pressures
1.1.1 Concepts of Various Subsurface Pressures
1.1.1.1 Hydrostatic Pressure
1.1.2 Underground Stress
1.1.2.1 Formation Pore Pressures
1.1.2.2 Matrix Stress
1.1.2.3 Mechanisms for Abnormal Formation Pressure
1.1.2.4 Pressure Transition Zone
1.1.2.5 Drilling Problems Associated with Abnormal Formation Pressures
1.1.3 Evaluation Methods for Formation Pressures
1.1.3.1 Prediction of Formation Pressure
1.1.3.2 Detection of Formation Pressures
1.1.4 Formation Fracture Pressure
1.1.4.1 The Hubbert and Willis Method
1.1.4.2 The Mathews and Kelly Method
1.1.4.3 The Eaton Method
1.1.4.4 The Rongzun Huang’s Method
1.1.4.5 Leak-off Test Method
1.1.5 Formation Collapse Pressure
1.1.5.1 Stress Distribution of Near Borehole in Vertical Wells
1.1.5.2 Formula for the Calculation of Formation Collapse Pressure in Vertical Wells
1.2 Rock Engineering Mechanical Properties
1.2.1 Mechanical Properties of Rock
1.2.1.1 Sedimentary Rock
1.2.1.2 Rock elasticity
1.2.1.3 Rock Strength
1.2.1.4 Rock Brittleness and Plasticity
1.2.1.5 Rock Hardness
Rock indentation hardness
1.2.2 Rock Mechanical Properties Under Bottomhole Pressure Conditions and Its Influencing Factors
1.2.2.1 Stress Status of Strata Rocks Around Wellbore
1.2.2.2 Influence of Various Pressure on Rock Performance at Bottom Hole
1.2.3 Rock Drillability and Abrasiveness
1.2.3.1 Rock Drillability
1.2.3.2 Rock Abrasiveness
2 Drilling Rigs and Tools
Abstract
2.1 Drilling Rig
2.1.1 Requirements of Drilling Technology to a Drilling Rig
2.1.1.1 The Capability of Rotary Drilling
2.1.1.2 The Capability of Tripping
2.1.1.3 The Capability of Wellbore Cleaning
2.1.2 The Primary Working System of a Drilling Rig
2.1.2.1 Hoisting System
2.1.2.2 Rotary System
2.1.2.3 Circulating System
2.1.2.4 Well Control System
2.1.2.5 Power and Transmission System
2.1.2.6 Monitoring and Control System
2.1.3 The Classifications and Characteristics of Drilling Rigs
2.1.3.1 Classifications of Drilling Rigs
2.1.3.2 Characteristics of Conventional Drilling Rigs
2.1.4 Series of Drilling Rigs
2.1.4.1 Basic Parameters of Drilling Rigs
2.1.4.2 Standard Series of Domestic Oil Drilling Rigs
2.2 Drill Bit
2.2.1 Summary
2.2.2 Roller Cone Bit
2.2.2.1 The Structure of Roller Cone Bit
2.2.2.2 The Rock-Breaking Principle of the Roller Cone Bit
2.2.2.3 The Selection and Reasonable Use of Roller Cone Bit
2.2.3 Diamond Bit
2.2.3.1 Diamond
2.2.3.2 The Structure and Design of the Diamond Bit
2.2.3.3 The Rock-Breaking Principle of the Diamond Bit
2.2.3.4 The Selection and Rational Use of Diamond Bits
2.2.4 PDC Bit
2.2.4.1 Polycrystalline Diamond Compact
2.2.4.2 The Structure and Design of PDC Bit
2.2.4.3 The Rock-Breaking Principle of PDC Bit
2.2.4.4 The Selection and Reasonable Use of the PDC Bit
2.3 Drill String
2.3.1 Function and Composition of Drill Sting
2.3.1.1 Functions of Drill Sting
2.3.1.2 Composition of Drill Sting
2.3.2 Working State and Force Analysis of the Drill String
2.3.2.1 Working State and Force Analysis During Tripping Process
2.3.2.2 Working State and Force Analysis During Drilling Process
2.3.2.3 Working State and Force Analysis During Other Special Drilling Processes
2.3.3 Design of Drill String
2.3.3.1 Size Selection of Drill String
2.3.3.2 Length Design of Drill Collar
2.3.3.3 Strength Design of Drill String
