Download or read book Modeling of Gas Transport in Shale Matrix from Nanoscale to Reservoir Scale written by Keliu Wu and published by Elsevier. This book was released on 2024-10-01 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: Engineers continue to understand shale gas reservoirs and how to improve well productivity. One aspect is through pore transport, but this is an advanced level of research unlike any conventional method or model. Modeling of Gas Transport in Shale Matrix from Nanoscale to Reservoir Scale delivers a necessary reference to engineers and researchers on how to approach, model, and validate gas transport through multi-scale phenomena. Bridging between theory and practical, the reference walks the engineer through the scope of the project, establishing a model, illustrating the case study through workflow charts and follow up actions needed, then rounds out with project results, remaining challenges, and future references to advance learning. Supported from a strong group of experts in the field, Modeling of Gas Transport in Shale Matrix from Nanoscale to Reservoir Scale gives today's engineers and researchers the most advanced research and field application knowledge to understand unconventional shale gas and increase overall well productivity.
Download or read book Modelling in Nanoporous Shale written by Liehui Zhang and published by Springer. This book was released on 2024-10-26 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: This book addresses the problems involved in the modelling and simulation of shale gas reservoirs at pore scale, and details recent advances in the field. It presents the construction of simulation methods, mainly using the lattice Boltzmann method (LBM), that describe sorption, flow, and transport in nanoporous shale with some case studies. This book highlights the nanoscale effects, ascribed to the large surface-to-volume ratio, on fluids occurrence and transport physics. It discusses some interesting phenomena occurs at nanoporous shale, such as absorbed water film, water condensation, sorption hysteresis, surface excess adsorption, Knudsen diffusion, surface diffusion, structural fluid density, no-slip boundary, etc. The key techniques and methods introduced in this book provide the basis for accurate prediction of gas-well productivity. The basic principles and modeling methods are also relevant to many other nanoporous applications in science and engineering. The book aims to provide a valuable reference resource for researchers and professional scientists and engineers working on shale gas development and nanoporous media research.
Download or read book Laboratory Estimation and Modeling of Apparent Permeability for Ultra Tight Anthracite and Shale Matrix written by Yi Wang and published by . This book was released on 2017 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: Gas production from unconventional reservoirs such as gas shale and coalbed methane (CBM) has become a major source of clean energy in the United States. Reservoir apparent permeability is a critical and controlling parameter for the predictions of shale gas and coalbed methane (CBM) productions. Shale matrix and tight anthracite are characterized by ultra-tight pore structure and low permeability at micro- and nano-scale with gas molecules stored by adsorption. Gas transport in shale and anthracite matrices no longer always falls into the continuum flow regime described by Darcys law, rather a considerable portion of transport is sporadic and irregular due to the mean free path of gas is comparable to the prevailing pore scale. Therefore, gas transport in both anthracite and shale will be a complicated nonlinear multi-mechanistic process. A multi-mechanistic flow process is always happening during shale gas and CBM production, including Darcy viscous flow, slip flow, transition flow and Knudsen diffusion and their proportional contributions to apparent permeability are constantly changing with continuous reservoir depletion. The complexity of the gas storage and flow mechanisms in ultra-fine pore structure is diverse and makes it more difficult to predict the matrix permeability and gas deliverability. In this study, a multi-mechanistic apparent-permeability model for unconventional reservoir rocks (shale and anthracite) was derived under different stress boundary conditions (constant-stress and uniaxial-strain). The proposed model incorporates the pressure-dependent weighting coefficients to separate the contributions of Knudsen diffusion and Darcy flow on matrix permeability. A combination of both permeability components was coupled with pressure-dependent weighting coefficients. A stressstrain relationships for a linear elastic gas-desorbing porous medium under hydrostatic stress condition was derived from thermal-elastic equations and can be incorporated into the Darcian flow component, serving for the permeability data under hydrostatic stress. The modeled results well agree with anthracite and shale sample permeability measured data.In this study, laboratory measurements of gas apparent permeability were conducted on coal and shale samples for both helium and CO2 injection/depletion under different stress conditions. At low pressure under constant stress condition, CO2 permeability