Coil Tubing Unit for Oil Production and Remedial Measures (River Publishers Series in Chemical, Environmental and Energy Engineering)

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
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