2.3.4 Examples of Typical Drill String Design
2.3.4.1 Design Datum
2.3.4.2 Design of Drill Collar String
2.3.4.3 Design of Drill Pipe String
3 Drilling Fluids
Abstract
3.1 Composition and Category of Drilling Fluids
3.1.1 Main Functions of Drilling Fluids
3.1.1.1 Remove Drill Cuttings from Well Bottom
3.1.1.2 Cool and Lubricate Drill Bit and String
3.1.1.3 Enhance Filtration Control and Maintain Wellbore Stability
3.1.1.4 Control Formation Pressure
3.1.1.5 Suspend Cuttings and Weighting Materials
3.1.1.6 Acquire Formation Data
3.1.1.7 Transmit the Hydraulic Power
3.1.2 Basic Composition of Drilling Fluids
3.1.3 Types of Drilling Fluids
3.1.3.1 Aqueous Drilling Fluids
3.1.3.2 Non-aqueous Drilling Fluid
3.1.3.3 Gaseous Drilling Fluid
3.2 Basic Properties of Drilling Fluids
3.2.1 Density of Drilling Fluid
3.2.2 The Rheological Properties of Drilling Fluid
3.2.2.1 Plastic Flow
3.2.2.2 Pseudo-Plastic Flow and Dilatant Flow
3.2.2.3 The Measurement of Rheological Parameter
3.2.2.4 The Relation of Mud Rheology with Drilling Engineering
3.2.3 The Filtration Properties of Drilling Fluid
3.2.3.1 Filtration Property
3.2.3.2 Concepts of Mud Filtration
3.2.3.3 Fluid Loss Agents and Their Function Mechanism
3.2.3.4 The Measurement of Fluid Loss and Technical Requirement
3.2.4 Solid Content and Control in Drilling Fluid
3.2.4.1 The Effect of Solid on ROP
3.2.4.2 Methods of Solid Control
3.2.4.3 Solid Control Equipment
3.2.4.4 Polymer Flocculants
3.2.5 The Lubrication Property of Drilling Fluid
3.2.6 Well Collapsing and Anti-collapsing Methods
3.2.6.1 Reasons for Wellbore Collapsing
3.2.6.2 Anti-collapsing Methods
3.2.7 Lost Circulation of Drilling Fluid and Plugging
3.2.7.1 Lost Circulation of Drilling Fluid
3.2.7.2 Lost Circulation Plugging
3.2.8 Pipe Sticking and Stuck Freeing
3.2.9 Drilling and Completion Fluids and Formation Protection
4 Drilling Parameters Optimization
Abstract
4.1 Basic Relationship Between Various Parameters in Drilling Process
4.1.1 Main Factors Affecting ROP
4.1.1.1 Effect of WOB on ROP
4.1.1.2 Effect of Rotational Speed on ROP
4.1.1.3 Effect of Tooth Wear on ROP
4.1.1.4 Effect of Hydraulic Factors on ROP
4.1.1.5 Effect of Drilling Fluid Performance on ROP
4.1.2 Drilling Rate Model
4.1.3 Bit Wear Equation
4.1.3.1 Tooth Wear Rate Model
4.1.3.2 Bearing Wear Rate Model
4.1.4 Determination of Related Coefficient in Drilling Equation
4.1.4.1 Threshold WOB and Rotational Speed Index
4.1.4.2 Determination of Formation Drillability Coefficient
4.1.4.3 Determination of Tooth Wear Coefficient C2
4.1.4.4 Determination of Rock Abrasive Coefficient Af
4.2 Optimization of Drilling Parameters for Mechanical Rock Breaking
4.2.1 Objective Function Establishment
4.2.2 The Extreme Condition and Constraint Condition of Objective Function
4.2.3 The Optimal Wear, ROP and WOB
4.2.3.1 Optimal Drill Bit Wear
4.2.3.2 Optimal Rotational Speed
4.2.3.3 Optimal WOB
4.3 The Optimal Design of Hydraulic Parameters
4.3.1 The Hydraulic Characteristics of Bits
4.3.1.1 Jet Flow and Its Impact on Hole Bottom
4.3.1.2 Hydraulic Parameters of Jet Flow
4.3.1.3 The Hydraulic Parameters of the Bit
4.3.2 The Basic Relation of Hydraulic Horsepower Transmissions
4.3.3 The Pressure Loss Calculation
4.3.3.1 The Basic Pressure Loss Equation