enhancement due to sorption-induced matrix shrinkage effect is significant, which can be either clearly observed from the pulse-decay pressure response curves or the data reduced by Cui et al.s method. CO2 apparent permeability can be higher than He at pressure higher than 1000 psi, which may be resulted from limited shale adsorption capacity. Helium permeability is more sensitive to the variation of Terzaghi effective stress than CO2 and it is independent of pore pressure. The true effective stress coefficient can be found two values at low pressure region (500 psi) and high pressure region (500 psi). The negative value indicates Knudsen diffusion and slip flow effect have more impact on apparent permeability than Terzaghi stress at low pressure. Additionally, laboratory measurements of gas sorption, Knudsen diffusion coefficient and coal deformation were conducted to break down the key effects that influence gas permeability evolution. Adsorption isotherms of crushed anthracite coal samples was measured using Gibbs adsorption principle at different gas pressures. The adsorption isotherm result showed that the adsorption capacity at low pressure changes with a higher rate and thus brings a significant sorption-induced rock matrix swelling/shrinkage effect. And the isotherm data are important inputs for the Darcy permeability models. The latter was coupled in the apparent-permeability model as the Darcy flow component which involves the sorption-induced strain component. Diffusion coefficients of the pulverized samples were estimated by using the particle method and was used to calculate the effective Knudsen permeability. The Knudsen diffusion flow component in the proposed apparent-permeability model was constructed by transforming Knudsen mass flux into permeability term and used to match the effective Knudsen permeability based on diffusion data. Increasing trends for all results were performed during pressure drop down in the result plots. And the modeling result showed very good agreements with them, giving a solid proof of the availability of Knudsen diffusion component as part of the proposed model. The results of a series of experimental measurements of coal deformation with gas injection and depletion revealed that the coal sorption induced deformation exhibits anisotropy, with larger deformation in direction perpendicular to bedding than those parallel to the bedding planes. The deformation of coal is reversible for helium and methane with injection/depletion, but not for CO2. Based on the modeling results, it was found that application of isotropic deformation in permeability model can overestimate the permeability loss compared to anisotropic deformation. This demonstrates that the anisotropic coal deformation should be considered to predict the permeability behavior of CBM as well as CO2 sequestration/ECBM projects.
Download or read book Transport in Shale Reservoirs written by Kun Sang Lee and published by Gulf Professional Publishing. This book was released on 2019-02-20 with total page 150 pages. Available in PDF, EPUB and Kindle. Book excerpt: Transport in Shale Reservoirs fills the need for a necessary, integrative approach on shale reservoirs. It delivers both the fundamental theories of transport in shale reservoirs and the most recent advancements in the recovery of shale oil and gas in one convenient reference. Shale reservoirs have distinctive features dissimilar to those of conventional reservoirs, thus an accurate evaluation on the behavior of shale gas reservoirs requires an integrated understanding on their characteristics and the transport of reservoir and fluids. Updates on the various transport mechanisms in shale, such as molecular diffusion and phase behavior in nano-pores Applies theory to practice through simulation in both shale oil and gas Presents an up-to-date reference on remaining challenges, such as organic material in the shale simulation and multicomponent transport in CO2 injection processes
Download or read book Challenges in Modelling and Simulation of Shale Gas Reservoirs written by Jebraeel Gholinezhad and published by Springer. This book was released on 2017-12-27 with total page 96 pages. Available in PDF, EPUB and Kindle. Book excerpt: This book addresses the problems involved in the modelling and simulation of shale gas reservoirs, and details recent advances in the field. It discusses various modelling and simulation challenges, such as the complexity of fracture networks, adsorption phenomena, non-Darcy flow, and natural fracture networks, presenting the latest findings in these areas. It also discusses the difficulties of developing shale gas models, and compares analytical modelling and numerical simulations of shale gas reservoirs with those of conventional reservoirs. Offering a comprehensive review of the state-of-the-art in developing shale gas models and simulators in the upstream oil industry, it allows readers to gain a better understanding of these reservoirs and encourages more systematic research on efficient exploitation of shale gas plays. It is a valuable resource for researchers interested in the modelling of unconventional reservoirs and graduate students studying reservoir engineering. It is also of interest to practising reservoir and production engineers.
