{"product_id":"physics-of-fluid-flow-and-transport-in-unconventional-reservoir-rocks-isbn-9781119729877","title":"Physics of Fluid Flow and Transport in Unconventional Reservoir Rocks","description":"\u003cb\u003ePhysics of Fluid Flow and Transport in Unconventional Reservoir Rocks\u003c\/b\u003e \u003cp\u003e\u003cb\u003eUnderstanding and predicting fluid flow in hydrocarbon shale and other non-conventional reservoir rocks\u003c\/b\u003e \u003c\/p\u003e\u003cp\u003eOil and natural gas reservoirs found in shale and other tight and ultra-tight porous rocks have become increasingly important sources of energy in both North America and East Asia. As a result, extensive research in recent decades has focused on the mechanisms of fluid transfer within these reservoirs, which have complex pore networks at multiple scales. Continued research into these important energy sources requires detailed knowledge of the emerging theoretical and computational developments in this field. \u003c\/p\u003e\u003cp\u003eFollowing a multidisciplinary approach that combines engineering, geosciences and rock physics, \u003ci\u003ePhysics of Fluid Flow and Transport in Unconventional Reservoir Rocks\u003c\/i\u003e provides both academic and industrial readers with a thorough grounding in this cutting-edge area of rock geology, combining an explanation of the underlying theories and models with practical applications in the field.  \u003c\/p\u003e\u003cp\u003eReaders will also find: \u003c\/p\u003e\u003cul\u003e\n\u003cli\u003eAn introduction to the digital modeling of rocks\u003c\/li\u003e \u003cli\u003eDetailed treatment of digital rock physics, including decline curve analysis and non-Darcy flow\u003c\/li\u003e \u003cli\u003eSolutions for difficult-to-acquire measurements of key petrophysical characteristics such as shale wettability, effective permeability, stress sensitivity, and sweet spots\u003c\/li\u003e\n\u003c\/ul\u003e \u003cp\u003e\u003ci\u003ePhysics of Fluid Flow and Transport in Unconventional Reservoir Rocks\u003c\/i\u003e is a  fundamental resource for academic and industrial researchers in hydrocarbon exploration, fluid flow, and rock physics, as well as professionals in related fields. \u003c\/p\u003e\u003cp\u003eList of Contributors xvii\u003c\/p\u003e \u003cp\u003ePreface xxi\u003c\/p\u003e \u003cp\u003eIntroduction 1\u003c\/p\u003e \u003cp\u003e\u003cb\u003e1 Unconventional Reservoirs: Advances and Challenges 3\u003cbr\u003e \u003c\/b\u003e\u003ci\u003eBehzad Ghanbarian, Feng Liang, and Hui-Hai Liu\u003c\/i\u003e\u003c\/p\u003e \u003cp\u003e1.1 Background 3\u003c\/p\u003e \u003cp\u003e1.2 Advances 4\u003c\/p\u003e \u003cp\u003e1.2.1 Wettability 4\u003c\/p\u003e \u003cp\u003e1.2.2 Permeability 5\u003c\/p\u003e \u003cp\u003e1.3 Challenges 7\u003c\/p\u003e \u003cp\u003e1.3.1 Multiscale Systems 7\u003c\/p\u003e \u003cp\u003e1.3.2 Hydrocarbon Production 9\u003c\/p\u003e \u003cp\u003e1.3.3 Recovery Factor 9\u003c\/p\u003e \u003cp\u003e1.3.4 Unproductive Wells 9\u003c\/p\u003e \u003cp\u003e1.4 Concluding Remarks 11\u003c\/p\u003e \u003cp\u003eReferences 11\u003c\/p\u003e \u003cp\u003e\u003cb\u003ePart I Pore-Scale Characterizations 15\u003c\/b\u003e\u003c\/p\u003e \u003cp\u003e\u003cb\u003e2 Pore-Scale Simulations and Digital Rock Physics 17\u003cbr\u003e \u003c\/b\u003e\u003ci\u003eJunjian Wang, Feifei Qin, Jianlin Zhao, Li Chen, Hari Viswanathan, and Qinjun Kang\u003c\/i\u003e\u003c\/p\u003e \u003cp\u003e2.1 Introduction 17\u003c\/p\u003e \u003cp\u003e2.2 Physics of Pore-Scale Fluid Flow in Unconventional Rocks 18\u003c\/p\u003e \u003cp\u003e2.2.1 Physics of Gas Flow 18\u003c\/p\u003e \u003cp\u003e2.2.1.1 Gas Slippage and Knudsen Layer Effect 18\u003c\/p\u003e \u003cp\u003e2.2.1.2 Gas Adsorption\/Desorption and Surface Diffusion 20\u003c\/p\u003e \u003cp\u003e2.2.2 Physics of Water Flow 22\u003c\/p\u003e \u003cp\u003e2.2.3 Physics of Condensation 23\u003c\/p\u003e \u003cp\u003e2.3 Theory of Pore-Scale Simulation Methods 23\u003c\/p\u003e \u003cp\u003e2.3.1 The Isothermal Single-Phase Lattice Boltzmann Method 23\u003c\/p\u003e \u003cp\u003e2.3.1.1 Bhatnagar–Gross–Krook (BGK) Collision Operator 24\u003c\/p\u003e \u003cp\u003e2.3.1.2 The Multi-Relaxation Time (MRT)-LB Scheme 24\u003c\/p\u003e \u003cp\u003e2.3.1.3 The Regularization Procedure 26\u003c\/p\u003e \u003cp\u003e2.3.2 Multi-phase Lattice Boltzmann Simulation Method 27\u003c\/p\u003e \u003cp\u003e2.3.2.1 Color-Gradient Model 27\u003c\/p\u003e \u003cp\u003e2.3.2.2 Shan-Chen Model 28\u003c\/p\u003e \u003cp\u003e2.3.3 Capture Fluid Slippage at the Solid Boundary 29\u003c\/p\u003e \u003cp\u003e2.3.4 Capture the Knudsen Layer\/Effective Viscosity 30\u003c\/p\u003e \u003cp\u003e2.3.5 Capture the Adsorption\/Desorption and Surface Diffusion Effects 30\u003c\/p\u003e \u003cp\u003e2.3.5.1 Modeling of Adsorption in LBM 30\u003c\/p\u003e \u003cp\u003e2.3.5.2 Modeling of Surface Diffusion Via LBM 31\u003c\/p\u003e \u003cp\u003e2.4 Applications 32\u003c\/p\u003e \u003cp\u003e2.4.1 Simulation of Gas Flow in Unconventional Reservoir Rocks 32\u003c\/p\u003e \u003cp\u003e2.4.1.1 Gas Slippage 32\u003c\/p\u003e \u003cp\u003e2.4.1.2 Gas Adsorption 33\u003c\/p\u003e \u003cp\u003e2.4.1.3 Surface Diffusion of Adsorbed Gas 35\u003c\/p\u003e \u003cp\u003e2.4.2 Simulation of Water Flow in Unconventional Reservoir Rocks 35\u003c\/p\u003e \u003cp\u003e2.4.3 Simulation of Immiscible Two-Phase Flow 39\u003c\/p\u003e \u003cp\u003e2.4.4 Simulation of Vapor Condensation 43\u003c\/p\u003e \u003cp\u003e2.4.4.1 Model Validations 44\u003c\/p\u003e \u003cp\u003e2.4.4.2 Vapor Condensation in Two Adjacent Nano-Pores 44\u003c\/p\u003e \u003cp\u003e2.5 Conclusion 48\u003c\/p\u003e \u003cp\u003eReferences 49\u003c\/p\u003e \u003cp\u003e\u003cb\u003e3 Digital Rock Modeling: A Review 53\u003cbr\u003e \u003c\/b\u003e\u003ci\u003eYuqi Wu and Pejman Tahmasebi\u003c\/i\u003e\u003c\/p\u003e \u003cp\u003e3.1 Introduction 53\u003c\/p\u003e \u003cp\u003e3.2 Single-Scale Modeling of Digital Rocks 54\u003c\/p\u003e \u003cp\u003e3.2.1 Experimental Techniques 54\u003c\/p\u003e \u003cp\u003e3.2.1.1 Imaging Technique of Serial Sectioning 54\u003c\/p\u003e \u003cp\u003e3.2.1.2 Laser Scanning Confocal Microscopy 54\u003c\/p\u003e \u003cp\u003e3.2.1.3 X-Ray Computed Tomography Scanning 55\u003c\/p\u003e \u003cp\u003e3.2.2 Computational Methods 55\u003c\/p\u003e \u003cp\u003e3.2.2.1 Simulated Annealing 56\u003c\/p\u003e \u003cp\u003e3.2.2.2 Markov Chain Monte Carlo 56\u003c\/p\u003e \u003cp\u003e3.2.2.3 Sequential Indicator Simulation 56\u003c\/p\u003e \u003cp\u003e3.2.2.4 Multiple-Point Statistics 57\u003c\/p\u003e \u003cp\u003e3.2.2.5 Machine Learning 58\u003c\/p\u003e \u003cp\u003e3.2.2.6 Process-Based Modeling 58\u003c\/p\u003e \u003cp\u003e3.3 Multiscale Modeling of Digital Rocks 59\u003c\/p\u003e \u003cp\u003e3.3.1 Multiscale Imaging Techniques 60\u003c\/p\u003e \u003cp\u003e3.3.2 Computational Methods 60\u003c\/p\u003e \u003cp\u003e3.3.2.1 Image Superposition 60\u003c\/p\u003e \u003cp\u003e3.3.2.2 Pore-Network Integration 61\u003c\/p\u003e \u003cp\u003e3.3.2.3 Image Resolution Enhancement 63\u003c\/p\u003e \u003cp\u003e3.3.2.4 Object-Based Reconstruction 63\u003c\/p\u003e \u003cp\u003e3.4 Conclusions and Future Perspectives 65\u003c\/p\u003e \u003cp\u003eAcknowledgments 66\u003c\/p\u003e \u003cp\u003eReferences 66\u003c\/p\u003e \u003cp\u003e\u003cb\u003e4 Scale Dependence of Permeability and Formation Factor: A Simple Scaling Law 77\u003cbr\u003e \u003c\/b\u003e\u003ci\u003eBehzad Ghanbarian and Misagh Esmaeilpour\u003c\/i\u003e\u003c\/p\u003e \u003cp\u003e4.1 Introduction 77\u003c\/p\u003e \u003cp\u003e4.2 Theory 78\u003c\/p\u003e \u003cp\u003e4.2.1 Funnel Defect Approach 78\u003c\/p\u003e \u003cp\u003e4.2.2 Application to Porous Media 79\u003c\/p\u003e \u003cp\u003e4.3 Pore-network Simulations 80\u003c\/p\u003e \u003cp\u003e4.4 Results and Discussion 81\u003c\/p\u003e \u003cp\u003e4.5 Limitations 86\u003c\/p\u003e \u003cp\u003e4.6 Conclusion 86\u003c\/p\u003e \u003cp\u003eAcknowledgment 86\u003c\/p\u003e \u003cp\u003eReferences 87\u003c\/p\u003e \u003cp\u003e\u003cb\u003ePart II Core-Scale Heterogeneity 89\u003c\/b\u003e\u003c\/p\u003e \u003cp\u003e\u003cb\u003e5 Modeling Gas Permeability in Unconventional Reservoir Rocks 91\u003cbr\u003e \u003c\/b\u003e\u003ci\u003eBehzad Ghanbarian, Feng Liang, and Hui-Hai Liu\u003c\/i\u003e\u003c\/p\u003e \u003cp\u003e5.1 Introduction 91\u003c\/p\u003e \u003cp\u003e5.1.1 Theoretical Models 91\u003c\/p\u003e \u003cp\u003e5.1.2 Pore-Network Models 92\u003c\/p\u003e \u003cp\u003e5.1.3 Gas Transport Mechanisms 93\u003c\/p\u003e \u003cp\u003e5.1.4 Objectives 93\u003c\/p\u003e \u003cp\u003e5.2 Effective-Medium Theory 93\u003c\/p\u003e \u003cp\u003e5.3 Single-Phase Gas Permeability 95\u003c\/p\u003e \u003cp\u003e5.3.1 Gas Permeability in a Cylindrical Tube 95\u003c\/p\u003e \u003cp\u003e5.3.2 Pore Pressure-Dependent Gas Permeability in Tight Rocks 96\u003c\/p\u003e \u003cp\u003e5.3.3 Comparison with Experiments 96\u003c\/p\u003e \u003cp\u003e5.3.4 Comparison with Pore-Network Simulations 98\u003c\/p\u003e \u003cp\u003e5.3.5 Comparaison with Lattice-Boltzmann Simulations 99\u003c\/p\u003e \u003cp\u003e5.4 Gas Relative Permeability 100\u003c\/p\u003e \u003cp\u003e5.4.1 Hydraulic Flow in a Cylindrical Pore 100\u003c\/p\u003e \u003cp\u003e5.4.2 Molecular Flow in a Cylindrical Pore 101\u003c\/p\u003e \u003cp\u003e5.4.3 Total Gas Flow in a Cylindrical Pore 101\u003c\/p\u003e \u003cp\u003e5.4.4 Gas Relative Permeability in Tight Rocks 101\u003c\/p\u003e \u003cp\u003e5.4.5 Comparison with Experiments 102\u003c\/p\u003e \u003cp\u003e5.4.6 Comparison with Pore-Network Simulations 107\u003c\/p\u003e \u003cp\u003e5.5 Conclusions 108\u003c\/p\u003e \u003cp\u003eAcknowledgment 109\u003c\/p\u003e \u003cp\u003eReferences 109\u003c\/p\u003e \u003cp\u003e\u003cb\u003e6 NMR and Its Applications in Tight Unconventional Reservoir Rocks 113\u003cbr\u003e \u003c\/b\u003e\u003ci\u003eJin-Hong Chen, Mohammed Boudjatit, and Stacey M. Althaus\u003c\/i\u003e\u003c\/p\u003e \u003cp\u003e6.1 Introduction 113\u003c\/p\u003e \u003cp\u003e6.2 Basic NMR Physics 113\u003c\/p\u003e \u003cp\u003e6.2.1 Nuclear Spin 114\u003c\/p\u003e \u003cp\u003e6.2.2 Nuclear Zeeman Splitting and NMR 114\u003c\/p\u003e \u003cp\u003e6.2.3 Nuclear Magnetization 115\u003c\/p\u003e \u003cp\u003e6.2.4 Bloch Equations and NMR Relaxation 116\u003c\/p\u003e \u003cp\u003e6.2.5 Simple NMR Experiments: Free Induction Decay and CPMG