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"Drilling Fluid Engineering" by Pål Skalle



"Drilling Fluid Engineering" by Pål Skalle
BoBoCoAe, PS & Ventus Publishing ApS | 2011 | ISBN: 8776819293 9788776819293 | 132 pages | PDF | 7 MB

This book presents how to apply fluid mechanics on drilling fluid related challenges and explains the related physics involved and the different engineering approaches.

Mud has many functions, the single most important one is to remove the cuttings a) away from under the bit and b) transport them from the bottom to the surface. Viscosity of drilling fluids is not a constant parameter; it varies with shear rate. Pipe, rock bit and annular friction pressure loss has high importance for several tasks. Stable wellbore includes many sub tasks like chemical stability and filtration control.


Content
1 Introduction
1.1 Nine distinct mud systems
1.2 The five main tasks of a drilling fluid
1.3 About this book
2 Mud circulation loop and its components
2.1 The mud loop and solids control
2.2 The mud pump
3 Drilling fluid viscosity control
3.1 Clay chemistry
3.2 Polymer chemistry
3.3 Rheology of drilling fluids
3.4 Additives
4 Hydraulic friction in the circulating system
4.1 Head loss
4.2 Laminar flow
4.3 Turbulent pipe flow
4.4 Singularity losses
5 Removal of cuttings from under the bit
5.1 Cuttings removal process
5.2 Boundary conditions of the drilling process
5.3 General
5.3 Optimizing ROP, liner by liner
5.4 Optimizing the complete well
6 Transport of cuttings to the surface
6.1 Hole cleaning in vertical wells
6.2 Hole cleaning in inclinded wells
7 Keeping wellbore within maximum and minimum pressure; ECD-control
7.1 Density control
7.2 ECD factors
7.3 Temperature variation
8 Keeping the wellbore stable
8.1 Introduction
8.2 Filtration control
8.3 Mechanical stability
8.4 Chemical stability
8.5 Hole problems
8.6 Inhibitive mud
8.7 Countermeasures to hole problems
9 References
10 Supportive information
10.1 Nomenclature
10.2 Abbreviations and explanations
10.3 Definitions
10.4 Continuity, momentum and energy equation in microscopic and macroscopic form
10.5 Hydraulic friction loss equations
10.6 Determine Rheological Constants – Regression Analysis
10.7 Unit conversion factors
10.8 Viscosity and density of water vs. temperature
with TOC BookMarkLinks

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"Drilling Fluid Engineering: Exercises" by Pål Skalle


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"Drilling Fluid Engineering: Exercises" by Pål Skalle
BoBoCoAe, PS & Ventus Publishing ApS | 2011 | ISBN: 8776818654 9788776818654 | 101 pages | PDF | 6 MB

This is the exercise book accompanying Drilling Fluid Engineering. This book presents how to apply fluid mechanics on drilling fluid related challenges and explains the related physics involved and the different engineering approaches.

The content has the understanding of the physics and mathematics of the processes in focus. Practical applications have also priority, but come after the physics.
Most of the exercises have been solved by students in the corresponding course at the Department of Petroleum Engineering and Applied Geophysics at NTNU of Trondheim.