Download or read book Mathematical Modeling of Fluid Flow and Heat Transfer in Petroleum Industries and Geothermal Applications written by Mehrdad Massoudi and published by MDPI. This book was released on 2020-04-16 with total page 470 pages. Available in PDF, EPUB and Kindle. Book excerpt: Geothermal energy is the thermal energy generated and stored in the Earth's core, mantle, and crust. Geothermal technologies are used to generate electricity and to heat and cool buildings. To develop accurate models for heat and mass transfer applications involving fluid flow in geothermal applications or reservoir engineering and petroleum industries, a basic knowledge of the rheological and transport properties of the materials involved (drilling fluid, rock properties, etc.)—especially in high-temperature and high-pressure environments—are needed. This Special Issue considers all aspects of fluid flow and heat transfer in geothermal applications, including the ground heat exchanger, conduction and convection in porous media. The emphasis here is on mathematical and computational aspects of fluid flow in conventional and unconventional reservoirs, geothermal engineering, fluid flow, and heat transfer in drilling engineering and enhanced oil recovery (hydraulic fracturing, CO2 injection, etc.) applications.
Download or read book Advancements of Phase Behavior and Fluid Transport in Petroleum Reservoirs written by Xiaohu Dong and published by Frontiers Media SA. This book was released on 2022-06-30 with total page 102 pages. Available in PDF, EPUB and Kindle. Book excerpt:
Download or read book Pore Scale Study of Gas Sorption and Transport in Shale Nanopore Systems written by Rui Xu (Ph. D.) and published by . This book was released on 2019 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: Shale gas production accounts for about 70% of the total natural gas production in the US. Yet it remains a nontrivial task to characterize the petrophysical properties of shale core samples either by experimental analysis or numerical simulations. Shale matrix has low porosity and permeability resulting from nanometer-scale pore sizes. Surface properties of shale can be quite inhomogeneous arising from complex mineralogy and diagenesis. Heterogeneous morphology and topology of the pore structure poses significant challenges on understanding fluid distribution and flow capacity. Pore scale simulations provide insight into the fundamental mechanisms of thermodynamics and hydrodynamics in tight porous materials, and can supplement experimental characterization of shale petrophysical properties (e.g. absolute/relative permeability, capillary pressure curves). However, challenges exist in creating representative pore structures tailored for specific simulation tools, incorporating the appropriate and relevant physics for the problems to be simulated, and interpreting, calibrating, or validating the simulation results. In this work, we used two types of pore scale simulation tools, namely pore network modeling (PNM) and lattice Boltzmann method (LBM), to study gas adsorption/desorption and transport behavior in shale matrix. For the first part of the work, a dual-scale PNM was integrated with lattice density functional theory (LDFT) to study nitrogen adsorption/desorption in mesoporous materials with pore sizes smaller than 200 nm. Critical pore structure parameters (i.e. porosity, pore size distribution, and pore throat connectivity) were characterized by calibrating the simulated nitrogen sorption isotherms to experimental results, and were then used to construct PNMs to study supercritical methane transport. We found that the pore structure characterization results were nonunique and highly dependent on the assumed pore shape. Scanning electron microscope (SEM) images were used to further constrain the description of pore shapes. Advection and diffusion of methane at reservoir conditions were simulated and compared, and suggestions were made regarding the choice of representative pore shape in PNMs for single phase advection/diffusion calculations. We next used LBM to study two-phase thermodynamic and hydrodynamic problems in nanopore systems in shale. Both 2D and 3D LBM models were developed with consideration of mesoscale fluid-fluid and solid-fluid interactions to model gas adsorption in complex geometries, and phase separation occurs automatically without the need to track the interface. This overcomes the pore shape deficiency of PNMs in cases where nanoporous media reconstruction exists. LBM models were then calibrated to LDFT and validated against experimental adsorption data for both subcritical and supercritical gases for the first time. We studied and compared nitrogen sorption hysteresis in two model nanopore system reconstructions representing the interparticle and intraparticle pores in shale. As another example of many possible applications of our developed model, we studied water adsorption and condensation in a reconstructed clay pore structure based on SEM image analysis, and explored the effect of surface wettability on adsorbed/condensed water distribution and connectivity. Supercritical methane flow simulations with the existence of condensed water were conducted using a 3D hydrodynamic LBM model that considers nanoscale flow physics for high Knudsen number flow. The relative permeability of methane as a function of water saturation and surface wettability was calculated and compared to available experimental data measured on geosynthetic clay liners. We demonstrated the wide applicability of our model and suggested future applications
Download or read book Gas Transport in Porous Media written by Edward Allen Mason and published by . This book was released on 1983 with total page 212 pages. Available in PDF, EPUB and Kindle. Book excerpt: This monograph gives an historical account of the development of the dusty-gas model for the description of gas transport in porous media, and describes the model and its applications in sufficient detail that it can be employed in engineering practice.