Echoes 117\u003c\/p\u003e \u003cp\u003e6.2.6 NMR Relaxation of a Pure Fluid in a Rock Pore 118\u003c\/p\u003e \u003cp\u003e6.2.7 Measured NMR CPMG Echoes in a Formation Rock 119\u003c\/p\u003e \u003cp\u003e6.2.8 Inversion 119\u003c\/p\u003e \u003cp\u003e6.2.8.1 Regularized Linear Least Squares 120\u003c\/p\u003e \u003cp\u003e6.2.8.2 Constrains of the Resulted NMR Spectrum in Inversion 120\u003c\/p\u003e \u003cp\u003e6.2.9 Data from NMR Measurement 121\u003c\/p\u003e \u003cp\u003e6.3 NMR Logging for Unconventional Source Rock Reservoirs 121\u003c\/p\u003e \u003cp\u003e6.3.1 Brief Introduction of Unconventional Source Rocks 121\u003c\/p\u003e \u003cp\u003e6.3.2 NMR Measurement of Source Rocks 122\u003c\/p\u003e \u003cp\u003e6.3.2.1 NMR Log of a Source Rock Reservoir 122\u003c\/p\u003e \u003cp\u003e6.3.3 Pore Size Distribution in a Shale Gas Reservoir 124\u003c\/p\u003e \u003cp\u003e6.4 NMR Measurement of Long Whole Core 125\u003c\/p\u003e \u003cp\u003e6.4.1 Issues of NMR Instrument for Long Sample 125\u003c\/p\u003e \u003cp\u003e6.4.2 HSR-NMR of Long Core 126\u003c\/p\u003e \u003cp\u003e6.4.3 Application Example 128\u003c\/p\u003e \u003cp\u003e6.5 NMR Measurement on Drill Cuttings 130\u003c\/p\u003e \u003cp\u003e6.5.1 Measurement Method 131\u003c\/p\u003e \u003cp\u003e6.5.1.1 Preparation of Drill Cuttings 131\u003c\/p\u003e \u003cp\u003e6.5.1.2 Measurements 131\u003c\/p\u003e \u003cp\u003e6.5.2 Results 132\u003c\/p\u003e \u003cp\u003e6.6 Conclusions 133\u003c\/p\u003e \u003cp\u003eReferences 135\u003c\/p\u003e \u003cp\u003e\u003cb\u003e7 Tight Rock Permeability Measurement in Laboratory: Some Recent Progress 139\u003cbr\u003e \u003c\/b\u003e\u003ci\u003eHui-Hai Liu, Jilin Zhang, and Mohammed Boudjatit\u003c\/i\u003e\u003c\/p\u003e \u003cp\u003e7.1 Introduction 139\u003c\/p\u003e \u003cp\u003e7.2 Commonly Used Laboratory Methods 140\u003c\/p\u003e \u003cp\u003e7.2.1 Steady-State Flow Method 140\u003c\/p\u003e \u003cp\u003e7.2.2 Pressure Pulse-Decay Method 141\u003c\/p\u003e \u003cp\u003e7.2.3 Gas Research Institute Method 143\u003c\/p\u003e \u003cp\u003e7.3 Simultaneous Measurement of Fracture and Matrix Permeabilities from Fractured Core Samples 144\u003c\/p\u003e \u003cp\u003e7.3.1 Estimation of Fracture and Matrix Permeability from PPD Data for Two Flow Regimes 144\u003c\/p\u003e \u003cp\u003e7.3.2 Mathematical Model 146\u003c\/p\u003e \u003cp\u003e7.3.3 Method Validation and Discussion 148\u003c\/p\u003e \u003cp\u003e7.4 Direct Measurement of Permeability-Pore Pressure Function 150\u003c\/p\u003e \u003cp\u003e7.4.1 Knudsen Diffusion, Slippage Flow, and Effective Gas Permeability 150\u003c\/p\u003e \u003cp\u003e7.4.2 Methodology for Directly Measuring Permeability-Pore Pressure Function 152\u003c\/p\u003e \u003cp\u003e7.4.3 Experiments 155\u003c\/p\u003e \u003cp\u003e7.5 Summary and Conclusions 159\u003c\/p\u003e \u003cp\u003eReferences 159\u003c\/p\u003e \u003cp\u003e\u003cb\u003e8 Stress-Dependent Matrix Permeability in Unconventional Reservoir Rocks 163\u003cbr\u003e \u003c\/b\u003e\u003ci\u003eAthma R. Bhandari, Peter B. Flemings, and Sebastian Ramiro-Ramirez\u003c\/i\u003e\u003c\/p\u003e \u003cp\u003e8.1 Introduction 163\u003c\/p\u003e \u003cp\u003e8.2 Sample Descriptions 164\u003c\/p\u003e \u003cp\u003e8.3 Permeability Test Program 165\u003c\/p\u003e \u003cp\u003e8.4 Permeability Behavior with Confining Stress Cycling 166\u003c\/p\u003e \u003cp\u003e8.5 Matrix Permeability Behavior 170\u003c\/p\u003e \u003cp\u003e8.6 Concluding