Content
Preface
1 Fluid Properties
1.1 Filter loss control
1.2 Filter loss control
1.3 Filter loss control
1.4 Filter loss control
1.5 Density control
1.6 Density control
1.7 Density control
1.8 Density control
1.9 Rheology control
1.10 Rheology control
1.11 Rheology - control
1.12 Flocculation
1.13 Mud contamination
1.14 Flocculation
1.15 Fluid additives
1.16 Fluid Additives. Drag reducer
1.17 Fluid additives
1.18 Fluid additive
2 Rheological models
2.1 Bingham
2.2 Bingham/ Power law
2.3 Bingham/Power law
2.4 Bingham / Power law. Regression
2.5 Effective viscosity
2.6 All models
2.7 All models. Regression
2.8 All models
3 Drilling fluid dynamics
3.1 Velocity profile. Continuity equation
3.2 Velocity profile. Momentum flux
3.3 Velocity profile
3.4 Pressure loss vs. rheology
3.5 Pressure loss vs. rheology
3.6 Pressure loss. Power law
3.7 Pressure loss. Turbulent. Energy equation
3.8 Pressure loss vs. flow rate
3.9 Pressure loss. Field data
3.10 Pressure loss. Nozzles.OFU
3.11 Swab pressure. Cling factor
4 Hydraulic program
4.1 Mud pump issues
4.2 Parasitic pressure
4.3 Optimal nozzles? Section wise
4.4 Liner selection. Section wise
4.5 Optimal parameters for BHHP. OFU. Section wise
4.6 Hydraulic program. Section wise
4.7 Liner selection. Complete well
4.8 Liner selection. Complete well
5 Well challenges
5.1 ECD. Cuttings concentration
5.2 ECD. Solids control
5.3 ECD. Barite
5.4 ECD. Flow rate and fluid consistency
5.5 ECD. Temperature change
5.6 Water activity
5.7 Water activity
5.8 Shale stability
5.9 Clay behavior
5.10 Wellbore problem
6 Additional information
6.1 Pump and hydraulic program data
6.2 Fluid mechanic
6.3 Conversion factors

Solutions to Exercises in Drilling Fluid Engineering
1 Fluid Properties
1.1 Fluid loss control
1.2 Filter loss control
1.3 Filter loss control
1.4 Filter loss control
1.5 Density control
1.6 Density control
1.7 Density control
1.8 Density control
1.9 Rheology control
1.10 Rheology control
1.11 Rheology control
1.12 Flocculation
1.13 Mud contamination
1.14 Flocculation
1.15 Fluid additives
1.16 Drag reducer
1.17 Fluid additives
1.18 Fluid additives
2 Rheological models
2.1 Bingham
2.2 Bingham / Power law
2.3 Bingham / Power law
2.4 Bingham / Power law. Regression
2.5 Effective viscosity
2.6 All models
2.7 All models. Regression
2.8 All models
3 Drilling fluid dynamics
3.1 Velocity profile. Continuity equation
3.2 Velocity profile. Momentum flux
3.3 Flow profile
3.4 Pressure loss vs. rheology
3.5 Pressure loss vs. Rheology
3.6 Pressure loss. Power law
3.7 Pressure loss. Turbulent flow. Energy equation
3.8 Pressure loss vs. flow rate
3.9 Pressure loss. Field data
3.10 Pressure loss. Bit nozzle. OFU
3.13 Swab pressure. Clinging factor
4 Hydraulic program
4.1 Mud pump issues
4.2 Parasitic pressure
4.3 Nozzle selection. Section wise
4.4 Liner selection. Section wise
4.5 Optimal parameters with BHHP. OFU. Section wise
4.6 Hydraulic program. Section wise
4.7 Liner selection. Complete well
4.8 Liner selection. Complete well
5 Wellbore challenges
5.1 ECD. Cuttings concentration
5.2 Solids control
5.3 ECD. Barite
5.4 ECD. Flow rate + fluid consistency
5.5 ECD. Temperature influence
5.6 Water activity
5.7 Water Activity
5.8 Shale stability
5.9 Clay behavior
5.10 Wellbore problems
with TOC BookMarkLinks

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"Pressure Control During Oil Well Drilling" by Pål Skalle



"Pressure Control During Oil Well Drilling" by Pål Skalle
BoBoCoAe, PS & Ventus Publishing ApS | 2011 | ISBN: 8776819415 9788776819415 | 118 pages | PDF | 11 MB

This book aims at explaining the physics and the engineering approaches behind pressures in the sediments, detection of unstable wellbores, equipments necessary to close and kill the well, killing methods and offshore challenges.

Porous sedimentary formations penetrated by the rock bit contain fluids such as oil, gas or salt water. If the hydrostatic pressure of the drilling fluid drops below the formation pore pressure, pore fluid will enter the well and “kick” the mud out of the well. To control the pressure while drilling you need to understand the behavior of gas.

