[PDF] The Application Of Fluid Phase Behavior For Bakken Shale Reservoir eBook

Author : Yi Chun Zhu
Publisher :
Page : 0 pages
File Size : 11,63 MB
Release : 2021
Category :
ISBN :

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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.

Author : Raj Deo Tewari
Publisher : CRC Press
Page : 412 pages
File Size : 10,9 MB
Release : 2018-12-14
Category : Science
ISBN : 1351857231

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This book deals with complex fluid characterization of oil and gas reservoirs, emphasizing the importance of PVT parameters for practical application in reservoir simulation and management. It covers modeling of PVT parameters, QA/QC of PVT data from lab studies, EOS modeling, PVT simulation and compositional grading and variation. It describes generation of data for reservoir engineering calculations in view of limited and unreliable data and techniques like downhole fluid analysis and photophysics of reservoir fluids. It discusses behavior of unconventional reservoirs, particularly for difficult resources like shale gas, shale oil, coalbed methane, reservoirs, heavy and extra heavy oils.

Author : Karen Schou Pedersen
Publisher : CRC Press
Page : 423 pages
File Size : 45,48 MB
Release : 2006-11-01
Category : Science
ISBN : 1420018256

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Understanding the phase behavior of the various fluids present in a petroleum reservoir is essential for achieving optimal design and cost-effective operations in a petroleum processing plant. Taking advantage of the authors' experience in petroleum processing under challenging conditions, Phase Behavior of Petroleum Reservoir Fluids introdu

Author : Alireza Bahadori
Publisher : Gulf Professional Publishing
Page : 556 pages
File Size : 42,80 MB
Release : 2016-11-24
Category : Technology & Engineering
ISBN : 0128034467

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Fluid Phase Behavior for Conventional and Unconventional Oil and Gas Reservoirs delivers information on the role of PVT (pressure-volume-temperature) tests/data in various aspects, in particular reserve estimation, reservoir modeling, flow assurance, and enhanced oil recovery for both conventional and unconventional reservoirs. This must-have reference also prepares engineers on the importance of PVT tests, how to evaluate the data, develop an effective management plan for flow assurance, and gain perspective of flow characterization, with a particular focus on shale oil, shale gas, gas hydrates, and tight oil making. This book is a critical resource for today’s reservoir engineer, helping them effectively manage and maximize a company’s oil and gas reservoir assets. Provides tactics on reservoir phase behavior and dynamics with new information on shale oil and gas hydrates Helps readers Improve on the effect of salt concentration and application to C02-Acid Gas Disposal with content on water-hydrocarbon systems Provides practical experience with PVT and tuning of EOS with additional online excel spreadsheet examples

Author : Yueliang Liu
Publisher : Gulf Professional Publishing
Page : 248 pages
File Size : 34,96 MB
Release : 2022-05-05
Category : Science
ISBN : 032398620X

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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

Author : Karen Schou Pedersen
Publisher : CRC Press
Page : 0 pages
File Size : 44,50 MB
Release : 2014-12-18
Category : Science
ISBN : 9781439852231

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Developed in conjunction with several oil companies using experimental data for real reservoir fluids, Phase Behavior of Petroleum Reservoir Fluids introduces industry standard methods for modeling the phase behavior of petroleum reservoir fluids at different stages in the process. Keeping mathematics to a minimum, this book discusses sampling, characterization, compositional analyses, and equations of state used to simulate various pressure–volume–temperature (PVT) properties of reservoir fluids. Featuring new figures, references, and updates throughout, this Second Edition: Adds simulation results for PVT data obtained with the PC-SAFT equation Describes routine and EOR PVT experiments with enhanced procedural detail Expands coverage of sampling, compositional analyses, and measurement of PVT data Phase Behavior of Petroleum Reservoir Fluids, Second Edition supplies a solid understanding of the phase behavior of the various fluids present in a petroleum reservoir, providing practical knowledge essential for achieving optimal design and cost-effective operations in a petroleum processing plant.

Author : Curtis H. Whitson
Publisher : Society of Petroleum Engineers
Page : 248 pages
File Size : 38,12 MB
Release : 2000
Category : Business & Economics
ISBN :

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Phase Behavior provides the reader with the tools needed to solve problems requiring a description of phase behavior and specific pressure/volume/temperature (PVT) properties.

Author : Bahareh Nojabaei
Publisher :
Page : pages
File Size : 13,59 MB
Release : 2015
Category :
ISBN :

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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.

Author : E.J. Hoffman
Publisher : Elsevier
Page : 484 pages
File Size : 12,98 MB
Release : 1999-07-02
Category : Technology & Engineering
ISBN : 0080543456

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The ubiquitous examples of unsteady-state fluid flow pertain to the production or depletion of oil and gas reservoirs. After introductory information about petroleum-bearing formations and fields, reservoirs, and geologic codes, empirical methods for correlating and predicting unsteady-state behavior are presented. This is followed by a more theoretical presentation based on the classical partial differential equations for flow through porous media.Whereas these equations can be simplified for the flow of (compressible) fluids, and idealized solutions exist in terms of Fourier series for linear flow and Bessel functions for radial flow, the flow of compressible gases requires computer solutions, read approximations. An analysis of computer solutions indicates, fortuitously, that the unsteady-state behavior can be reproduced by steady-state density or pressure profiles at successive times. This will demark draw down and the transition to long-term depletion for reservoirs with closed outer boundaries.As an alternative, unsteady-state flow may be presented in terms of volume and surface integrals, and the methodology is fully developed with examples furnished. Among other things, permeability and reserves can be estimated from well flow tests.The foregoing leads to an examination of boundary conditions and degrees of freedom and raises arguments that the classical partial differential equations of mathematical physics may not be allowable representations. For so-called open petroleum reservoirs where say water-drive exists, the simplifications based on successive steady-state profiles provide a useful means of representation, which is detailed in the form of material balances. Unsteady-State Fluid Flow provides:• empirical and classical methods for correlating and predicting the unsteady-state behavior of petroleum reservoirs• analysis of unsteady-state behavior, both in terms of the classical partial differential equations, and in terms of volume and surface integrals• simplifications based on successive steady-state profiles which permit application to the depletion of both closed reservoirs and open reservoirs, and serves to distinguish drawdown, transition and long-term depletion performance.