4.3.3.2 The Identification of Friction Coefficient
4.3.3.3 The Pressure Loss Equation of the Circulatory System
4.3.3.4 Methods to Improve the Hydraulic Parameters of Bits
4.3.4 The Working Performance of the Drill Pump
4.3.5 The Criteria of the Optimal Design of Hydraulic Parameters
4.3.6 The Maximum Bit Hydraulic Power
4.3.6.1 The Condition to Reach the Maximum Bit Hydraulic Power
4.3.6.2 The Variation of Bit Hydraulic Power with Flow rate and the Well Depth
4.3.6.3 Determination of the Optimal Nozzle Diameter
4.3.7 The Maximum Jet Impact Force
4.3.7.1 The Condition to Reach the Maximum Jet Impact Force
4.3.7.2 The Relationship Between the Maximum Jet Impact Force and Flow rate and Well Depth
4.3.7.3 The Determination of Optimal Nozzle Diameter
4.3.8 The Optimal Design of Hydraulic Parameters
4.3.8.1 The Minimum Flow rate Qa
4.3.8.2 The Pressure Loss Coefficient at Different Well Depth
4.3.8.3 Determination of the Size of Cylinder Liner
4.3.8.4 Computation and Determination of Optimal Flow rate, Optimal Nozzle Diameter and Hydraulic Parameters
5 Well Trajectory Design and Wellpath Control
Abstract
5.1 Fundamentals of Wellpath
5.1.1 Basic Parameters of Wellpath
5.1.2 Calculated Parameters of Wellpath
5.1.3 Graphical Methods of Wellpath
5.2 Wellpath Measurements and Calculations
5.2.1 Introduction to Wellpath Survey Methods and Inclinometer’s Principles
5.2.1.1 Measurement Principle of the Inclination by the Gravity Accelerator
5.2.1.2 Measurement Principle for the Azimuth by the Fluxgate
5.2.1.3 Calculations for Wellpath Parameters and Orientation Parameters
5.2.2 Regulations on Calculation Data of Wellpath Survey
5.2.3 Wellpath Calculation Methods
5.2.3.1 Process of Wellpath Calculation
5.2.3.2 Diversity of Wellpath Calculation Methods
5.3 Deviation Control for Vertical Wells
5.3.1 Analyzing the Reasons for Well Deflection
5.3.1.1 Geological Factors
5.3.1.2 Drilling Tools
5.3.1.3 Borehole Enlargement
5.3.2 Deviation Control by Packed-Hole BHA
5.3.2.1 Structure of YXY Packed-Hole BHA
5.3.2.2 Location Calculations for Middle Stabilizer on YXY Packed-Hole BHA
5.3.2.3 Notes for Packed-Hole Assembly
5.3.3 Deviation Control by Pendulum BHA
5.3.3.1 Principle of Pendulum BHA
5.3.3.2 Design for Pendulum BHA
5.3.3.3 Notes for Pendulum BHA
5.4 Well Trajectory Design for Directional Wells
5.4.1 Types of Directional Well Trajectory
5.4.2 Well Trajectory Design for Conventional 2D Directional Well
5.4.2.1 Design Principles
5.4.2.2 Types of Well Trajectory
5.4.2.3 Given Conditions for Well Trajectory Design
5.4.2.4 Calculations for Key Parameters
5.4.2.5 Calculations for Nodal Parameters and Interpretations for Design Results
5.5 Deflection Tools and Wellpath Control for Directional Well
5.5.1 Downhole Motor Deflection Tools
5.5.1.1 Types of Mud Motor Deflection Tool
5.5.1.2 Structures and Characteristics of Turbine Motor
5.5.1.3 Structures and Output Characteristics of PDM
5.5.2 Rotary Drilling Deflection Tools
5.5.2.1 Whipstocks
5.5.2.2 Jetting Bits
5.5.2.3 Stabilizer BHA
5.5.3 Steering Drilling System
5.5.3.1 Sliding Steering Drilling System
5.5.3.2 Rotary Steering Drilling System
5.5.4 Basic Methods for Directional Wellpath Control
5.5.4.1 Drilling the Vertical Section as Vertically as Possible
5.5.4.2 Strictly Control the Directional Deflection Operation
