Numerical Modelling and Simulation of Fully Coupled Gas Hydrate Reservoirs and Wellbore Fluid Flow PDF Download
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Author: Sabastine Anibueze
Publisher:
ISBN:
Category :
Languages : en
Pages : 0
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Author: Sabastine Anibueze
Publisher:
ISBN:
Category :
Languages : en
Pages : 0
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Author: Jebraeel Gholinezhad
Publisher: Springer
ISBN: 3319707698
Category : Technology & Engineering
Languages : en
Pages : 96
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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.
Author: Venkataramana Putcha
Publisher:
ISBN:
Category :
Languages : en
Pages :
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As the reservoir pressure declines with time, many of the wells do not have adequate bottom-hole pressure to carry the fluids to the surface. Under such circumstances, artificial lift mechanisms must be employed. Amongst various artificial lift mechanisms, a significant proportion of wells utilize the gas-lift mechanism, which is an extension of the natural flow. In gas-lift implementation, high pressure gas is injected into the wellbore through a valve, where injected gas supports production by altering the composition and reducing the density, and increasing the velocity of the produced fluids. In order to design a gas-lift system, a study of the inflow performance of the fluid from the reservoir into the wellbore, combined with the outflow performance of the fluids from the bottom of the wellbore to the surface is necessary. For this purpose, existing technologies for optimization of gas-lift systems predominantly use empirical correlations in order to reduce the computational overhead. These systems use a single-equation based inflow performance relations and black-oil outflow performance correlations that have restricted applicability in systems where the fluid composition varies spatially and temporally. The contemporary protocols consider the oil flow rate, water cut and formation gas-liquid ratio and well productivity index at a given instant of time to calculate the optimal quantity of gas lift injection. Due to this methodology, the effects of pressure decline and subsequent variations in well performance are not adequately captured. This results in a solution which determines the maximum liquid flow rate expected for a given gas lift injection rate only for the instantaneous period at which the study has been performed. This optimal gas lift injection rate may or may not provide the maximum total output of oil over the producing life of the well. As a first step, a compositional coupled numerical reservoir and wellbore hydraulics models has been developed as a part of this work. These hard-computing tools simulate the variations in composition, pressure and production profiles of a gas lift well and its associated reservoir from inception to abandonment. One more advantage of this method is that it can predict the future performance of a well with or without the details of well production history. This capability can be useful when gas lift is introduced in a well immediately after its completion post a drilling or a work-over job. Soft computing tools have gained popularity in the petroleum industry due to their speed, simplicity, wide range of applicability, capacity to identify patterns and ability to provide inverse solutions. The fully numerical coupled reservoir-wellbore simulator developed is computationally expensive. In order to develop a faster system, firstly, an ANN based wellbore hydraulics tool is developed and coupled with the numerical reservoir simulator. The data utilized for training the ANN tool was generated using the numerical wellbore hydraulics tool. Both the numerical and ANN wellbore hydraulics models were validated against cases from the field and another compositional numerical model from the literature. The average relative deviation with respect to field data was observed to be 2.2% and 2.4% respectively for the ANN and numerical wellbore hydraulics model, respectively. When compared against another compositional numerical model, the average relative deviation for the ANN based model was observed to be between 3.3% and 7.1%, while it was between 2.3% and 8.1% for the numerical model developed in this work. While the ANN based wellbore hydraulics model maintained the accuracy of the numerical model, it outperformed its counterpart the numerical model, by four orders of magnitude in terms of speed-up. The ANN based wellbore model was also coupled with the numerical reservoir simulator. This resultant model which involves a coupled numerical-ANN system is faster than the fully numerical coupled system by about 160 times. This coupled tool was used to generate a gas lift database of cumulative oil production of a well with various reservoir and wellbore operating conditions under a range of operating gas lift injection depths and flow rates. This database was used to develop an ANN based gas lift model that is capable of generating performance curves plotting total oil produced during the producing life of a well as a function of gas lift injection rate. Blind testing of the ANN gas lift model showed an average absolute error of 16.6 % with respect to the predictions of the coupled numerical-ANN reservoir wellbore model. This fully ANN based gas lift model provided a speed-up by four orders of magnitude with respect to the coupled numerical-ANN based model. Hence, a fast, robust and versatile model has been developed for maximizing total primary oil recovery using gas lift optimization through integration of numerical and neuro-simulation.