Download or read book Fundamentals of Gas Shale Reservoirs written by Reza Rezaee and published by John Wiley & Sons. This book was released on 2015-07-01 with total page 417 pages. Available in PDF, EPUB and Kindle. Book excerpt: Provides comprehensive information about the key exploration, development and optimization concepts required for gas shale reservoirs Includes statistics about gas shale resources and countries that have shale gas potential Addresses the challenges that oil and gas industries may confront for gas shale reservoir exploration and development Introduces petrophysical analysis, rock physics, geomechanics and passive seismic methods for gas shale plays Details shale gas environmental issues and challenges, economic consideration for gas shale reservoirs Includes case studies of major producing gas shale formations
Download or read book Nanoscale Fluid Transport written by Tuan Anh Ho and published by Springer. This book was released on 2016-09-29 with total page 95 pages. Available in PDF, EPUB and Kindle. Book excerpt: This thesis demonstrates how molecular modeling techniques can be used to gain significant insights into numerous applications that are increasingly attracting research interest because of their societal importance. It presents innovative ideas that, by altering the fundamental physical phenomena occurring at the solid/liquid interface, allow the fluid transport in nanochannels to be manipulated so as to improve the performance of the practical applications. The applications explicitly considered in this thesis are the design of drag-reducing and self-cleaning surfaces; water desalination; and shale gas exploration – all of which are, to some extent, governed by nanoscale fluid transport. Overall, this thesis is useful for students and researchers entering the field who wish to understand how molecular modeling can improve the performance in a wide range of applications.
Download or read book Mechanism Model and Upscaling of the Gas Flow in Shale Matrix written by Yaxiong Li and published by . This book was released on 2018 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: Shale gas accounts for an increasing proportion in the world,Äôs oil and gas supply, with the properties of low carbon, clean production, and huge potential for the compensation for the gradually depleted conventional resources. Due to the ubiquitous nanopores in shale matrix, the nanoscale gas flow becomes one of the most vital themes that are directly related to the formulation of shale gas development schemes, including the optimization of hydraulic fracturing, horizontal well spacing, etc. With regard to the gas flow in shale matrix, no commonly accepted consensus has been reached about the flow mechanisms to be considered, the coupled flow model in nanopores, and the upscaling method for its macroscopic form. In this chapter, the propositions of wall-associated diffusion, a physically sound flow mechanism scheme, a new coupled flow model in nanopores, the upscaling form of the proposed model, and the translation of lab-scale results into field-scale ones aim to solve the aforementioned issues. It is expected that this work will contribute to a deeper understanding of the intrinsic relationship among various flow mechanisms and the extension of the flow model to full flow regimes and to upscaling shale matrix, thus establishing a unified model for better guiding shale gas development.
