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A Fully Three Dimensional Semianalytical Model for Shale Gas Reservoirs with Hydraulic Fractures

Figure 2. Illustrations of dimensionless pressure distributions for various shapes of fractures.

A Fully Three Dimensional Semianalytical Model for Shale Gas Reservoirs with Hydraulic Fractures   The shale gas diffusion equations considers complex transport mechanism such as gas slippage and gas diffusion. This semianalytical model is verified with a commercial software and an analytical method for single fully penetrated rectangle fracture, and the production

Hydraulic Fracture Design with a Proxy Model for Unconventional Shale Gas Reservoir with Considering Feasibility Study

Figure 6. Natural fracture generation and upscaling in 3D grid systems—(a) natural fracture generation, (b) fracture porosity, (c) sigma factor, (d) fracture permeability, x, (e) fracture permeability, y, and (f) facture permeability, z.

Hydraulic Fracture Design with a Proxy Model for Unconventional Shale Gas Reservoir with Considering Feasibility Study The proxy model uses a robust regression scheme and can replace a commercial reservoir simulator. The proxy model proposed can determine the influence of impact factors on the production at each production time. The calculation

An Analytical Flow Model for Heterogeneous Multi-Fractured Systems in Shale Gas Reservoirs

Figure 1. Schematic of physical models for hydraulically fractured horizontal wells. (a) The typical five-region flow model proposed by Stalgorova and Mattar [10]. (b) The improved five-region flow model (new model). Fracture half-length: xf; width of the hydraulic fracture: wD; distance from the hydraulic fracture to stimulated reservoir volume (SRV): y1; no flow bound: x2,y2.

An Analytical Flow Model for Heterogeneous Multi-Fractured Systems in Shale Gas Reservoirs Tang et al. [4] established a three-dimensional numerical model based on the construction of spatial discretization by the finite volume method. Wang [5] proposed a unified model for shale gas reservoirs based on discrete fracture networks to investigate shale

Numerical Study of Simultaneous Multiple Fracture Propagation in Changning Shale Gas Field

Figure 1. Three transverse fractures with a uniform spacing of 23.3 m in a single stage.

Numerical Study of Simultaneous Multiple Fracture Propagation in Changning Shale Gas Field A series of case studies were investigated to analyze the effects of engineering parameters on simultaneous multiple fracture propagation. The fracture spacing, perforating number, injection rate, fluid viscosity and number of fractures within one stage were considered. The simulation

An Analytical Model for Capturing the Decline of Fracture Conductivity in the Tuscaloosa Marine Shale Trend from Production Data

Figure 1. Schematic chart between two fractures. (a) Virtual boundary between two fractures. (b) Schematic chart of pressure distribution.

An Analytical Model for Capturing the Decline of Fracture Conductivity in the Tuscaloosa Marine Shale Trend from Production Data Production data analyses with the model revealed that the pressure-dependent fracture conductivity in the TMS in the Mississippi section declines following a logarithmic mode, with dimensionless coefficient χ varying between 0.116 and

Comparative Porosity and Pore Structure Assessment in Shales: Measurement Techniques, Influencing Factors and Implications for Reservoir Characterization

Figure 1. The porosity values obtained from mercury intrusion capillary pressure (MICP), Helium, and nuclear magnetic resonance (NMR) for two different shale formations.

Comparative Porosity and Pore Structure Assessment in Shales: Measurement Techniques, Influencing Factors and Implications for Reservoir Characterization Porosity and PSD have been interpreted based on nuclear magnetic resonance (NMR), low-pressure N2 gas adsorption (LP-N2-GA), mercury intrusion capillary pressure (MICP) and helium expansion porosimetry. The results highlight NMR with the advantage of detecting

A Data-Driven Workflow Approach to Optimization of Fracture Spacing in Multi-Fractured Shale Oil Wells

Figure 1. Twelve hydraulic fractures developed from 12 perforation clusters in three stages of fracturing.

A Data-Driven Workflow Approach to Optimization of Fracture Spacing in Multi-Fractured Shale Oil Wells This offers a reliable and cost-effective means for assessment of well production potential in terms of optimization of fracture spacing in the MFHW. Result of a field case study indicated that three wells were drilled in an

Using Cohesive Zone Model to Simulate the Hydraulic Fracture Interaction with Natural Fracture in Poro-Viscoelastic Formation

Figure 8. Crack geometry in different fracturing fluid injection rate.

