Coil Tubing Unit for Oil Production and Remedial Measures.

• Author: Iqbal, Mohammed Ismail.
• Place / Publishing House: Aalborg : : River Publishers,, 2021.; Ã2021.
• Year of Publication: 2021
• Edition: 1st ed.
• Language: English
• Physical Description: 1 online resource (156 pages)

Table of Contents

• Front Cover
• Coil Tubing Unit for Oil Production and Remedial Measures
• Contents
• Preface
• List of Figures
• List of Tables
• List of Abbreviations
• 1 Nitrogen Application
• 1.1 Introduction
• 1.2 History of N2
• 1.2.1 N2 Properties
• 1.3 Cryogenics
• 1.3.1 Introduction
• 1.4 Basic Equipment
• 1.4.1 Storage Tank
• 1.4.2 Pumping System
• 1.4.3 Vaporizer System
• 1.5 Safety
• 1.5.1 General Information
• 1.5.2 Safety Bulletin from CGA (Compressed Gas Association)
• 1.5.3 Oxygen-deficient Atmospheres
• 1.5.4 Safety for Handling and Exposure
• 1.6 N2 Service Applications
• 1.6.1 Displacement
• 1.6.2 Nitrified Fluids-Acidisation
• 1.6.3 Atomized Atom
• 1.6.4 Foamed Acid
• 1.6.4.1 N2 Retention
• 1.6.4.2 Diverting
• 1.6.4.3 Production of Fines
• 1.6.4.4 Foamed Acid Guidelines
• 1.6.5 Aerating Conventional Fluids
• 1.6.6 Pipeline Purging
• 1.6.7 Use of Foam as a Drilling and Workover Fluid
• 1.7 Foam Clean Out
• 1.7.1 Introduction
• 1.7.2 Foam Stability and Viscosity
• 1.7.3 Fire Control
• 1.8 Water Control Technique by N2 Injection
• 1.8.1 Introduction
• 1.8.2 Technology
• 1.8.3 Job Description
• 1.8.4 Commercial Viability
• 1.8.5 Quick and Easy
• 1.8.6 Versatility and Adaptability
• 1.8.7 Economical
• 1.8.8 Freeding Differentially Stuck Drill Pipe
• 1.8.8.1 N2 Lift
• 1.8.8.2 N2 cushion
• 1.9 Case Study - I
• 1.10 Results/Remarks
• 1.11 Conclusion
• 1.12 Specification of N2 Pumpers Available with WSS COLD END
• 2 Water Control
• 2.1 Introduction to Water Production
• 2.1.1 Methods to Predict, Prevent, Delay and Reduce Excessive Water Production
• 2.1.1.1 Oil and Water production rates and ratios
• 2.1.1.1.1 Material Mass Balance
• 2.1.1.1.2 Darcy's Law
• 2.1.1.1.3 Productivity index
• 2.1.1.1.4 Simulators
• 2.1.1.2 Rate-limited facilities
• 2.1.1.3 Water production effect on bypassed oil.
• 2.1.1.4 Reservoir maturity
• 2.1.1.5 Water production rate effect on corrosion rates
• 2.1.1.6 Water production rate effect on scale deposition rates
• 2.1.1.7 Water production rate effect on sand production
• 2.2 Water Production Mechanisms
• 2.2.1 Completions-Related Mechanisms
• 2.2.1.1 Casing leaks
• 2.2.1.2 Channel behind casing
• 2.2.1.3 Completion into Water
• 2.2.2 Reservoir-Related Mechanisms
• 2.2.2.1 Bottomwater
• 2.2.2.2 Barrier breakdown
• 2.2.2.3 Coning and cresting
• 2.2.2.4 Channeling through high permeability
• 2.2.2.5 Fracture communication between injector and producer
• 2.2.2.6 Stimulation out of zone
• 2.3 Preventing Excessive Water Production
• 2.3.1 Preventing Casing Leaks
• 2.3.2 Preventing Channels Behind Casing
• 2.3.3 Preventing Coning and Cresting
• 2.3.4 Perforating
• 2.3.5 Fracturing
• 2.3.6 Artificial Barriers
• 2.3.7 Dual Completions
• 2.3.8 Horizontal Wells to Prevent Coning
• 2.3.9 Preventing Channeling Through High Permeability
• 2.3.9.1 Perforating
• 2.3.9.2 Stimulation techniques
• 2.3.9.3 Permeability reduction
• 2.3.9.4 Preventing fracture communication between injector and producer
• 2.3.9.5 Completing to accommodate future water production rates future zonal isolation
• 2.4 Creative Water Management
• 2.5 Treatments Used to Reduce Excessive Water Production
• 2.5.1 Characterizing the Problem
• 2.5.2 Treatment Design
• 2.5.3 Expected Treatment Effect on Water Production
• 2.5.4 Treatment Types
• 2.5.4.1 Zone sealants
• 2.5.4.2 Permeability-Reducing Agents (PRA)
• 2.5.4.3 Relative Permeability Modifiers (RPM)
• 2.5.5 Description of Previously Applied Treatments