The book was revised and updated in 2011, mostly on basis of input from readers.

Contents
1 Introduction
1.1 The drilling process
1.2 Geological sediments
1.3 About Pressure Control in sedimentary rocks
1.4 Principle of barriers and safety aspects
1.5 Scope of this book
2 Pressure in the sediments
2.1 Sedimentary pressure prediction models
2.2 Quantifying formation pressure
3 Well Control Equipment
3.1 BOP stack and associated equipment
3.2 Remote control of the BOP
3.3 Volumetric unstable well (kicking well)
3.4 Closing procedure during drilling operations
3.5 Well barriers during drilling operations
4 Standard killing methods
4.1 Surface and bottom pressure of a shut in well
4.2 Hydraulic friction during killing
4.3 Killing by means of Driller's Method
4.4 The Engineer's Method and kill sheet
4.5 Killing when unable to circulate from bottom
5 Modification of the standard killing method
5.1 Modification due to narrow pressure window
5.2 Killing with irregular drill string geometry
5.3 Best practice while drilling through narrow pressure windows.
6 More realistic gas behavior
6.1 Transport of gas
6.2 Wellbore pressure during two phase flow.
6.3 Gas solubility
7 Special offshore safety issues
7.1 Low sea temperature
7.2 Other deep water problems
7.3 Shallow sands below deep sea water
8 Gas migration through cement
8.1 The cement slurry
8.2 Cementing operations
8.3 Gas migration
References
Nomenclature
Abbreviations
Unit conversion factors
with TOC BookMarkLinks

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"Pressure Control During Oil Well Drilling: Exercises" by Pål Skalle

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"Pressure Control During Oil Well Drilling: Exercises" by Pål Skalle
BoBoCoAe | 2011 | ISBN: 8776818890 9788776818890 | 100 pages | PDF | 6 MB

These exercises have been made to fit the content of the book "Pressure Control During Oil Well Drilling". This book aims at explaining the physics and the engineering approaches behind pressures in the sediments, detection of unstable wellbores, equipments necessary to close and kill the well, killing methods and offshore challenges.

If the hydrostatic pressure of the drilling fluid drops below the formation pore pressure, pore fluid will enter the well and “kick” the mud out of the well. To control the pressure while drilling you need to understand the behavior of gas.

Many of the exercises in present book have been solved by students in the corresponding course at the Department of Petroleum Engineering and Applied Geophysics at NTNU of Trondheim, Norway.