Author: Yu-Shu Wu
Publisher: Gulf Professional Publishing
ISBN: 0128039116
Category : Science
Languages : en
Pages : 420
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Multiphase Fluid Flow in Porous and Fractured Reservoirs discusses the process of modeling fluid flow in petroleum and natural gas reservoirs, a practice that has become increasingly complex thanks to multiple fractures in horizontal drilling and the discovery of more unconventional reservoirs and resources. The book updates the reservoir engineer of today with the latest developments in reservoir simulation by combining a powerhouse of theory, analytical, and numerical methods to create stronger verification and validation modeling methods, ultimately improving recovery in stagnant and complex reservoirs. Going beyond the standard topics in past literature, coverage includes well treatment, Non-Newtonian fluids and rheological models, multiphase fluid coupled with geomechanics in reservoirs, and modeling applications for unconventional petroleum resources. The book equips today's reservoir engineer and modeler with the most relevant tools and knowledge to establish and solidify stronger oil and gas recovery. - Delivers updates on recent developments in reservoir simulation such as modeling approaches for multiphase flow simulation of fractured media and unconventional reservoirs - Explains analytical solutions and approaches as well as applications to modeling verification for today's reservoir problems, such as evaluating saturation and pressure profiles and recovery factors or displacement efficiency - Utilize practical codes and programs featured from online companion website
Author: Xin Chen
Publisher:
ISBN:
Category : Multiphase flow
Languages : en
Pages : 0
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Natural gas hydrates are solid crystalline mixtures of water and small gas molecules that typically form at relatively low temperatures and moderate pressures. As a promising energy resource, the natural gas hydrates are discovered in many offshore and permafrost geological formations. Besides, the natural gas hydrates are also found to form in the pipelines located in cold areas and in the wellbores used in offshore petroleum industry, causing the flow assurance problems. The decomposition of in-situ hydrates during the exploitation process and the formation of hydrates in pipelines or wellbores will lead to a series of changes on the number of equilibrium phases and the phase compositions. How to accurately describe the phase behavior of natural gas hydrates plays a fundamentally important role in the accurate modeling of multiphase flow involving gas hydrates in both reservoirs and wellbores/pipelines. This study will start from developing improved thermodynamic frameworks that can improve the accuracy in modeling the phase behavior of reservoir fluids and gas hydrates. Then based on the improved thermodynamic models, we provide a reliable multiphase equilibrium calculation algorithm for gas hydrate systems. As an efficient and reliable thermodynamic tool for modeling the multiphase behavior of reservoir fluids, cubic equation of state (CEOS) has been widely adopted in industrial simulators. However, most of the CEOS models cannot provide an accurate density prediction for the liquid phase. Although the temperature-volume-dependent volume translation (VT) is deemed as the most accurate method to correct the liquid density yielded by CEOS, the available VT-models do not fully exploit the potential of distance function and there is still a room for improving the prediction accuracy of saturated and single-phase liquid densities for water and hydrocarbons by VT-CEOS. Hence, this study proposes a series of improved VT-models to achieve more accurate volumetric calculations for water, hydrocarbons and their mixtures. The absolute percentage deviations of the liquid molar volumes yielded by the newly-proposed VT-CEOSs for different compounds are usually lower than 1%. In academia and industry, the van der Waals-Platteeuw (vdW-P) hydrate model is one of the most popular and classical hydrate-equilibrium calculation methods. Nevertheless, the hydrate equilibria of gas-mixture systems predicted by the vdW-P model are not as accurate as those predicted for pure-gas systems. In contrast to the previous studies that focused on the modifications of functional forms, the current study aims to provide new pragmatic strategies for tuning the gas-dependent parameters in the vdW-P hydrate model. A new procedure is developed for fitting the Kihara potential parameters in the vdW-P hydrate model using the experimental hydrate equilibrium data for both pure gases and binary-gas mixtures, considering the differences between hydrate structures I and II. As a result, the vdW-P model coupled with the newly fitted Kihara potential parameters performs well in gas hydrate equilibrium calculations and also properly detects the hydrate structure transition and cage occupancy behaviors. Lastly, on the basis of the improved thermodynamic models, we develop an algorithm for multiphase equilibrium calculations in the presence of gas hydrates. The number of equilibrium phases that can be detected by this algorithm is up to four phases, i.e., a vapor phase, a hydrocarbon-rich liquid phase, an aqueous phase, and a gas hydrate phase. In this algorithm, a new criterion for determining the onset of hydrate dissociation is proposed based on van der Waals-Platteeuw model. To calculate the phase fractions and phase compositions, this new algorithm provides a series of material-balance equations involving hydrates. Example calculations demonstrate that this algorithm is capable of robustly conducting hydrate-inclusive multiphase equilibrium calculations for a given fluid at specified temperature and pressure.
