Nanotechnology for CO2 Utilization in Oilfield Applications

Front Cover
Nanotechnology for CO2 Utilization in Oilfield Applications
Copyright
Contents
Contributors
Chapter 1: Introduction
1.1. Background
1.2. Challenges with CO2 injection and utilization in oilfield applications
1.3. Why current alternatives do not work?
1.4. What the book aims to achieve?
1.5. Scope of the book
References
Further reading
Chapter 2: Synthesis and characterization of nanofluids for oilfield applications
2.1. Introduction
2.2. Synthesis of nanofluids
2.2.1. Synthesis of NPs
2.2.2. Synthesis of nanofluids
2.2.2.1. Single-step method of nanofluid synthesis
2.2.2.2. Two-step method of nanofluid synthesis
2.3. Various types of nanofluids
2.3.1. Metal-based nanofluid
2.3.2. Metal-oxide based nanofluid
2.3.3. Carbon-based nanofluid
2.3.4. Hybrid/mixed metal-based nanofluid
2.4. Nanofluid imaging methods
2.5. Characterization of nanofluids
2.6. Improving stability of nanofluids
2.6.1. Methods to evaluate stability of nanofluids
2.6.1.1. Visual methods to evaluate stability of nanofluids
2.6.1.2. Analytical methods to evaluate stability of nanofluids
2.6.2. Methods to improve stability of nanofluids
2.6.2.1. Chemical additives to increase the stability of nanofluids
2.6.2.2. Surface functionalization to increase the stability of nanofluids
References
Chapter 3: Rheological characterization of nanofluids
3.1. Introduction
3.2. Rheological behavior of nanofluids
3.3. Factors affecting the rheology of nanofluids
3.3.1. Temperature
3.3.2. Volume fraction
3.3.3. Shear rate
3.3.4. Size of nanoparticles
3.3.5. Shape of nanoparticles
3.3.6. Base fluid properties
3.4. Experimental determination of rheological characteristics of nanofluids
3.5. Mathematical models to predict the rheology of nanofluid
3.6. Importance of nanofluid rheology in oilfield applications
3.7. Conclusion
References
Chapter 4: Why CO2 for oilfield applications?
4.1. CO2 and industrial development
4.2. CO2 as a greenhouse gas
4.3. Sources of CO2
4.4. CO2 capture and storage
4.5. Future climate goals
4.6. Role of oil and gas industry in meeting climate targets
References
Chapter 5: Carbonated nanofluids for EOR and improved carbon storage
5.1. Carbonation: Principles and introduction
5.2. CO2 solubility: Molality and Henrys law
5.3. Absorption kinetics in nanofluids
5.4. Physisorption and chemisorption
5.5. Oilfield applications of carbonated nanofluids: EOR
5.6. Carbon storage potential and future research in carbonated nanofluids
References
Chapter 6: CO2 EOR and injection process: Role of nanomaterials
6.1. Introduction
6.1.1. CO2 characteristics
6.1.2. Benefits and limitations of using CO2
6.1.3. Role of nanomaterials in improving CO2 efficacy
6.2. Sources of CO2
6.3. Types and methods of CO2-EOR
6.4. Nanomaterials in CO2 EOR
References
Further reading
Chapter 7: Mass transfer by molecular diffusion
Abbreviations
7.1. Diffusion in bulk fluids and porous media
7.1.1. Diffusion in bulk fluids
7.2. Ficks law of diffusion for binary mixtures
7.2.1. Ficks first law
7.2.2. Ficks second law
7.2.3. Diffusion through porous media
7.2.3.1. Knudsen diffusion
7.2.4. Surface diffusion
7.3. Molecular diffusion of gases into liquid phases
7.3.1. Two-film theory
7.3.2. Penetration theory
7.3.3. Surface renewal theory
7.4. The role of CO2 molecular diffusion in oil reservoirs
7.4.1. Primary process
7.4.2. Secondary process
7.4.3. Tertiary process
7.4.4. Mechanism of EOR process
7.4.5. CO2 diffusion into oil
7.5. Determination of gas diffusion coefficient
7.5.1. Experimental measurements of mass transfer parameters
7.5.2. Loschmidt cell
7.5.3. Two-bulb method
7.5.4. Stefan tube
7.5.5. Gas chromatography
7.5.6. PVT method
7.5.7. Pressure decay method
7.5.8. X-ray CAT method
7.5.9. Empirical correlations of diffusion coefficients
7.6. Conclusion
References
Chapter 8: Corrosion mitigation in oil reservoirs during CO2 injection using nanomaterials