Remarks 172\u003c\/p\u003e \u003cp\u003eAcknowledgments 174\u003c\/p\u003e \u003cp\u003eReferences 174\u003c\/p\u003e \u003cp\u003e\u003cb\u003e9 Assessment of Shale Wettability from Spontaneous Imbibition Experiments 177\u003cbr\u003e \u003c\/b\u003e\u003ci\u003eZhiye Gao and Qinhong Hu\u003c\/i\u003e\u003c\/p\u003e \u003cp\u003e9.1 Introduction 177\u003c\/p\u003e \u003cp\u003e9.2 Spontaneous Imbibition Theory 178\u003c\/p\u003e \u003cp\u003e9.3 Samples and Analytical Methods 179\u003c\/p\u003e \u003cp\u003e9.3.1 SI Experiments 179\u003c\/p\u003e \u003cp\u003e9.3.2 Barnett Shale from United States 180\u003c\/p\u003e \u003cp\u003e9.3.3 Silurian Longmaxi Formation and Triassic Yanchang Formation Shales from China 180\u003c\/p\u003e \u003cp\u003e9.3.4 Jurassic Ziliujing Formation Shale from China 182\u003c\/p\u003e \u003cp\u003e9.4 Results and Discussion 183\u003c\/p\u003e \u003cp\u003e9.4.1 Complicated Wettability of Barnett Shale Inferred Qualitatively from SI Experiments 183\u003c\/p\u003e \u003cp\u003e9.4.1.1 Wettability of Barnett Shale 184\u003c\/p\u003e \u003cp\u003e9.4.1.2 Properties of Barnett Samples and Their Correlation to Wettability 186\u003c\/p\u003e \u003cp\u003e9.4.1.3 Low Pore Connectivity to Water of Barnett Samples 187\u003c\/p\u003e \u003cp\u003e9.4.2 More Oil-Wet Longmaxi Formation Shale and More Water-Wet Yanchang Formation Shale 188\u003c\/p\u003e \u003cp\u003e9.4.2.1 TOC and Mineralogy 188\u003c\/p\u003e \u003cp\u003e9.4.2.2 Pore Structure Difference Between Longmaxi and Yanchang Samples 188\u003c\/p\u003e \u003cp\u003e9.4.2.3 Water and Oil Imbibition Experiments 191\u003c\/p\u003e \u003cp\u003e9.4.2.4 Wettability of Longmaxi and Yanchang Shale Samples Deduced from SI Experiments 197\u003c\/p\u003e \u003cp\u003e9.4.3 Complicated Wettability of Ziliujing Formation Shale 197\u003c\/p\u003e \u003cp\u003e9.4.3.1 TOC and Mineralogy 197\u003c\/p\u003e \u003cp\u003e9.4.3.2 Pore Structure 197\u003c\/p\u003e \u003cp\u003e9.4.3.3 Water and Oil Imbibition Experiments 200\u003c\/p\u003e \u003cp\u003e9.4.3.4 Wettability of Ziliujing Formation Shale Indicated from SI Experiments and its Correlation to Shale Pore Structure and Composition 201\u003c\/p\u003e \u003cp\u003e9.4.4 Shale Wettability Evolution Model 201\u003c\/p\u003e \u003cp\u003e9.5 Conclusions 204\u003c\/p\u003e \u003cp\u003eAcknowledgments 204\u003c\/p\u003e \u003cp\u003eReferences 204\u003c\/p\u003e \u003cp\u003e\u003cb\u003e10 Permeability Enhancement in Shale Induced by Desorption 209\u003cbr\u003e \u003c\/b\u003e\u003ci\u003eBrandon Schwartz and Derek Elsworth\u003c\/i\u003e\u003c\/p\u003e \u003cp\u003e10.1 Introduction 209\u003c\/p\u003e \u003cp\u003e10.1.1 Shale Mineralogical Characteristics 209\u003c\/p\u003e \u003cp\u003e10.1.2 Flow Network 210\u003c\/p\u003e \u003cp\u003e10.1.2.1 Bedding-Parallel Flow Network 211\u003c\/p\u003e \u003cp\u003e10.1.2.2 Bedding-Perpendicular Flow Paths 212\u003c\/p\u003e \u003cp\u003e10.2 Adsorption in Shales 214\u003c\/p\u003e \u003cp\u003e10.2.1 Langmuir Theory 214\u003c\/p\u003e \u003cp\u003e10.2.2 Competing Strains in Permeability Evolution 215\u003c\/p\u003e \u003cp\u003e10.2.2.1 Poro-Sorptive Strain 215\u003c\/p\u003e \u003cp\u003e10.2.2.2 Thermal-Sorptive Strain 218\u003c\/p\u003e \u003cp\u003e10.3 Permeability Models for Sorptive Media 218\u003c\/p\u003e \u003cp\u003e10.3.1 Strain Based Models 219\u003c\/p\u003e \u003cp\u003e10.4 Competing Processes during Permeability Evolution 220\u003c\/p\u003e \u003cp\u003e10.4.1 