Author: Akkharachai Limpasurat
Publisher:
ISBN:
Category :
Languages : en
Pages :
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Liquid loading in a gas well occurs when the upward gas flow rate is insufficient to lift the coproduced liquid to the surface, which results in an accumulation of liquid at the bottom of the well. The liquid column in the tubing creates backpressure on the formation, which decreases the gas production rate and may stop the well from flowing. To model these phenomena, the dynamic interaction between the reservoir and the wellbore must be characterized. Due to wellbore phase re-distribution and potential phase-reinjection into the reservoir, the boundary conditions must be able to handle changing flow direction through the connections between the two subsystems. This study presents a new formulation of the wellbore boundary condition used in reservoir simulators. The boundary condition uses the new state variable, the multiphase zero flow pressure (MPZFP, p0), to determine flow direction in the connection grid block. If the wellbore pressure is less than the p0, the connection is producing; otherwise, it is injecting. The volumetric proportion of the flow is always determined by the upstream side. The new reservoir simulator is used in coupled modeling associated with liquid loading phenomena. The metastable condition can be modeled in a simple manner without any limiting assumptions and numerical stability problems. We also applied this simulator for history matching of a gas well flowing with an intermittent production strategy. A basic transient wellbore model was developed for this purpose. The long-term tubinghead pressure (THP) history can be traced by our coupled simulation. Our modeling examples indicated that, the new wellbore boundary condition is suitable in modeling the dynamic interactions between reservoir and wellbore subsystems during liquid loading. The flow direction through the connection grid block can be automatically detected by our boundary condition without numerical difficulty during the course of the simulation. In addition, the capillary pressure can be accounted at the connection grid blocks when applying our new formulation in the reservoir simulator. The electronic version of this dissertation is accessible from http://hdl.handle.net/1969.1/151699
Author: Jose ́Gildardo Osorio
Publisher:
ISBN:
Category : Analytical geochemistry
Languages : en
Pages : 346
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Author: Yunmin Chen
Publisher: Springer Science & Business Media
ISBN: 3642044603
Category : Science
Languages : en
Pages : 944
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"Advances in Environmental Geotechnics" presents the latest developments in this interdisciplinary field. The topics covered include basic and advanced theories for modeling of geoenvironmental phenomena, testing and monitoring for geoenvironmental engineering, municipal solid wastes and landfill engineering, sludge and dredged soils, geotechnical reuse of industrial wastes, contaminated land and remediation technology, applications of geosynthetics in geoenvironmental engineering, geoenvironmental risk assessment, management and sustainability, ecological techniques and case histories. This proceedings includes papers authored by core members of ISSMGE TC5 (International Society of Soil Mechanics and Geotechnical Engineering---Environmental Geotechnics) and geoenvironmental researchers from more than 20 countries and regions. It is a valuable reference for geoenvironmental and geotechnical engineers as well as civil engineers. Yunmin Chen, Xiaowu Tang, and Liangtong Zhan are Professors at the Department of Civil Engineering of Zhejiang University, China.
Author: Olivier Coussy
Publisher: Wiley
ISBN: 9780471952671
Category : Technology & Engineering
Languages : en
Pages : 472
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This book provides a unified and systematic continuum approach for engineers and applied physicists working on the modelling of porous media. Self-contained, it sets out—from a macroscopic point of view—the main concepts and results of deformable porous media subject to the flow of one or several fluids. The theory presented includes developments in the areas of thermodynamics, poroelastoplasticity, poroviscoplasticity, wave propagation and surfaces of discontinuity, boundary value problems and numerical methods, as well as chemico-mechanical couplings. It can be used for numerous diversified applications in geophysics, civil engineering, biomechanics, material science, etc.
Author:
Publisher:
ISBN:
Category :
Languages : en
Pages : 5
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The Mallik site represents an onshore permafrost-associated gas hydrate accumulation in the Mackenzie Delta, Northwest Territories, Canada. An 1150 m deep gas hydrate research well was drilled at the site in 1998. The objective of this study is the analysis of various gas production scenarios from several gas-hydrate-bearing zones at the Mallik site. The TOUGH2 general-purpose simulator with the EOSHYDR2 module were used for the analysis. EOSHYDR2 is designed to model the non-isothermal CH4 (methane) release, phase behavior and flow under conditions typical of methane-hydrate deposits by solving the coupled equations of mass and heat balance, and can describe any combination of gas hydrate dissociation mechanisms. Numerical simulations indicated that significant gas hydrate production at the Mallik site was possible by drawing down the pressure on a thin free-gas zone at the base of the hydrate stability field. Gas hydrate zones with underlying aquifers yielded significant gas production entirely from dissociated gas hydrate, but large amounts of produced water. Lithologically isolated gas-hydrate-bearing reservoirs with no underlying free gas or water zones, and gas-hydrate saturations of at least 50% were also studied. In these cases, it was assumed that thermal stimulation by circulating hot water in the well was the method used to induce dissociation. Sensitivity studies indicated that the methane release from the hydrate accumulations increases with gas-hydrate saturation, the initial formation temperature, the temperature of the circulating water in the well, and the formation thermal conductivity. Methane production appears to be less sensitive to the rock and hydrate specific heat and permeability of the formation.