• 2.5.5.1 Mechanical plugs
• 2.5.5.2 Sand plugs
• 2.5.5.3 Water-based cement
• 2.5.5.4 Hydrocarbon-based cements
• 2.5.5.5 Externally activated silicates
• 2.5.5.6 Internally Activated Silicates (IAS).
• 2.5.5.7 Monomer systems
• 2.5.5.8 Crosslinked polymer systems
• 2.5.5.9 Surface-active RPMs
• 2.5.5.10 Foams
• 2.5.6 Treatment Lifetime
• 2.6 Selecting Treatment Composition and Volume
• 2.6.1 Placement Techniques
• 2.6.1.1 Bullheading
• 2.6.1.2 Mechanical packer placement
• 2.6.1.3 Dual injection
• 2.6.1.4 Isoflow
• 2.6.2 Viscosity Considerations
• 2.6.3 Temperature Considerations
• References
• 3 Sand Control
• 3.1 Sand Control Introduction
• 3.1.1 Formation Damage
• 3.1.2 Fines Migration
• 3.1.3 Sand Production Mechanisms
• 3.2 Formation Sand
• 3.2.1 Petro Physical Properties
• 3.2.2 Geological Deposition of Sand
• 3.2.2.1 Desert aeolian sands
• 3.2.2.2 Marine shelf sand
• 3.2.2.3 Beaches, barriers and bar
• 3.2.2.4 Tidal flat and estuarine sands
• 3.2.2.5 Fluviatile sands
• 3.2.2.6 Alluvial sands
• 3.2.3 Formation Sand Description
• 3.2.3.1 Quicksand
• 3.2.3.2 Partially consolidated sand
• 3.2.3.3 Friable sand
• 3.3 Causes and Effects of Sand Production
• 3.3.1 Causes of Sand Production
• 3.3.1.1 Totally unconsolidated formation
• 3.3.1.2 High production rates
• 3.3.1.3 Water productions
• 3.3.1.4 Increase in water production
• 3.3.1.5 Reservoir depletion
• 3.3.2 Effects of Sand Production
• 3.4 Detection and Prediction of Sand Production
• 3.4.1 Methods for Monitoring and Detection of Sand Production
• 3.4.1.1 Wellhead shakeouts
• 3.4.1.2 Safety plugs and erosion sand probes
• 3.4.1.3 Sonic sand detection
• 3.5 Methods for Sand Exclusion
• 3.5.1 Production Restriction
• 3.5.2 Mechanical Methods
• 3.5.3 In-Situ Chemical Consolidation Methods
• 3.5.4 Combination Methods
• 3.5.5 Selecting the Appropriate Sand Exclusion Method
• 3.6 Mechanical Methods of Sand Exclusions
• 3.6.1 Mechanical Components
• 3.6.1.1 Pack-sands
• 3.6.1.2 Liners and screens
• 3.6.1.3 Carrier fluids.
• 3.6.2 Tools and Accessories
• 3.6.3 Completion Tools
• 3.6.3.1 Gravel-pack Packer
• 3.6.3.2 Flow sub
• 3.6.3.3 Mechanical fluid-loss device
• 3.6.3.4 Safety joint
• 3.6.3.5 Blank pipe
• 3.6.3.6 Tell-tale screen
• 3.6.3.7 Seal assembly
• 3.6.3.8 Sump packer
• 3.6.4 Service Tools
• 3.6.4.1 Crossover service tool
• 3.6.4.2 Reverse-ball check-valve
• 3.6.4.3 Swivel joint
• 3.6.4.4 Washpipe
• 3.6.4.5 Shifting tools
• 3.6.4.6 Tool selection
• 3.7 Mechanical Method: Techniques and Procedures
• 3.7.1 Gravity Pack
• 3.7.2 Washdown Method
• 3.7.3 Circulation Packs
• 3.7.4 Reverse-circulation Pack
• 3.7.5 Bullhead Pressure Packs
• 3.7.6 Circulating-pressure Packs
• 3.7.7 Slurry Packs
• 3.7.8 Staged Prepacks and Acid Prepacks
• 3.7.9 Water-packs and High-rate Water-packs
• 3.7.10 Fracpacks
• 3.7.11 Summary
• 3.7.12 Mechanical Job Designs
• 3.7.12.1 Formation characteristics
• 3.7.12.2 Pack-sand selection criteria
• 3.7.12.3 Screen selection criteria
• 3.7.12.4 Gravel-pack job calculations
• 3.7.12.4.1 Pack-sand volume required
• 3.7.12.4.2 Carrier-fluid Volume
• 3.7.12.5 Predicting job outcome by computer modeling
• 3.8 Chemical Consolidation Techniques
• 3.8.1 Internally Activated Systems
• 3.8.2 Externally Activated Systems
• 3.8.3 Application
• 3.9 Combination Methods
• 3.9.1 Semicured Resin-coated Pack Gravels
• 3.9.2 Liquid Resin-coated Pack Gravel
• 3.10 Horizontal Gravel-Packing
• 3.10.1 Variables that Affect Sand Delivery
• 3.10.2 Pump Rate and Fluid Velocity
• 3.10.3 Alpha and Beta Wave Progression Through the Annulus
• 3.10.4 Sand Concentration
• 3.10.5 Placement Procedure and Tool Configuration
• 3.10.6 Liner/Tailpipe Ratio
• 3.10.7 Screen/Casing Clearance
• 3.10.8 Perforation Phasing
• References
• Index
• About the Author
• Back Cover.