5.5.4.3 Track and Control the Wellpath Until the Target
5.5.5 Calculations for Azimuth Correction Run
5.5.5.1 Concept of Tool Face Angle
5.5.5.2 Calculations for Tool Face Angle
5.5.5.3 Calculations for Reactive Torque Angle of Mud Motor
5.5.6 Orientation Methods of Deflection Tool
6 Well Control
Abstract
6.1 Introduction
6.1.1 The Basic Conception of Well Control
6.1.2 The Balance Relationship of Wellbore Pressure and Formation Pressure
6.1.2.1 Fluctuating Pressure
6.1.2.2 The Pressure Increment with Cuttings Bearing in Drilling Fluid
6.1.2.3 The Effective Bottomhole Pressure {{\varvec p}}_{{{{\bf he}}}}
6.1.2.4 The Balance Relationship of Effective Bottomhole Pressure and Formation Pressure
6.2 The Invasion and Detection of Formation Fluid
6.2.1 The Invasion of Formation Fluid
6.2.1.1 The Classification of Formation Fluid
6.2.1.2 The Causes of Formation Fluid Invasion
6.2.1.3 The Formation Fluid Invasion Volume in Different Status
6.2.2 Gas Invasion
6.2.2.1 Kinds of Gas Invasion
6.2.2.2 Characteristics of Gas Invasion
6.2.2.3 Hazards of Gas Invasion
6.2.2.4 Pressure Changes After the Gas Invasion
6.2.3 Hazards of the H2S Gas
6.2.3.1 Physico-chemical Properties of H2S
6.2.3.2 Distribution of the H2S Gas
6.2.4 Causes and Indicators of Kick
6.2.4.1 Cause of Kick
6.2.4.2 Primary Indicators of a Kick
6.2.5 Detection of the Formation Fluid Invasion
6.2.5.1 Volume Detection Method for the Drilling Fluid
6.2.5.2 Flow Detection Method for Returning Drilling Fluid
6.2.5.3 Acoustic Wave Method of Kick Detection
6.2.5.4 Acoustic Wave Method of Total Loss Detection
6.2.5.5 Other Detections
6.3 Well Control Equipment
6.3.1 Functions of Well Control Equipment
6.3.2 Basic Components of Well Control Equipment
6.3.2.1 Wellhead BOP (Blowout Preventor) Stacks
6.3.2.2 Hydraulic BOP Control System
6.3.2.3 Well Control Manifolds
6.3.2.4 Inside BOP Tools
6.3.2.5 Well Control Instrumentation
6.3.2.6 Drilling Fluid Treatment Equipment
6.3.2.7 Special Operation Equipment
6.3.3 Common BOP Combination
6.3.3.1 BOP Combination with 14 MPa Pressure Rating
6.3.3.2 BOP Combination with 21 MPa Pressure Rating
6.3.3.3 BOP Combination with 35 MPa Pressure Rating
6.3.3.4 BOP Combination with 70 and 105 MPa Pressure Rating
6.3.4 Well Control Manifold
6.4 Well Shut-in
6.4.1 Shut-in
6.4.1.1 Shut-in Method and Selection
6.4.1.2 Shut-in Steps (Set Hard Shut-in as Example)
6.4.1.3 The Cautions During Well Shut-in
6.4.2 The Calculation of Drilling Fluid Density for Well Killing
6.4.2.1 The Mechanism of U-Tube Effect
6.4.2.2 Method of Reading Standpipe Pressure and Casing Pressure of Shut-in Well Without Inside BOP Tool Installed Inside the Drill String
6.4.2.3 Method of Reading Standpipe Pressure and Casing Pressure of Shut-in Well with Inside BOP Tool
6.5 Well Killing
6.5.1 Purpose and Principle of Well Killing
6.5.1.1 The Purpose of Well Killing
6.5.1.2 The Basic Principle of Well Killing
6.5.1.3 Maximum Allowable Shut-in Casing Pressure
6.5.1.4 The Process of Well Killing
6.5.2 Calculation of Basic Parameters of Well Killing
6.5.2.1 Calculation of Well-Killing Fluid Density
6.5.2.2 Calculation of Flow Rate for Well Killing
6.5.2.3 Variation Law of Standpipe Pressure During Well Killing
6.5.2.4 Time of Well-Killing Fluid Travelling from the Surface to the Bit