Resolving Competing Strains 220\u003c\/p\u003e \u003cp\u003e10.4.2 Solving for Sorption-Induced Permeability Evolution 221\u003c\/p\u003e \u003cp\u003e10.5 Desorption Processes Yielding Permeability Enhancement 223\u003c\/p\u003e \u003cp\u003e10.5.1 Pressure Depletion 223\u003c\/p\u003e \u003cp\u003e10.5.2 Lowering Partial Pressure 224\u003c\/p\u003e \u003cp\u003e10.5.3 Sorptive Gas Injection 225\u003c\/p\u003e \u003cp\u003e10.5.4 Desorption with Increased Temperature 225\u003c\/p\u003e \u003cp\u003e10.6 Permeability Enhancement Due to Nitrogen Flooding 225\u003c\/p\u003e \u003cp\u003e10.7 Discussion 226\u003c\/p\u003e \u003cp\u003e10.8 Conclusion 228\u003c\/p\u003e \u003cp\u003eReferences 229\u003c\/p\u003e \u003cp\u003e\u003cb\u003e11 Multiscale Experimental Study on Interactions Between Imbibed Stimulation Fluids and Tight Carbonate Source Rocks 235\u003cbr\u003e \u003c\/b\u003e\u003ci\u003eFeng Liang, Hui-Hai Liu, and Jilin Zhang\u003c\/i\u003e\u003c\/p\u003e \u003cp\u003e11.1 Introduction 235\u003c\/p\u003e \u003cp\u003e11.2 Fluid Uptake Pathways 236\u003c\/p\u003e \u003cp\u003e11.2.1 Experimental Methods 236\u003c\/p\u003e \u003cp\u003e11.2.1.1 Materials 236\u003c\/p\u003e \u003cp\u003e11.2.1.2 Experimental Procedure 237\u003c\/p\u003e \u003cp\u003e11.2.2 Results and Discussion 237\u003c\/p\u003e \u003cp\u003e11.2.2.1 Surface Characterization 237\u003c\/p\u003e \u003cp\u003e11.2.2.2 Spontaneous Imbibition Tests 239\u003c\/p\u003e \u003cp\u003e11.3 Mechanical Property Change After Fluid Exposure 240\u003c\/p\u003e \u003cp\u003e11.3.1 Experimental Methods 242\u003c\/p\u003e \u003cp\u003e11.3.1.1 Materials 242\u003c\/p\u003e \u003cp\u003e11.3.1.2 Experimental Procedure 242\u003c\/p\u003e \u003cp\u003e11.3.2 Results and Discussion 243\u003c\/p\u003e \u003cp\u003e11.3.2.1 UCS and Brazilian Test on Cylindrical Core Plugs 243\u003c\/p\u003e \u003cp\u003e11.3.2.2 Microindentation Test 243\u003c\/p\u003e \u003cp\u003e11.4 Morphology and Minerology Changes After Fluid Exposure 245\u003c\/p\u003e \u003cp\u003e11.4.1 Experimental Methods 247\u003c\/p\u003e \u003cp\u003e11.4.1.1 Materials 247\u003c\/p\u003e \u003cp\u003e11.4.1.2 Experimental Procedure 248\u003c\/p\u003e \u003cp\u003e11.4.2 Results and Discussion 248\u003c\/p\u003e \u003cp\u003e11.4.2.1 SEM and EDS Mapping of Thin-Section Surface before Fluid Treatment 248\u003c\/p\u003e \u003cp\u003e11.4.2.2 SEM and EDS Mapping of Thin-Section Surface after Fluid Treatment 251\u003c\/p\u003e \u003cp\u003e11.4.2.3 Quantification of Dissolved Ions in the Treatment Fluids 256\u003c\/p\u003e \u003cp\u003e11.5 Flow Property Change After Fluid Exposure 257\u003c\/p\u003e \u003cp\u003e11.5.1 Experimental Methods 258\u003c\/p\u003e \u003cp\u003e11.5.1.1 Materials 258\u003c\/p\u003e \u003cp\u003e11.5.1.2 Experimental Procedure 258\u003c\/p\u003e \u003cp\u003e11.5.2 Results and Discussion 258\u003c\/p\u003e \u003cp\u003e11.5.2.1 Changes in Flow Characteristics 258\u003c\/p\u003e \u003cp\u003e11.6 Conclusions 259\u003c\/p\u003e \u003cp\u003eReferences 261\u003c\/p\u003e \u003cp\u003e\u003cb\u003ePart III Large-Scale Petrophysics 265\u003c\/b\u003e\u003c\/p\u003e \u003cp\u003e\u003cb\u003e12 Effective Permeability in Fractured Reservoirs: Percolation-Based Effective-Medium Theory 267\u003cbr\u003e \u003c\/b\u003e\u003ci\u003eBehzad Ghanbarian\u003c\/i\u003e\u003c\/p\u003e \u003cp\u003e12.1 Introduction 267\u003c\/p\u003e \u003cp\u003e12.1.1 Percolation Theory 267\u003c\/p\u003e \u003cp\u003e12.1.2 