[PDF] Confined Fluid Phase Behavior And Co2 Sequestration In Shale Reservoirs eBook
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Confined Fluid Phase Behavior and CO2 Sequestration in Shale Reservoirs delivers the calculation components to understand pore structure and absorption capacity involving unconventional reservoirs. Packed with experimental procedures, step-by-step instructions, and published data, the reference explains measurements for capillary pressure models, absorption behavior in double nano-pore systems, and the modeling of interfacial tension in C02/CH4/brine systems. Rounding out with conclusions and additional literature, this reference gives petroleum engineers and researchers the knowledge to maximize productivity in shale reservoirs. Helps readers gain advanced understanding of methods of adsorption behavior in shale gas Presents theories and calculations for measuring and computing by providing step-by-step instructions, including flash calculation for phase equilibrium Includes advances in shale fluid behavior, along with well-structured experiments and flow charts
Shale gas and oil has been explored and developed in the recent years. Because of its complex pore structure and reservoir characteristics, fluid properties and mechanisms of fluid flow are always difficult but important topics which need to be recognized and described. It is known that properties of fluid in the shale reservoir will be affected by confined environment, and fluid flow in shale reservoir does not always follow Darcy's Law such as turbulent flow in the shale gas reservoir. Consequently, it is a significant study for calculating modified properties and describing fluid flow mechanisms within shale reservoirs. Flash calculation is the first step to characterize reservoir fluid properties because shale reservoir is a multi-phase fluid system. This study primarily considers reservoir as a two-phase system, which includes gas and liquid phases based on the prevailing composition of hydrocarbons in studied shale reservoir formation. Comparing with conventional phase behavior studies for bulk phase fluid, the confined flash calculation for shale reservoir fluids considers the shifts of critical properties of components and the impacts of capillary pressure. It determines the bubble-point pressure and dew point pressure of shale fluids at specific temperatures, composition of gas/liquid phases, and the amount of each phase at equilibrium. The obtained results are compared with those results generated by CMGTM Winprop module (Version 2019.10, Computer Modelling Group Limited, Canada) to verify the accuracy of program from the study. Additionally, with those calculated individual composition in each phase, the assessment of several important properties of fluid such as density, viscosity and compressibility of vapor/liquid phases are performed. Based on the calculated results, critical properties shift and capillary pressure prove to be two important aspects which do affect the flash calculations and physical properties determination. Therefore, they should be considered in flash calculation for shale reservoir fluid at confinement effects. In addition, a case study of transient fluid flow which is influenced by phase behavior and confined effects in the shale formation is developed and solved. Starting from general diffusivity equation, an expression of dimensionless bottomhole pressure of shale gas reservoir with dimensionless time in the scenario of infinite outer boundary and vertical well production is constructed and then solved eventually by using several mathematical approaches (Laplace transform, Fourier transform and Stehfest inversion). Furthermore, within the restricted space, fracture pressures and production rates are calculated in the different pore sizes. Through this study, at the confined space, effects of confinement (critical properties shift and capillary pressure) at the shale reservoir apparently influence flash calculation, phase equilibrium, bubble point and dew point pressures estimation, physical property evaluations of fluid and transient fluid flow analysis.
The massive increase in energy demand and the related rapid development of unconventional reservoirs has opened up exciting new energy supply opportunities along with new, seemingly intractable engineering and research challenges. The energy industry has primarily depended on a heuristic approach—rather than a systematic approach—to optimize and tackle the various challenges when developing new and improving the performance of existing unconventional reservoirs. Industry needs accurate estimations of well production performance and of the cumulative estimated ultimate reserves, accounting for uncertainty. This Special Issue presents 10 original and high-quality research articles related to the modeling of unconventional reservoirs, which showcase advanced methods for fractured reservoir simulation, and improved production forecasting techniques.