Contents
Preface
1 Formation Pressure
1.1 High pore pressure zone
1.2 High pore pressure zone
1.3 High pore pressure zone
1.4 High pore pressure zone
1.5 Porosity. Overburden. Sonic log
1.6 Porosity. Overburden. Sonic
1.7 Pore pressure detection. General
1.8 Pore Pressure. ROP
1.9 Pore pressure detection. Sonic
1.10 Pore pressure, d
1.11 Pore pressure detection, d Overlay curves
1.12 Fracture pressure. LOT
1.13 Fracture pressure. LOT
1.14 Fracture pressure from field data
1.15 Casing setting depth
2 Killing operation
2.1 Avoid kick
2.2 BOP issues
2.3 Prepare for kick. SCR and Shut In Pressure
2.4 Riser margin
2.5 Kick tolerance
2.6 Kill sheet. W&W. Conventional
2.7 Driller's. Conventional
2.8 Engineer's method. Conventional. Pressure in 3 situations
2.9 Driller's. Conventional. Pressure in 6 situations
2.10 Killing. Fracturing. W&W. Conventional
2.11 Killing. Fracturing. W & W. Conventional
2.12 Is conventional killing acceptable?
2.13 Killing operation. Modified for choke line friction.
2.14 Conventional vs. modified for high choke line friction
2.15 Kill sheet. Driller's modified for choke line friction
2.16 Engineer's. Modified for annular friction. Pressure in situation # 2 and 3
2.17 Modified for choke line friction. Stop in operation
2.18 Modified for more realistic drill string.
2.19 Modified for more realistic drill string
2.20 Modified vs. volumetric
2.21 Volumetric
2.22 Volumetric method
2.23 Comparing 3 Killing methods. Modified
2.24 Killing a gas well
3 Gas behaviour
3.1 Gas transport (percolation)
3.2 Gas transport
3.3 Wellbore pressure during 2-phase flow
3.4 Wellbore pressure during 2-phase flow. Task 2008 - 7
3.5 Gas solubility
3.6 Gas solubility
4 Deep water and cementing issues
4.1 Cold water issues
4.2 Shallow Water flow
4.3 SWF
4.4 Deep water issues
4.5 Cementing in general
4.6 Cementing problem (onshore)
4.7 Gas migration during cementing
Solutions - Pressure control
1 Formation pressure
1.1 High pore pressure zone
1.2 High Pore pressure zone
1.3 High pore pressure zone
1.4 High formation pressure zone
1.5 Porosity. Overburden. Sonic log
1.7 Pore pressure detection. General
1.8 Pore Pressure. ROP
1.9 Pore pressure detection. Sonic
1.10 Pore pressure, d£
1.11 Pore pressure detection. d£ overlay curve
1.12 Fracture pressure. LOT
1.13 Fracture pressure. LOT
1.14 Fracture pressure from field data
1.15 Casing setting depth in well 34/10-11.
2 Conventional and modified p-control
2.1 Avoid kick.
2.2 BOP - issues
2.3 SCP and shut in pressure
2.4 Riser margin
2.5 Kick tolerance
2.6 Kill sheet. W & W. Conventional
2.7 Killing. Fracturing. Driller's. Conventional
2.8 Engineer's. Conventional. Pressure in 3 situations
2.9 Driller's. Conventional. Pressure in 6 situations
2.10 Killing. Fracturing. W&W Conventional
2.11 Killing. Fracturing. W & W. Conventional
2.12 Is conventional killing acceptable?
2.13 Killing operations. Modified for choke line friction
2.14 Conventional vs. Modified for high choke line friction
2.15 Kill sheet. Driller's modified for choke line ular friction
2.16 Engineer's. Modified for annular friction
2.17 Modified for choke line friction. Stop in operation
2.18 Modified for more realistic drill string
2.19 Modified for more realistic drill string.
2.20 Modified vs. volumetric p-control
2.21 Volumetric
2.22 Volumetric
2.23 Comparing 3 Killing methods. Modified
2.24 Killing a gas well
3 Gas behavior
3.1 Gas transport (percolation)
3.2 Gas transport
3.3 Wellbore pressure during 2-phase flow
3.4 Gas solubility
3.5 Gas solubility
4 Deep water and cementing issues
4.1 Cold water issues
4.2 SWF
4.3 SWF
4.4 Deep water issues
4.5 Cementing in general
4.6 Cementing problem (onshore)
4.7 Gas migration during cementing
with TOC BookMarkLinks

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"Drilling Fluid Engineering" by Pål Skalle



"Drilling Fluid Engineering" by Pål Skalle
BoBoCoAe, PS & Ventus Publishing ApS | 2011 | ISBN: 8776819293 9788776819293 | 132 pages | PDF | 7 MB

This book presents how to apply fluid mechanics on drilling fluid related challenges and explains the related physics involved and the different engineering approaches.

Mud has many functions, the single most important one is to remove the cuttings a) away from under the bit and b) transport them from the bottom to the surface. Viscosity of drilling fluids is not a constant parameter; it varies with shear rate. Pipe, rock bit and annular friction pressure loss has high importance for several tasks. Stable wellbore includes many sub tasks like chemical stability and filtration control.