8.1. Introduction
8.2. Methods of preparation
8.3. Corrosion inhibition and mechanisms
8.3.1. Corrosion in acid solutions
8.3.2. Adsorption of corrosion inhibitors on a metal surface
8.3.3. Metal/metal oxide nanoparticles as corrosion inhibitors
8.3.3.1. Barrier properties
8.3.3.2. Self-healing properties
8.3.3.3. For photodegradation resistance
8.3.4. Nanocontainers for storage of inhibitors
8.3.5. Carbon dots (CDs)
8.3.6. Nanotubes
8.4. The role of CO2 in promoting corrosion in multiphase flow environment
8.5. Prospects
8.6. Conclusion
References
Further reading
Chapter 9: Formation damage in oil reservoirs during CO2 injection
9.1. Introduction
9.2. Challenges during CO2 flooding
9.2.1. Pore plugging
9.2.2. Asphaltene induced wettability alteration
9.2.3. Permeability damage
9.2.4. Interfacial tension (IFT)
9.2.5. Mobility ratio
9.2.6. Wetting conditions of the rock surface
9.2.7. Role of nanomaterials and their types
9.3. CO2 rock water interaction: How do nanomaterials alter the equation?
9.4. Reservoir screening for CO2-EOR to avoid formation damage
9.5. Special considerations for nanofluid injection
9.5.1. Concentration of nanomaterials
9.5.2. Nanomaterials sizes
9.5.3. Temperature
9.5.4. Salinity
9.5.5. Injection rate of the nanofluid
9.5.6. Surfactant nanofluid
9.6. Composite nanomaterial in EOR
9.6.1. Polymer nanofluid
9.6.2. Combining of nanomaterials
9.6.3. Nanomaterials and emulsion stability
9.7. Challenges and opportunities for future research
9.8. Conclusion
References
Chapter 10: Current advances, challenges, and prospects of CO2 capture, storage, and utilization
10.1. Introduction
10.2. Carbon storage and trapping mechanisms
10.2.1. Carbon storage and trapping mechanisms
10.2.2. Methods of carbon capture
10.2.2.1. Underground geological CO storage
10.2.3. CO2 storage in deep ocean
10.2.4. CO2 storage by carbonation of minerals
10.3. CO2 transport mechanisms and models representing geosequestration process
10.4. Biological CO2 Ultilization: Status, prospects and challenges
10.5. Photosynthetic CO2 conversion
10.5.1. Cyanobacteria
10.5.2. Algae
10.5.3. Nonphotosynthetic CO2 conversion
10.5.3.1. Chemolithotrophs
10.5.3.2. Bioelectrochemical systems
10.6. Nano technology for carbon geosequestration and related applications
10.6.1. Photo-electrochemical reduction of CO2
10.6.2. Photo-nano-catalytic reduction of CO2
10.6.3. Nanomaterials for plasma catalytic hydrogenation of CO2
10.6.4. Carbon capture and storage using solid and liquid nanoabsorbents
10.6.5. Challenges of large-scale implementation of nanotechnology for CO2 capture and mitigation
10.7. CO2 geosequestration challenges and future prospects
References
Chapter 11: Governing mechanism of nanofluids for CO2 EOR
11.1. Fundamentals of EOR
11.1.1. Stages of oil recovery
11.1.2. EOR recovery concepts
11.1.3. Two main EOR parameters
11.1.4. Why water flooding efficiency is generally low?
11.2. CO2 flooding and the associated recovery mechanism
11.3. Limitation associated with CO2
11.3.1. Low density and gravity segregation
11.3.2. Low viscosity and poor mobility control
11.3.3. Low viscosity and poor conformance control
11.3.4. Common limitations with the existing improvement techniques
11.4. CO2 EOR for sequestration
11.5. Special features of Nano particle
11.6. Nano-particle applications
11.6.1. Effect of Nano fluid on CO2-wettability during CO2 sequestration
11.6.1.1. Effect of nanoparticle size on CO2-wettability
11.6.1.2. Effect of nanoparticle concentration on wettability
11.6.2. Effect of Nano fluids on CO2-brine-oil interfacial tension
11.6.3. Mobility control of CO2 flood using nanofluid
11.6.4. Nanofluid for EOR in naturally fractured reservoirs
11.7. Conclusion
References
Further reading
Chapter 12: Retention of nanoparticles in porous media: Implications for fluid flow
12.1. Introduction to nanoparticle retention
12.2. Mechanisms and principles of NP retention
12.3. Implications for fluid flow
12.4. Role of SEM/AFM/EDX imaging
12.5. Challenges in understanding NP fluid flow and retention
12.6. Recent and suggested advances in NP fluid flow
References
Chapter 13: CO2 foams for enhanced oil recovery
13.1. Introduction to CO2 foam
13.2. Foam stability
13.2.1. Gravity and capillary drainage
13.2.2. Marangoni effect
13.2.3. Disjoining pressure
13.2.4. Gas diffusion
13.3. CO2 foam for EOR
13.4. Mechanisms of improving oil recovery by CO2 foam
13.4.1. Stabilization of the displacement process
13.4.2. Reduction of capillary forces
13.4.3. Reservoir rock wettability alteration
13.4.4. Interfacial mass transfer between CO2 and oil
13.5. Key parameters influencing CO2 foam flooding
13.5.1. Effect of slug size of foam
13.5.2. Effect of slug ratio
13.5.3. Effect of injection mode
13.5.4. Effect of injection timing
13.6. Nanoparticle stabilized CO2 foams
13.7. Colloid gas aphrons
13.8. Hybrid foam flooding
13.9. Conclusions
References
Chapter 14: Solid CO2 storage by hydrate-based geo sequestration
14.1. Introduction
14.1.1. Phase behavior of CO2 hydrate
14.1.2. Molecular structure
14.1.3. Computed tomography in hydrate research
14.2. Hydrate-based CO2 capture, storage, and geo-sequestration technologies
14.2.1. CO2 hydrate capture technology: CO2 capture in seawater desalination and CO2 separation from a flue gas mixture
14.2.2. Location-specific storage and capturing of CO2
14.2.3. CO2 as hydrate in the ocean water column, under the seafloor, and depleted hydrocarbon reservoir
14.2.4. Replacement of CH4 with CO2
14.2.5. CO2+N2/H2 (nitrogen/hydrogen) hydrate
14.3. Application of nanoparticles for CO2 hydrate promotion
14.3.1. Role of nanoparticles in the formation of CO2 hydrates
14.3.2. Nanoporous materials
14.3.3. Hydrate formations in nanoporous clay and silica sand
14.4. Conclusions and future directions
References
Chapter 15: Case studies of CO2-EOR
15.1. CO2 Injection in laboratory and on field scale
15.2. Carbonated water injection in laboratory and on field scale
References
Further reading
Chapter 16: Conclusion and future research direction
16.1. Closing remarks
16.2. Viability of nanotechnology in improving carbon utilization
16.3. How does this book help?
Index
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