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Book ChapterDOI

Coupled Flow and Geomechanics Model for CO 2 Storage in Tight Gas Reservoir

TL;DR: In this article, a fully coupled fully implicit flow and geomechanics simulator is introduced to describe the physics associated with the injection of CO2 into tight shales, and assess and mitigate the risks associated with reservoir overpressure.
Abstract: The process of injection and withdrawal from tight gas reservoirs is a multiphysics and multicomponent problem. The aim of the present work is to capture the physics associated with the injection of CO2 into tight shales, and assess and mitigate the risks associated with reservoir overpressure. The overpressure caused by CO2 injection usually triggers the onset of formation–deformation, which inadvertently affects the state of the stress in the target geological formations and its surroundings, the monitoring of which is critical to understand the risks in conjunction with CO2 storage. In the present work, a novel fully coupled fully implicit flow and geomechanics simulator is introduced to describe the physics in conjunction with an extended injection phase of CO2. The developed model solves for pressure saturation and porosity and permeability changes considering a multicomponent system while principally focusing on the adsorption and diffusion of CO2 and stress-dependent reservoir deformation employing cell-centred finite volume method. It is envisaged that the injection of CO2, while with the primary purpose of storage, will parallelly enhance the recovery from shale gas due to lateral sweep effects. Based on these mechanisms, for the case study of a tight gas field, the applicability of the simulation model is tested for formations with varied rock and fluid moduli in a 20-year simulation period.
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Journal ArticleDOI
TL;DR: An overview of pore-scale modeling and micro-CT scan imaging technique for CO2 sequestration including a background of basic concepts related to storage, CO2 enhanced oil recovery, simulators used, and storage estimation is provided in this paper.
Abstract: Global warming is increasing at a perpetual rate due to the emission of greenhouse gases in recent years. This spectacle has been mainly caused by the increase of carbon dioxide (CO2) in the environment. It is in need to find a path to reduce the greenhouse gases along with the additional benefit of energy demand in a sustainable way. A favorable long-term way out to mitigate global warming is to inject CO2 into geological formations of oil fields to achieve a goal of a combination of CO2 sequestration and enhanced oil recovery by CO2 flooding. Understanding the mechanism of CO2 sequestration under impermeable rock formation requires the knowledge of the pore-scale modeling concept. This review article provides an overview of pore-scale modeling and micro-CT scan imaging technique for CO2 sequestration including a background of basic concepts related to storage, CO2 enhanced oil recovery, simulators used, and storage estimation. Trapping mechanisms, geological description of the formation for CO2 sequestration, and reactions that have taken place during the trapping in underground formation are also discussed elaborately. Macro-scale and pore-scale modeling are depicted based on the current literature available. This review also presents petrophysical data that comes from the pore network modeling of CO2-brine pore structure for the formation of carbon-containing sandstone reservoirs. A discussion on the challenges of CO2 sequestration and modeling in pore-scale is also furnished to point out the problems and solutions in near future. Finally, the prospect of CO2 sequestration and pore-scale modeling are described for its uncountable value in greenhouse gas reduction from the environment.

28 citations

Journal ArticleDOI
TL;DR: In this paper , the authors present the results of analysing geological structure of the Famennian deposits (Devonian) in the Perm Region, where numerical finite element models of near-wellbore zones were created considering slotted and cumulative perforation.
Abstract: The article presents the results of analysing geological structure of the Famennian deposits (Devonian) in the Perm Region. Numerical modelling of the distribution of inhomogeneous stress field near the well was performed for the two considered types of perforation. With regard for the geometry of the forming perforation channels, numerical finite element models of near-wellbore zones were created considering slotted and cumulative perforation. It is ascertained that in the course of slotted perforation, conditions are created for a significant restoration of effective stresses and, as a result, restoration of reservoir rock permeability. Stress recovery area lies near the well within a radius equal to the length of the slots, and depends on the drawdown, with its increase, the area decreases. From the assessment of failure areas, it was found that in case of slotted perforation, the reservoir in near-wellbore zone remains stable, and failure zones can appear only at drawdowns of 10 MPa and more. The opposite situation was recorded for cumulative perforation; failure zones near the holes appear even at a drawdown of 2 MPa. In general, the analysis of results of numerical simulation of the stress state for two simulated types of perforation suggests that slotted perforation is more efficient than cumulative perforation. At the same time, the final conclusion could be drawn after determining the patterns of changes in permeability of the considered rocks under the influence of changing effective stresses and performing calculations of well flow rates after making the considered types of perforation channels.