Content
1 Introduction
1.1 Nine distinct mud systems
1.2 The five main tasks of a drilling fluid
1.3 About this book
2 Mud circulation loop and its components
2.1 The mud loop and solids control
2.2 The mud pump
3 Drilling fluid viscosity control
3.1 Clay chemistry
3.2 Polymer chemistry
3.3 Rheology of drilling fluids
3.4 Additives
4 Hydraulic friction in the circulating system
4.1 Head loss
4.2 Laminar flow
4.3 Turbulent pipe flow
4.4 Singularity losses
5 Removal of cuttings from under the bit
5.1 Cuttings removal process
5.2 Boundary conditions of the drilling process
5.3 General
5.3 Optimizing ROP, liner by liner
5.4 Optimizing the complete well
6 Transport of cuttings to the surface
6.1 Hole cleaning in vertical wells
6.2 Hole cleaning in inclinded wells
7 Keeping wellbore within maximum and minimum pressure; ECD-control
7.1 Density control
7.2 ECD factors
7.3 Temperature variation
8 Keeping the wellbore stable
8.1 Introduction
8.2 Filtration control
8.3 Mechanical stability
8.4 Chemical stability
8.5 Hole problems
8.6 Inhibitive mud
8.7 Countermeasures to hole problems
9 References
10 Supportive information
10.1 Nomenclature
10.2 Abbreviations and explanations
10.3 Definitions
10.4 Continuity, momentum and energy equation in microscopic and macroscopic form
10.5 Hydraulic friction loss equations
10.6 Determine Rheological Constants – Regression Analysis
10.7 Unit conversion factors
10.8 Viscosity and density of water vs. temperature
with TOC BookMarkLinks

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zidaan قال:
"Drilling Fluid Engineering" by Pål Skalle



"Drilling Fluid Engineering" by Pål Skalle
BoBoCoAe, PS & Ventus Publishing ApS | 2011 | ISBN: 8776819293 9788776819293 | 132 pages | PDF | 7 MB

This book presents how to apply fluid mechanics on drilling fluid related challenges and explains the related physics involved and the different engineering approaches.

Mud has many functions, the single most important one is to remove the cuttings a) away from under the bit and b) transport them from the bottom to the surface. Viscosity of drilling fluids is not a constant parameter; it varies with shear rate. Pipe, rock bit and annular friction pressure loss has high importance for several tasks. Stable wellbore includes many sub tasks like chemical stability and filtration control.


Content
1 Introduction
1.1 Nine distinct mud systems
1.2 The five main tasks of a drilling fluid
1.3 About this book
2 Mud circulation loop and its components
2.1 The mud loop and solids control
2.2 The mud pump
3 Drilling fluid viscosity control
3.1 Clay chemistry
3.2 Polymer chemistry
3.3 Rheology of drilling fluids
3.4 Additives
4 Hydraulic friction in the circulating system
4.1 Head loss
4.2 Laminar flow
4.3 Turbulent pipe flow
4.4 Singularity losses
5 Removal of cuttings from under the bit
5.1 Cuttings removal process
5.2 Boundary conditions of the drilling process
5.3 General
5.3 Optimizing ROP, liner by liner
5.4 Optimizing the complete well
6 Transport of cuttings to the surface
6.1 Hole cleaning in vertical wells
6.2 Hole cleaning in inclinded wells
7 Keeping wellbore within maximum and minimum pressure; ECD-control
7.1 Density control
7.2 ECD factors
7.3 Temperature variation
8 Keeping the wellbore stable
8.1 Introduction
8.2 Filtration control
8.3 Mechanical stability
8.4 Chemical stability
8.5 Hole problems
8.6 Inhibitive mud
8.7 Countermeasures to hole problems
9 References
10 Supportive information
10.1 Nomenclature
10.2 Abbreviations and explanations
10.3 Definitions
10.4 Continuity, momentum and energy equation in microscopic and macroscopic form
10.5 Hydraulic friction loss equations
10.6 Determine Rheological Constants – Regression Analysis
10.7 Unit conversion factors
10.8 Viscosity and density of water vs. temperature
with TOC BookMarkLinks

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