Download or read book Study of Multi scale Transport Phenomena in Tight Gas and Shale Gas Reservoir Systems written by Craig Matthew Freeman and published by . This book was released on 2014 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: The hydrocarbon resources found in shale reservoirs have become an important energy source in recent years. Unconventional geological and engineering features of shale systems pose challenges to the characterization of these systems. These challenges have impeded efficient economic development of shale resources. New fundamental insights and tools are needed to improve the state of shale gas development. Few attempts have been made to model the compositional behavior of fluids in shale gas reservoirs. The transport and storage of reservoir fluids in shale is controlled by multiple distinct micro-scale physical phenomena. These phenomena include preferential Knudsen diffusion, differential desorption, and capillary critical effects. Together, these phenomena cause significant changes in fluid composition in the subsurface and a measureable change in the composition of the produced gas over time. In order to quantify this compositional change we developed a numerical model describing the coupled processes of desorption, diffusion, and phase behavior in heterogeneous ultra-tight rocks as a function of pore size. The model captures the various configurations of fractures induced by shale gas fracture stimulation. Through modeling of the physics at the macro-scale (e.g. reservoir-scale hydraulic fractures) and micro-scale (e.g. Knudsen diffusion in kerogen nanopores), we illustrate how and why gas composition changes spatially and temporally during production. We compare the results of our numerical model against measured composition data obtained at regular intervals from shale gas wells. We utilize the characteristic behaviors explicated by the model results to identify features in the measured data. We present a basis for a new method of production data analysis incorporating gas composition measurements in order to develop a more complete diagnostic process. Distinct fluctuations in the flowing gas composition are shown to uniquely identify the onset of fracture interference in horizontal wells with multiple transverse hydraulic fractures. The timescale and durations of the transitional flow regimes in shales are quantified using these measured composition data. These assessments appear to be robust even for high levels of noise in the rate and pressure data. Integration of the compositional shift analysis of this work with modern production analysis is used to infer reservoir properties. This work extends the current understanding of flow behavior and well performance for shale gas systems to encompass the physical phenomena leading to compositional change. This new understanding may be used to aid well performance analysis, optimize fracture and completion design, and improve the accuracy of reserves estimates. In this work we contribute a numerical model which captures multicomponent desorption, diffusion, and phase behavior in ultra-tight rocks. We also describe a workflow for incorporating measured gas composition data into modern production analysis. The electronic version of this dissertation is accessible from http://hdl.handle.net/1969.1/151782
Download or read book Modelling Shale Gas Flow Using the Concept of Dynamic Apparent Permeability written by Syed Munib Ullah Farid and published by . This book was released on 2015 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: The basic idea behind this research is to propose a work flow to model gas flow in numerical simulators, which would take into consideration all the complexities of the multiple porosity systems that exist in shale matrix and the different dynamics of flow involved within them. The concept of a multi porosity system that is composed of the organic part (kerogen), inorganic matter, and natural and hydraulic fractures is used here. Kerogen is very different from other shale components because of its highly porous nature, capability to adsorb gas and abundance of nano-pores on its surface. Some theories have been put forward for the physics involved in shale on a micro scale level. However, when working with reservoir scale models, the details as described for porosity systems in micro scale models is lost. To overcome this problem, the idea of dynamic apparent permeability, which is a function of matrix pressure, is used. It helps in up-scaling the particulars of the micro scale model to a reservoir one and aids in modelling Darcy flow, Fickian diffusion and transition flow in between the matrix and fractures. Our assumptions are validated by working with the case of a horizontal well model, producing gas from the Barnett shale formation, that doesn't take into consideration the relevant flow phenomenon. History matching the model after integrating diffusion and desorption reveals that considering these additional processes impacts the assumed SRV region, affecting its volume as well as its properties. This would be a critical factor in optimizing completion design, to lower down the well cost for same or ever greater production. Similarly, this can play a vital role in well spacing for effective field development. We summarize our findings from production forecasts that matrix