6.5.2.5 Time Required for Displacing the Annular Space with Killing Fluid
6.5.3 One-Circulation Well Killing Method
6.5.3.1 Characteristics
6.5.3.2 Operation Procedure
6.5.4 Two-Circulation Well-Killing Method
6.5.4.1 Characteristics
6.5.4.2 Operation Procedure
6.5.4.3 Comparison of Two Killling Methods
6.5.5 Special Killing Method
6.5.5.1 Volumetric Method
6.5.5.2 Bullhead Method
6.5.5.3 Snubbing Method
6.5.5.4 Dynamic Killing Method
6.5.5.5 Reverse Circulation Killing Method
6.6 Controlled Pressure Drilling
6.6.1 Underbalanced Drilling (UBD)
6.6.1.1 Definition of UBD
6.6.1.2 Technical Characteristics of UBD
6.6.1.3 Major Equipment of UBD
6.6.1.4 Application Conditions of UBD
6.6.1.5 Value of Underbalanced Pressure Differential
6.6.2 Gas Underbalanced Drilling
6.6.2.1 Definition of Gas Underbalanced Drilling
6.6.2.2 Technical Characteristics of Gas Underbalanced Drilling
6.6.2.3 Major Equipment of Gas Underbalanced Drilling
6.6.2.4 Conditions for Gas Underbalanced Drilling
6.6.3 Managed Pressure Drilling (MPD)
6.6.3.1 Definition of MPD
6.6.3.2 Technical Characteristics of MPD
6.6.3.3 Major Equipment of MPD
6.6.3.4 Key Conditions of MPD
7 Well Cementing and Completion
Abstract
7.1 Casing Program Design
7.1.1 Casing Types
7.1.2 The Principles of Casing Program Design
7.1.3 The Basis of Casing Program Design and the Relevant Basic Parameters
7.1.3.1 Basis of Casing Program Design
7.1.3.2 The Basic Parameters and the Range of Corresponding Value
7.1.4 The Methods of Casing Program Design
7.1.4.1 The Constraint Conditions of Safe Open-Hole Section
7.1.4.2 The Bottom-up Method and Steps of Casing Program
7.1.5 Size Selection and Coordination of Casing and Wellbore
7.1.5.1 Factors Considered in the Selection and Matching of Casing and Wellbore Size
7.1.5.2 The Standard Combination of Casing and Wellbore Size
7.2 Casing String Strength Design
7.2.1 Casing and Casing String
7.2.2 The Calculation of Casing String Loadings and Strengths, and Casing Erosion
7.2.2.1 The Calculation of Casing String Loadings
7.2.2.2 Casing Strength
7.2.2.3 Casing Erosion
7.2.3 The Design Principles of Casing Strength
7.2.3.1 Common Design Methods of Casing String Strength
7.2.3.2 The Design Features of Each Casing Level
7.2.3.3 The Equal Safety Factor Method
7.3 Cementing Technology
7.3.1 Oil Well Cement
7.3.1.1 Basic Requirements and Manufacturing Process of the Oil Well Cement
7.3.1.2 Main Compounds of the Oil Well Cement
7.3.1.3 The Hydration of Oil Well Cement
7.3.1.4 The API Class of the Oil Well Cement
7.3.2 Cement Properties and Performance Requirements
7.3.2.1 Slurry Density
7.3.2.2 Thickening Time
7.3.2.3 The Cement Slurry Lost Circulation
7.3.2.4 The Setting Time of Cement Slurry
7.3.2.5 Rheology of Cement Slurries
7.3.2.6 The Stability of Cement Slurries
7.3.2.7 Strength Characteristics of Set Cement
7.3.2.8 The Permeability of Set Cement
7.3.2.9 The Corrosive Resistance of Set Cement
7.3.3 Cement Additives and Mechanisms of Action
7.3.3.1 Density Modifiers—Weighting Agents and Lightening Agents
7.3.3.2 Thickening Time Modifiers—Accelerators and Retarders
7.3.3.3 Fluid Loss Control Agents
7.3.3.4 Dispersants
7.3.3.5 Lost Circulation Prevention Agents
7.3.3.6 Antifoam Agents
7.3.3.7 Early Strength Agent
7.3.3.8 Expansion Agent
7.3.3.9 Strengthening Agents