Effective-Medium Theory 268\u003c\/p\u003e \u003cp\u003e12.2 Objectives 269\u003c\/p\u003e \u003cp\u003e12.3 Percolation-Based Effective-Medium Theory 269\u003c\/p\u003e \u003cp\u003e12.4 Comparison with Simulations 270\u003c\/p\u003e \u003cp\u003e12.4.1 Chen et al. (2019) 270\u003c\/p\u003e \u003cp\u003e12.4.1.1 Two-Dimensional Simulations 271\u003c\/p\u003e \u003cp\u003e12.4.1.2 Three-Dimensional Simulations 273\u003c\/p\u003e \u003cp\u003e12.4.2 New Three-Dimensional Simulations 274\u003c\/p\u003e \u003cp\u003e12.5 Conclusion 275\u003c\/p\u003e \u003cp\u003eAcknowledgment 277\u003c\/p\u003e \u003cp\u003eReferences 277\u003c\/p\u003e \u003cp\u003e\u003cb\u003e13 Modeling of Fluid Flow in Complex Fracture Networks for Shale Reservoirs 281\u003cbr\u003e \u003c\/b\u003e\u003ci\u003eHongbing Xie, Xiaona Cui, Wei Yu, Chuxi Liu, Jijun Miao, and Kamy Sepehrnoori\u003c\/i\u003e\u003c\/p\u003e \u003cp\u003e13.1 Shale Reservoirs with Complex Fracture Networks 281\u003c\/p\u003e \u003cp\u003e13.2 Complex Fracture Reservoir Simulation 281\u003c\/p\u003e \u003cp\u003e13.3 Embedded Discrete Fracture Model 283\u003c\/p\u003e \u003cp\u003e13.4 EDFM Verification 286\u003c\/p\u003e \u003cp\u003e13.5 Well Performance Study – Base Case 290\u003c\/p\u003e \u003cp\u003e13.6 Effect of Natural Fracture Connectivity on Well Performance 294\u003c\/p\u003e \u003cp\u003e13.6.1 Effect of Natural Fracture Azimuth 294\u003c\/p\u003e \u003cp\u003e13.6.2 Effect of Number of Natural Fractures 295\u003c\/p\u003e \u003cp\u003e13.6.3 Effect of Natural Fracture Length 298\u003c\/p\u003e \u003cp\u003e13.6.4 Effect of Number of Sets of Natural Fractures 301\u003c\/p\u003e \u003cp\u003e13.6.5 Effect of Natural Fracture Dip Angle 305\u003c\/p\u003e \u003cp\u003e13.7 Effect of Natural Fracture Conductivity on Well Performance 306\u003c\/p\u003e \u003cp\u003e13.8 Conclusions 311\u003c\/p\u003e \u003cp\u003eReferences 312\u003c\/p\u003e \u003cp\u003e\u003cb\u003e14 A Closed-Form Relationship for Production Rate in Stress-Sensitive Unconventional Reservoirs 315\u003cbr\u003e \u003c\/b\u003e\u003ci\u003eHui-Hai Liu, Huangye Chen, and Yanhui Han\u003c\/i\u003e\u003c\/p\u003e \u003cp\u003e14.1 Introduction 315\u003c\/p\u003e \u003cp\u003e14.2 Production Rate as a Function of Time in the Linear Flow Regime Under the Constant Pressure Drawdown Condition 317\u003c\/p\u003e \u003cp\u003e14.3 An Approximate Relationship Between Parameter A and Stress-Dependent Permeability 318\u003c\/p\u003e \u003cp\u003e14.4 Evaluation of the Relationship Between Parameter A and Stress-Dependent Permeability 321\u003c\/p\u003e \u003cp\u003e14.5 Equivalent State Approximation for the Variable Pressure Drawdown Conditions 327\u003c\/p\u003e \u003cp\u003e14.6 Discussions 328\u003c\/p\u003e \u003cp\u003e14.7 Concluding Remarks 329\u003c\/p\u003e \u003cp\u003eNomenclature 329\u003c\/p\u003e \u003cp\u003eSubscript 330\u003c\/p\u003e \u003cp\u003eAppendix 14.A Derivation of Eq. (14.22) with Integration by Parts 330\u003c\/p\u003e \u003cp\u003eReferences 331\u003c\/p\u003e \u003cp\u003e\u003cb\u003e15 Sweet Spot Identification in Unconventional Shale Reservoirs 333\u003cbr\u003e \u003c\/b\u003e\u003ci\u003eRabah Mesdour, Mustafa Basri, Cenk Temizel, and Nayif Jama\u003c\/i\u003e\u003c\/p\u003e \u003cp\u003e15.1 Introduction 333\u003c\/p\u003e \u003cp\u003e15.2 Reservoir Characterization 334\u003c\/p\u003e \u003cp\u003e15.3 Sweet Spot Identification 334\u003c\/p\u003e \u003cp\u003e15.3.1 The Method Based on