contribution towards production is under estimated when relevant assumptions for shale are not modelled. This signifies the importance of better understating the transport phenomenon occurring in shale, which would enable us to have a greater insight to scrutinize production data and later to predict changes in production as completion methods are changed. This means that a multi stage high density fracturing job might not optimize the well in terms of its value. Decreasing our expenditure on well completions, such that their design results in lower production rates at the initial time period along with lower decline rates, would enable us to produce these wells longer for the same recovery. This would enable us to push the production in future where oil and gas prices might be better. The electronic version of this dissertation is accessible from http://hdl.handle.net/1969.1/155074
Download or read book A Novel Approach For the Simulation of Multiple Flow Mechanisms and Porosities in Shale Gas Reservoirs written by Bicheng Yan and published by . This book was released on 2013 with total page 64 pages. Available in PDF, EPUB and Kindle. Book excerpt: The state of the art of modeling fluid flow in shale gas reservoirs is dominated by dual porosity models that divide the reservoirs into matrix blocks that significantly contribute to fluid storage and fracture networks which principally control flow capacity. However, recent extensive microscopic studies reveal that there exist massive micro- and nano- pore systems in shale matrices. Because of this, the actual flow mechanisms in shale reservoirs are considerably more complex than can be simulated by the conventional dual porosity models and Darcy's Law. Therefore, a model capturing multiple pore scales and flow can provide a better understanding of complex flow mechanisms occurring in these reservoirs. Through the use of a unique simulator, this research work establishes a micro-scale multiple-porosity model for fluid flow in shale reservoirs by capturing the dynamics occurring in three separate porosity systems: organic matter (mainly kerogen); inorganic matter; and natural fractures. Inorganic and organic portions of shale matrix are treated as sub-blocks with different attributes, such as wettability and pore structures. In the organic matter or kerogen, gas desorption and diffusion are the dominant physics. Since the flow regimes are sensitive to pore size, the effects of smaller pores (mainly nanopores and picopores) and larger pores (mainly micropores and nanopores) in kerogen are incorporated in the simulator. The separate inorganic sub-blocks mainly contribute to the ability to better model dynamic water behavior. The multiple porosity model is built upon a unique tool for simulating general multiple porosity systems in which several porosity systems may be tied to each other through arbitrary transfer functions and connectivities. This new model will allow us to better understand complex flow mechanisms and in turn to extend simulation to the reservoir scale including hydraulic fractures through upscaling techniques. The electronic version of this dissertation is accessible from http://hdl.handle.net/1969.1/151163
Download or read book Nanoscale Simulation of Shale Transport Properties Using the Lattice Boltzmann Method written by and published by . This book was released on 2015 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: Here, porous structures of shales are reconstructed using the markov chain monte carlo (MCMC) method based on scanning electron microscopy (SEM) images of shale samples from Sichuan Basin, China. Characterization analysis of the reconstructed shales is performed, including porosity, pore size distribution, specific surface area and pore connectivity. The lattice Boltzmann method (LBM) is adopted to simulate fluid flow and Knudsen diffusion within the reconstructed shales. Simulation results reveal that the tortuosity of the shales is much higher than that commonly employed in the Bruggeman equation, and such high tortuosity leads to extremely low intrinsic permeability. Correction of the intrinsic permeability is performed based on the dusty gas model (DGM) by considering the contribution of Knudsen diffusion to the total flow flux, resulting in apparent permeability. The correction factor over a range of Knudsen number and pressure is estimated and compared with empirical correlations in the literature. We find that for the wide pressure range investigated, the correction factor is always greater than 1, indicating Knudsen diffusion always plays a role on shale gas transport mechanisms in the reconstructed shales. Specifically, we found that most of the values of correction factor fall in the slip and transition regime, with no Darcy flow regime observed.
Download or read book Microflows written by George Em Karniadakis and published by Springer. This book was released on 2001-11-16 with total page 340 pages. Available in PDF, EPUB and Kindle. Book excerpt: This monograph focusing on gas flows addresses mostly theoretical issues and develops semi-analytical models as well as numerical methods for stimulating micro flows. It is appropriate for researchers in fluid mechanics interested in this new flow field as well as for electrical or mechanical engineers or physicists who need to incorporate flow modeling into their work.