Responding to the latest developments in rock physics research, this popular reference book has been thoroughly updated while retaining its comprehensive coverage of the fundamental theory, concepts, and laboratory results. It brings together the vast literature from the field to address the relationships between geophysical observations and the underlying physical properties of Earth materials - including water, hydrocarbons, gases, minerals, rocks, ice, magma and methane hydrates. This third edition includes expanded coverage of topics such as effective medium models, viscoelasticity, attenuation, anisotropy, electrical-elastic cross relations, and highlights applications in unconventional reservoirs. Appendices have been enhanced with new materials and properties, while worked examples (supplemented by online datasets and MATLAB® codes) enable readers to implement the workflows and models in practice. This significantly revised edition will continue to be the go-to reference for students and researchers interested in rock physics, near-surface geophysics, seismology, and professionals in the oil and gas industries.

The Rock Physics Handbook

The differential quadrature method is a numerical solution technique for initial and/or boundary problems. It was developed by the late Richard Bellman and his associates in the early 70s and, since then, the technique has been successfully employed in a variety of problems in engineering and physical sciences. The method has been projected by its proponents as a potential alternative to the conventional numerical solution techniques such as the finite difference and finite element methods. This paper presents a state-of-the-art review of the differential quadrature method, which should be of general interest to the computational mechanics community.

Differential Quadrature Method in Computational Mechanics: A Review

Numerical Methods for Scientists and Engineers

Gaseous flow regimes through tight porous media are described by rigorous application of a unified Hagen–Poiseuille-type equation. Proper implementation is accomplished based on the realization of the preferential flow paths in porous media as a bundle of tortuous capillary tubes. Improved formulations and methodology presented here are shown to provide accurate and meaningful correlations of data considering the effect of the characteristic parameters of porous media including intrinsic permeability, porosity, and tortuosity on the apparent gas permeability, rarefaction coefficient, and Klinkenberg gas slippage factor.

Effective Correlation of Apparent Gas Permeability in Tight Porous Media

Power to Gas: Technological Overview, Systems Analysis and Economic Assessment for a Case Study in Germany

A theoretically improved model incorporating the relevant mechanisms of gas retention and transport in gas-bearing shale formations is presented for determination of intrinsic gas permeability and diffusivity. This is accomplished by considering the various flow regimes according to a unified Hagen–Poiseuille-type equation, fully compressible treatment of gas and shale properties, and numerical solution of the non-linear pressure equation. The present model can accommodate a wide range of fundamental flow mechanisms, such as continuum, slip, transition, and free molecular flow, depending on the prevailing flow conditions characterized by the Knudsen number. The model indicates that rigorous determination of shale-gas permeability and diffusivity requires the characterization of various important parameters included in the present phenomenological modeling approach, many of which are not considered in previous studies. It is demonstrated that the improved model matches a set of experimental data better than a previous attempt. It is concluded that the improved model provides a more accurate means of analysis and interpretation of the pressure-pulse decay tests than the previous models which inherently consider a Darcian flow and neglect the variation of parameters with pressure.

Shale-Gas Permeability and Diffusivity Inferred by Improved Formulation of Relevant Retention and Transport Mechanisms

Preface Chapter 1-Overview of Formation Damage PART I Characterization of Reservoir Rock for Formation Damage- Mineralogy, Texture, Petrographics, Petrophysics, and Instrumental Techniques Chapter 2- Mineralogy and Mineral Sensitivity of Petroleum-Bearing Formations Chapter 3- Petrographical Characteristics of Petroleum-Bearing Formations Chapter 4- Petrophysics-Flow Functions and Parameters Chapter 5- Porosity and Permeability Relationships of Geological Formations Chapter 6- Instrumental and Laboratory Techniques for Characterization of Reservoir Rock PART II Characterization of the Porous Media Processes for Formation Damage-Accountability of Phases and Species, Rock-Fluid-Particle Interactions, and Rate Processes Chapter 7- Multi-Phase and Multi-Species Transport in Porous Media Chapter 8-Particulate Processes in Porous Media Chapter 9-Crystal Growth and Scale Formation in Porous Media PART III Formation Damage by Particulate Processes Chapter 10-Single-Phase Formation Damage by Fines Migration and Clay Swelling Chapter 11- Multi-Phase Formation Damage by Fines Migration Chapter 12-Cake Filtration: Mechanism, Parameters and Modeling PART IV Formation Damage by Inorganic and Organic Processes-Chemical Reactions, Saturation Phenomena, Deposition, and Dissolution Chapter 13-Inorganic Scaling and Geochemical Formation Damage Chapter 14-Formation Damage by Organic Deposition PART V Assessment of the Formation Damage Potential-Testing, Simulation, Analysis, and Interpretation Chapter 15-Laboratory Evaluation of Formation Damage Chapter 16- Formation Damage Simulator Development Chapter 17- Model Assisted Analysis and Interpretation of Laboratory and Field Tests PART VI Formation Damage Models for Fields Applications- Drilling Mud Invasion, Injectivity of Wells, Sanding and Gravel-Pack Damage, and Inorganic and Organic Deposition Chapter 18- Drilling Mud Filtrate and Solids Invasion and Mudcake Formation Chapter 19-Injectivity of the Waterflooding Wells Chapter 20- Reservoir Sand Migration and Gravel-Pack Damage: Stress-Induced Formation Damage, Sanding Tendency, and Prediction Chapter 21- Near-Wellbore Formation Damage by Inorganic and Organic Precipitates Deposition PART VII Diagnosis and Mitigation of Formation Damage-Measurement, Assessment, Control, and Remediation Chapter 22- Field Diagnosis and Measurement of Formation Damage Chapter 23-Determination of Formation- and Pseudo-Damage from Well Performance- Identification, Characterization, and Evaluation Chapter 24-Formation Damage Control and Remediation- Fundamentals Chapter 25-Reservoir Formation Damage Abatement- Guidelines, Methodology, Preventive Maintenance, and Remediation Treatments Index

Reservoir Formation Damage: Fundamentals, Modeling, Assessment, and Mitigation

Modification of Darcy's law for the threshold pressure gradient

Variation of porosity and permeability by scale dissolution and precipitation in porous media is described based on fractal attributes of the pores, realization of flow channels as a bundle of uniformly distributed mean-size cylindrical and tortuous hydraulic flow tubes, a permeability-porosity relationship conforming to Civan's power law flow units equation, and the pore surface scale precipitation and dissolution kinetics. Practical analytical solutions, considering the conditions of typical laboratory core tests and relating the lumped and phenomenological parameters, were derived and verified by experimental data. Deviations of the empirically determined exponents of the pore-to-matrix volume ratio compared to the Kozeny-Carman equation were due to the relative fractal dimensions of pore attributes of random porous media. The formulations provide useful insights into the mechanism of porosity and permeability variation by surface processes and accurate representation of the effect of scale on porosity and permeability by simpler lumped-parameter models.

Faruk Civan

Papers

Effective Correlation of Apparent Gas Permeability in Tight Porous Media

Shale-Gas Permeability and Diffusivity Inferred by Improved Formulation of Relevant Retention and Transport Mechanisms

Reservoir Formation Damage: Fundamentals, Modeling, Assessment, and Mitigation

Modification of Darcy's law for the threshold pressure gradient

Scale effect on porosity and permeability: Kinetics, model, and correlation