Pore sizes are on the order of nanometers for shale and tight rock formations. Such small pores can affect the phase behavior of in-situ oil and gas owing to increased capillary pressure. Not accounting for increased capillary pressure can lead to inaccurate estimates of ultimate recovery. In this research, capillary pressure is coupled with phase equilibrium equations and the resulting system of nonlinear fugacity equations is solved to present a comprehensive examination of the effect of small pores on saturation pressures and fluid properties. The results show, for the first time, that accounting for the impact of small pore throats on PVT properties explains the inconsistent GOR behavior observed in tight formations. The small pores decrease bubble-point pressures and either decrease or increase dew-point pressures depending on which part of the two-phase envelope is examined. To estimate production from shale reservoirs, a simulation model should be designed to account for the effect of high capillary pressure on fluid properties. We have chosen to use a compositionally-extended black-oil approach since it is faster and more robust compared to a fully compositional simulation model. Black-oil fluid properties are calculated by flash calculations of the reservoir fluid. Allowing for a variable bubble-point pressure in black- or volatile-oil models requires a table of fluid properties be extended above the original bubble-point. We calculate continuous black-oil fluid properties above the original bubble-point by adding a fraction of the equilibrium gas at one bubble-point pressure to achieve a larger bubble-point pressure. This procedure continues until a critical point is reached. Unlike other commonly used methods, our approach provides a smooth and continuous pressure-composition curve to the critical point. If another component is added, the model further allows for injection of methane or CO2 to increase oil recovery. Further, the approach allows the use of black-oil or volatile-oil properties for tight rocks where capillary pressure affects hydrocarbon phase behavior. The compositional equations (gas, oil, and water components) are solved directly with principle unknowns of oil pressure, overall gas composition, and water saturation. Flash calculations in the model are non-iterative and are based on K-values calculated explicitly from the black-oil data. The advantage of solving the black-oil model using the compositional equations is to increase robustness of the simulations owing to a variable bubble-point pressure that is a function of two parameters, namely gas content and capillary pressure. Leverett J-functions are used to establish the effective pore size-Pc-saturation relationship. The input fluid data to the simulator are pre-calculated fluid properties as functions of pressure for three fixed pore sizes. During the simulation, at any pressure and saturation, fluid properties are calculated at the effective pore radius by using linear interpolation between these three data sets. Our results show that there is up to a 90% increase in recovery when capillary pressure is included in flash calculations. Reservoir initial pressure, reservoir permeability, initial water saturation, and critical gas saturation are among the factors influencing the increase in recovery due to the effect of capillary pressure.
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
A comprehensive textbook presenting techniques for the analysis and characterization of shale plays Significant reserves of hydrocarbons cannot be extracted using conventional methods. Improvements in techniques such as horizontal drilling and hydraulic fracturing have increased access to unconventional hydrocarbon resources, ushering in the “shale boom” and disrupting the energy sector. Unconventional Hydrocarbon Resources: Techniques for Reservoir Engineering Analysis covers the geochemistry, petrophysics, geomechanics, and economics of unconventional shale oil plays. The text uses a step-by-step approach to demonstrate industry-standard workflows for calculating resource volume and optimizing the extraction process. Volume highlights include: Methods for rock and fluid characterization of unconventional shale plays A workflow for analyzing wells with stimulated reservoir volume regions An unconventional approach to understanding of fluid flow through porous media A comprehensive summary of discoveries of massive shale resources worldwide Data from Eagle Ford, Woodford, Wolfcamp, and The Bakken shale plays Examples, homework assignments, projects, and access to supplementary online resources Hands-on teaching materials for use in petroleum engineering software applications The American Geophysical Union promotes discovery in Earth and space science for the benefit of humanity. Its publications disseminate scientific knowledge and provide resources for researchers, students, and professionals.
This book gives background information why shale formations in the world are important both for storage capacity and enhanced gas recovery (EGR). Part of this book investigates the sequestration capacity in geological formations and the mechanisms for the enhanced storage rate of CO2 in an underlying saline aquifer. The growing concern about global warming has increased interest in geological storage of carbon dioxide (CO2). The main mechanism of the enhancement, viz., the occurrence of gravity fingers, which are the vehicles of enhanced transport in saline aquifers, can be visualized using the Schlieren technique. In addition high pressure experiments confirmed that the storage rate is indeed enhanced in porous media. The book is appropriate for graduate students, researchers and advanced professionals in petroleum and chemical engineering. It provides the interested reader with in-depth insights into the possibilities and challenges of CO2 storage and the EGR prospect.
This exclusive compilation written by eminent experts from more than ten countries, outlines the processes and methods for geologic sequestration in different sinks. It discusses and highlights the details of individual storage types, including recent advances in the science and technology of carbon storage. The topic is of immense interest to geoscientists, reservoir engineers, environmentalists and researchers from the scientific and industrial communities working on the methodologies for carbon dioxide storage. Increasing concentrations of anthropogenic carbon dioxide in the atmosphere are often held responsible for the rising temperature of the globe. Geologic sequestration prevents atmospheric release of the waste greenhouse gases by storing them underground for geologically significant periods of time. The book addresses the need for an understanding of carbon reservoir characteristics and behavior. Other book volumes on carbon capture, utilization and storage (CCUS) attempt to cover the entire process of CCUS, but the topic of geologic sequestration is not discussed in detail. This book focuses on the recent trends and up-to-date information on different storage rock types, ranging from deep saline aquifers to coal to basaltic formations.