Organic, Rock and Mechanical Qualities 335\u003c\/p\u003e \u003cp\u003e15.3.2 Methods Based on Geological and Engineering Sweet Spots 337\u003c\/p\u003e \u003cp\u003e15.3.3 Methods Based on Other Quality Indicators 340\u003c\/p\u003e \u003cp\u003e15.3.4 Methods Based on Data Mining and Machine Learning 343\u003c\/p\u003e \u003cp\u003e15.4 Discussion 345\u003c\/p\u003e \u003cp\u003e15.5 Conclusion 346\u003c\/p\u003e \u003cp\u003eReferences 347\u003c\/p\u003e \u003cp\u003eIndex 351\u003c\/p\u003e  \u003cp\u003e\u003cb\u003eBehzad Ghanbarian, PhD\u003c\/b\u003e is Associate Professor of Engineering Geology and Director of the Porous Media Research Lab in the Department of Geology, Kansas State University, Manhattan, Kansas, USA. \u003c\/p\u003e\u003cp\u003e\u003cb\u003eFeng Liang, PhD\u003c\/b\u003e is Production Technology Leader at Aramco Research Center Houston, Aramco Americas, Houston, Texas, USA. \u003c\/p\u003e\u003cp\u003e\u003cb\u003eHui-Hai Liu, PhD\u003c\/b\u003e is a Senior Petroleum Engineering Consultant at Aramco Research Center Houston, Aramco Americas, Houston, Texas, USA.   \u003c\/p\u003e\u003cp\u003e\u003cb\u003eUnderstanding and predicting fluid flow in hydrocarbon shale and other non-conventional reservoir rocks\u003c\/b\u003e \u003c\/p\u003e\u003cp\u003eOil and natural gas reservoirs found in shale and other tight and ultra-tight porous rocks have become increasingly important sources of energy in both North America and East Asia. As a result, extensive research in recent decades has focused on the mechanisms of fluid transfer within these reservoirs, which have complex pore networks at multiple scales. Continued research into these important energy sources requires detailed knowledge of the emerging theoretical and computational developments in this field. \u003c\/p\u003e\u003cp\u003eFollowing a multidisciplinary approach that combines engineering, geosciences and rock physics, \u003ci\u003ePhysics of Fluid Flow and Transport in Unconventional Reservoir Rocks\u003c\/i\u003e provides both academic and industrial readers with a thorough grounding in this cutting-edge area of rock geology, combining an explanation of the underlying theories and models with practical applications in the field.  \u003c\/p\u003e\u003cp\u003eReaders will also find: \u003c\/p\u003e\u003cul\u003e\n\u003cli\u003eAn introduction to the digital modeling of rocks\u003c\/li\u003e \u003cli\u003eDetailed treatment of digital rock physics, including decline curve analysis and non-Darcy flow\u003c\/li\u003e \u003cli\u003eSolutions for difficult-to-acquire measurements of key petrophysical characteristics such as shale wettability, effective permeability, stress sensitivity, and sweet spots\u003c\/li\u003e\n\u003c\/ul\u003e \u003cp\u003e\u003ci\u003ePhysics of Fluid Flow and Transport in Unconventional Reservoir Rocks\u003c\/i\u003e is a  fundamental resource for academic and industrial researchers in hydrocarbon exploration, fluid flow, and rock physics, as well as professionals in related fields.\u003c\/p\u003e","brand":"Wiley","offers":[{"title":"Default Title","offer_id":47989790507237,"sku":"NP9781119729877","price":195.0,"currency_code":"USD","in_stock":false}],"thumbnail_url":"\/\/cdn.shopify.com\/s\/files\/1\/1842\/7735\/files\/9781119729877.jpg?v=1761785478","url":"https:\/\/k12savings.com\/es\/products\/physics-of-fluid-flow-and-transport-in-unconventional-reservoir-rocks-isbn-9781119729877","provider":"K12savings","version":"1.0","type":"link"}