7.3.4 Cementing Design and Well Cementation Technology
7.3.4.1 Well Cementation String Structure
7.3.4.2 Cementing Design
7.3.4.3 Conventional Well Cementation Work Flow Well Cementation Characteristics
7.3.4.4 Commonly Used Well Cementation Technology
7.3.5 Procedures to Improve Well Cementing Quality
7.3.5.1 Basic Requirements to Ensure Well Cementing Quality
7.3.5.2 Prevent Channeling-Improve the Displacement Efficiency of Cement Slurry
7.3.5.3 Oil, Gas, and Water Channeling Problem in the setting Process of the Cement Slurry
7.3.6 Special Cement Slurry System
7.3.6.1 High-Density Cement Slurry System
7.3.6.2 Low-Density Cement Slurry System
7.3.6.3 High-Temperature-Resistant Cement Slurry System
7.3.6.4 Low-Temperature Cement Slurry System
7.3.6.5 Thixotropic Cement Slurry System
7.3.6.6 Anti-corrosion Cement Slurry System
7.4 Well Completion Technique
7.4.1 Drilling Through Reservoir
7.4.1.1 Change of Oil-Storage Properties When Drilling Through Reservoir
7.4.1.2 Changes of Rock Mechanical Properties When Drilling Through Reservoir
7.4.1.3 Methods for Drilling Reservoir
7.4.2 Principle of Well Completion and Types of Bottomhole Structure in Oil–Gas Well
7.4.2.1 Principles of Well Completion
7.4.2.2 Types of Bottomhole Structure
7.4.3 Common Methods for Well Completion
7.4.3.1 Open-Hole Completion Method
7.4.3.2 Perforation Completion
7.4.3.3 Slotted Liner Completion
7.4.3.4 Well Completion with Packer
7.4.3.5 Sand Control Completion
7.4.4 Special Well Completion
7.4.4.1 Completion Method for Horizontal Wells
7.4.4.2 Completion of Wells in Tight and Fractured Reservoirs
7.4.5 Wellhead Equipment for Completion Operation
7.4.5.1 Casing Head
7.4.5.2 Tubing Head
7.4.5.3 Christmas Tree
8 Other Drilling Techniques and Operations
Abstract
8.1 Handling of Complicated Downhole Conditions and Accidents
8.1.1 Uncontrolled Blowout and the Handling Procedures
8.1.1.1 Causes of Blowout
8.1.1.2 Handling of Out-of-Control Blowout
8.1.2 Lost Circulation and the Handling Procedures
8.1.2.1 Causes of Lost Circulation
8.1.2.2 Types of Lost Circulation
8.1.2.3 Handling of Lost Circulation
8.1.3 Sticking and Its Handling
8.1.3.1 Types, Causes, and Prevention of Sticking
8.1.3.2 Handling of Sticking
8.1.4 Drilling Tool Accidents and the Handling Procedures
8.1.4.1 Common Drilling Tool Accidents
8.1.4.2 Handling of Drilling Tool Accidents
8.1.5 Junk Accidents and Their Handling
8.1.5.1 Common Junk Accidents
8.1.5.2 Handling of Junk Accidents
8.2 Coring Technique
8.2.1 Introduction
8.2.1.1 Purpose of Coring
8.2.1.2 Processes of Core Drilling
8.2.1.3 Evaluation Index of Core Drilling
8.2.2 Coring Tools
8.2.2.1 Compositions of Coring Tools
8.2.2.2 Classification of Coring Tools
8.2.2.3 Conventional Coring Tool
8.2.2.4 Special Coring Tool
8.2.3 Enhance Core Recovery
8.2.3.1 Factors on Core Recovery
8.2.3.2 Measures to Enhance Core Recovery
8.3 Casing Sidetracking Technique
8.3.1 Sidetracking Through Casing by Whipstock
8.3.1.1 Construction Procedures of Simple Window-Cutting Tools
8.3.1.2 Construction Procedures of Fixed-Anchor Sidetracking Tools
8.3.1.3 Construction Procedures of Ground Anchor with Slip Packer Sidetracking Tools
8.3.2 Casing Sidetracking by Expanded Casing Mill Shoe
References

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