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.