Using Cohesive Zone Model to Simulate the Hydraulic Fracture Interaction with Natural Fracture in Poro-Viscoelastic Formation The numerical procedure for hydraulically driven fracture propagation uses a poro-viscoelasticity theory to describe the fluid diffusion and matrix creep in the solid skeleton, in conjunction with pore-pressure cohesive zone model and ABAQUS was used

Analysis of Pressure Communication between the Austin Chalk and Eagle Ford Reservoirs during a Zipper Fracturing Operation PART 2

Analysis of Pressure Communication between the Austin Chalk and Eagle Ford Reservoirs

PART 2 Analysis of Pressure Communication between the Austin Chalk and Eagle Ford Reservoirs during a Zipper Fracturing Operation Interpretation of Results The principal purpose of our study is to develop a conceptual model for the observed pressure communication between the two reservoirs (Eagle Ford and Austin Chalk). The estimated pressure acting on

Analysis of Pressure Communication between the Austin Chalk and Eagle Ford Reservoirs during a Zipper Fracturing Operation

Figure 2. (a) RELLIS wellbore trajectories. The white arrows represent the surface location of each well. The dotted outline represents the landing zone.

Analysis of Pressure Communication between the Austin Chalk and Eagle Ford Reservoirs during a Zipper Fracturing Operation Our study presents field data collected in fall 2017 that measured the annular pressure changes that occurred in Austin Chalk wells during the zipper fracturing treatment of two new wells in the underlying Eagle

Hydraulic Fracture Design with a Proxy Model for Unconventional Shale Gas Reservoir with Considering Feasibility Study

Figure 5. Shale gas reservoir in 3D grid systems—(a) matrix permeability, (b) matrix porosity, and (c) hydraulic fracturing design.

Hydraulic Fracture Design with a Proxy Model for Unconventional Shale Gas Reservoir with Considering Feasibility Study The proxy model uses a robust regression scheme and can replace a commercial reservoir simulator.  The proxy model proposed can determine the influence of impact factors on the production at each production time. The calculation

Retention of Hydraulic Fracturing Water in Shale: The Influence of Anionic Surfactant

Figure 5. The Energy-Dispersive X-Ray (EDX) spectra of (a) BG-2 and (b) KH-2 shales with a corresponding miniature FE-SEM images.

Retention of Hydraulic Fracturing Water in Shale: The Influence of Anionic Surfactant However, the role of some surface active agents like surfactants that are added in the hydraulic fracturing mixture in this issue needs to be understood. In this study, the influence of Internal Olefin Sulfate (IOS), which is an anionic

Integrating Embedded Discrete Fracture and Dual-Porosity, Dual-Permeability Methods to Simulate Fluid Flow in Shale Oil Reservoirs

Figure 1. Fracture density and fracture length correlation.

Integrating Embedded Discrete Fracture and Dual-Porosity, Dual-Permeability Methods to Simulate Fluid Flow in Shale Oil Reservoirs Most previous simulation studies have been based on dual porosity, but simulation results from dual-porosity models have not been as accurate as discrete fracture models in composition modeling. This study proposes a new model that integrates

A Prediction Model for Methane Adsorption capacity in Shale Gas Reservoirs

Figure 3. The relationship between the clay content and Langmuir volume at experimental temperature for low, medium and high TOC shale samples.

A Prediction Model for Methane Adsorption capacity in Shale Gas Reservoirs   The model was established in four steps: a model of Langmuir volume at experimental temperature, the temperature dependence of Langmuir volume, a model of Langmuir pressure, the temperature dependence of Langmuir pressure. In the model of Langmuir volume at experimental

Imbibition — the “old all new”​production mechanism of shale gas and oil

Imbibition --- the "old all new"​ production mechanism of shale gas and oil

Imbibition --- the "old all new"​production mechanism of shale gas and oil Conventional oil and gas production mechanisms   Such conventional transport mechanism is well understood and also believed to be the dominant transport mechanism in shale gas and oil production. Under such conventional production mechanism, it is widely accepted that there is the

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