Coil Tubing Unit for Oil Production and Remedial Measures.
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Place / Publishing House: | Aalborg : : River Publishers,, 2021. Ã2021. |
Year of Publication: | 2021 |
Edition: | 1st ed. |
Language: | English |
Online Access: | |
Physical Description: | 1 online resource (156 pages) |
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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.