1 citations

References
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Journal ArticleDOI
TL;DR: This work has established a set of simplifying assumptions that allow for calculation of solutions to large-scale injection and leakage problems in ways that traditional multicomponent multiphase simulators cannot, and serves as an example of how complex systems can be simplified while retaining the essential physics of the problem.
Abstract: The relentless increase of anthropogenic carbon dioxide emissions and the associated concerns about climate change have motivated new ideas about carbon-constrained energy production. One technological approach to control carbon dioxide emissions is carbon capture and storage, or CCS. The underlying idea of CCS is to capture the carbon before it emitted to the atmosphere and store it somewhere other than the atmosphere. Currently, the most attractive option for large-scale storage is in deep geological formations, including deep saline aquifers. Many physical and chemical processes can affect the fate of the injected CO2, with the overall mathematical description of the complete system becoming very complex. Our approach to the problem has been to reduce complexity as much as possible, so that we can focus on the few truly important questions about the injected CO2, most of which involve leakage out of the injection formation. Toward this end, we have established a set of simplifying assumptions that allow us to derive simplified models, which can be solved numerically or, for the most simplified cases, analytically. These simplified models allow calculation of solutions to large-scale injection and leakage problems in ways that traditional multicomponent multiphase simulators cannot. Such simplified models provide important tools for system analysis, screening calculations, and overall risk-assessment calculations. We believe this is a practical and important approach to model geological storage of carbon dioxide. It also serves as an example of how complex systems can be simplified while retaining the essential physics of the problem.

177 citations

Journal ArticleDOI
TL;DR: In this paper, a simulation model was constructed for CO2 flooding and huff and puff in the Marcellus and New Albany shale fields to examine the effects of CO2 injection to enhanced gas recovery (EGR) and CO2 storage.

151 citations

Journal ArticleDOI
TL;DR: In this paper, the authors address the modeling of geomechanical effects induced by reservoir production and their influence on fluid flow in the reservoir and present a field case study of a stress dependent reservoir simulator.
Abstract: The paper addresses the modeling of geomechanical effects induced by reservoir production and their influence on fluid flow in the reservoir. Geomechanical effects induced by reservoir production can be particularly pronounced in stress sensitive reservoirs, such as poorly compacted reservoirs and fractured reservoirs. The authors review the main coupled mechanisms associated with the production of these reservoirs, and describe the different approaches that can be used to solve the coupling between fluid flow and geomechanical problems. A field case study is then presented. A stress dependent reservoir simulator-ATH2VIS-was used to quantify effects associated with the production of a highly heterogeneous and compartmentalized limestone reservoir. This simulator relies on a partial coupling approach with different time steps for reservoir and geomechanical simulations and manages data exchanges at given time intervals between the ATHOSTM reservoir simulator developed at IFP and the VISAGETM geomechanical simulator (VIPS Ltd. , 2001). The results of the coupled reservoir geomechanical simulations indicate that perturbation of the reservoir mechanical equilibrium specifically leads to progressive strain localization on a limited number of faults. Only specific parts of these faults are critically stressed, depending on pore pressure variations in their vicinity, temperature variations, and fault strikes compared with stress orientation. The normal strains resulting from geomechanical computations are interpreted in terms of permeability variations using a fracture and fault permeability model to improve the dynamic description of fluid flow and history matching.

101 citations

Journal ArticleDOI
TL;DR: In this article, basin-scale sharp-interface models of CO 2 injection were constructed for the Illinois basin and the authors used 726 injection wells located near 42 power plants to deliver 80 million metric tons of CO2 /year.

91 citations