Download or read book Numerical Investigation of Multiphase Darcy Forchheimer Flow and Contaminant Transport During SO2 Co injection with CO2 in Deep Saline Aquifers written by Andi Zhang and published by . This book was released on 2013 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: Of all the strategies to reduce carbon emissions, carbon dioxide (CO2) geological sequestration is an immediately available option for removing large amounts of the gas from the atmosphere. However, our understanding of the transition behavior between Forchheimer and Darcy flow through porous media during CO2 injection is currently very limited. In addition, the kinetic mass transfer of SO2 and CO2 from CO2 stream to the saline and the fully coupling between the changes of porosity and permeability and multiphase flow are two significant dimensions to investigate the brine acidification and the induced porosity and permeability changes due to SO2 co-injection with CO2. Therefore, this dissertation develops a multiphase flow, contaminant transport and geochemical model which includes the kinetic mass transfer of SO2 into deep saline aquifers and obtains the critical Forchheimer number for both water and CO2 by using the experimental data in the literature. The critical Forchheimer numbers and the multiphase flow model are first applied to analyze the application problem involving the injection of CO2 into deep saline aquifers. The results show that the Forchheimer effect would result in higher displacement efficiency with a magnitude of more than 50% in the Forchheimer regime than that for Darcy flow, which could increase the storage capacity for the same injection rate and volume of a site. Another merit for the incorporation of Forchheimer effect is that more CO2 would be accumulated in the lower half of the domain and lower pressure would be imposed on the lower boundary of the cap-rock. However, as a price for the advantages mentioned above, the injection pressure required in Forchheimer flow would be higher than that for Darcy flow. The fluid flow and contaminant transport and geochemical model is then applied to analyze the brine acidification and induced porosity and permeability changes due to SO2 co-injection. The results show that the co-injection of SO2 with CO2 would lead to a substantially acid zone near the injecting well and it is important to include the kinetic dissolution of SO2 from the CO2 stream to the water phase into the simulation models, otherwise considerable errors would be introduced for the equilibrium assumption. This study provides a useful tool for future analysis and comprehension of multiphase Darcy-Forchheimer flow and brine acidification of CO2 injection into deep saline aquifers. Results from this dissertation have practical use for scientists and engineers concerned with the description of flow behavior, and transport and fate of SO2 during SO2 co-injection with CO2 in deep saline aquifers.

Download or read book An Experimental and Numerical Investigation Into Permeability and Injectivity Changes During CO2 Storage in Saline Aquifers written by Giacomo Bacci and published by . This book was released on 2011 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Experimental Study of Multiphase Flow in Porous Media During CO2 Geo Sequestration Processes written by Ali Saeedi and published by Springer. This book was released on 2016-05-01 with total page 206 pages. Available in PDF, EPUB and Kindle. Book excerpt: Undertaken with the aim of providing a better understanding of the multiphase fluid flow characteristics of fluid-rock systems during the geo-sequestration process, the research detailed in this volume addresses issues not previously covered in the literature.

Download or read book Migration and Trapping of Carbon Dioxide in Saline Aquifers written by Christopher William MacMinn and published by . This book was released on 2012 with total page 128 pages. Available in PDF, EPUB and Kindle. Book excerpt: Mitigation of climate change requires a reduction in atmospheric carbon dioxide (C0 2) emissions. One promising tool for achieving this is the large-scale injection of CO2 into deep saline aquifers. After injection, upward leakage of the CO2 is a primary concern because it will be buoyant relative to the ambient groundwater and, as a result, will rise toward the top of the aquifer and may migrate laterally away from the injection site. To assess leakage risks and estimate aquifer capacity requires an accurate understanding of the subsurface migration and trapping of the buoyant C0 2; however, many aspects of the fundamental physics of CO 2 migration and trapping are not fully understood, and traditional reservoir-simulation tools are currently unable to resolve the impact of small-scale trapping processes on these large-scale fluid flows. In this Thesis, we develop a simple gravity-current model for the post-injection migration and trapping of a buoyant plume of CO2 in a confined, sloping saline aquifer with a natural groundwater through-flow. We include both residual trapping, where small blobs of CO 2 are immobilized by capillarity along the trailing edge of the plume, and solubility trapping driven by convective dissolution, where CO2 dissolves into the groundwater and sinks downward in dense, C0 2-rich fingers. Although idealized, this model offers physical insight into the processes controlling CO 2 migration and trapping, and is not limited by computational resources. We derive solutions to the model in several limiting cases, and we use these solutions to study the interplay between slope and groundwater flow, and the competition between residual and solubility trapping. We validate the model against laboratory analog experiments, finding good agreement between the experimental results and the predictions of the model. We then use the experiments to study the small-scale dynamics of the convective-dissolution instability: the formation, descent, and coarsening of the fingers. Finally, we use the model to study the migration and trapping of CO 2 in the Mt. Simon Sandstone, a large deep saline aquifer in the Midwestern United States that is considered to be a promising candidate for geological CO 2 storage.

Download or read book Multiphase Flow for CO2 Injection in Saline Aquifers and Oil Reservoirs written by Ali Al-Menhali and published by . This book was released on 2016 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Numerical Analysis of Multiphase Flows in Porous Media on Non rectangular Geometry written by Zhen Tao and published by . This book was released on 2017 with total page 402 pages. Available in PDF, EPUB and Kindle. Book excerpt: Fluid flow through porous media is a subject of common interest in many branches of engineering as well as applied natural science. In this work, we investigate the behavior and numerical treatment of multiphase flow in porous media. To be more specific, we take the sequestration of CO2 in geological media as an example. Mathematical modeling and numerical study of carbon sequestration helps to predict both short and long-term behavior of CO2 storage in geological media, which can be a benefit in many ways. This work aims at developing accurate and efficient numerical treatment for problems in porous media on non-rectangular geometries. Numerical treatment of Darcy flow and transport have been developed for many years on rectangular and simplical meshes. However, extra effort is required to extend them to general non-rectangular meshes. In this dissertation work, for flow simulation, we develop new H(div)- conforming mixed finite elements (AT and AT [superscript red] ) which are accurate on cuboidal hexahedra. We also develop the new direct serendipity finite element (DS [subscript r] ), which is H1 -conforming and accurate on quadrilaterals and a special family of hexahedra called truncated cubes. The use of the direct serendipity finite element reduces the number of degrees of freedom significantly and therefore accelerates numerical simulations. For transport, we use the newly developed direct serendipity elements in an enriched Galerkin method (EG), which is locally conservative. The entropy viscosity stabilization is applied to eliminate spurious oscillations. We test the EG-DS [subscript r] method on problems with diffusion, transport, and coupled flow and transport. Finally, we study two-phase flow in heterogeneous porous media with capillary pressure. We work on a new formulation of the problem and force the continuity of the capillary flux with a modification to conquer the degeneracy. The numerical simulation of two-phase flow is conducted on non-rectangular grids and uses the new elements.

Download or read book Investigation of Fluid Flow and Contaminant Transport Processes in Heterogeneous Multiphase Systems written by and published by . This book was released on 1999 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: This final technical report summarizes the goals, objectives, experimental results, and continuum and stochastic modeling results from an University Research Initiative project focused on multiphase fluid flow and contaminant transport processes in heterogeneous multiphase systems. This report also annotates the many journal articles, book chapters, reports, newsletter articles, and professional meeting presentations and abstracts produced from this project, and lists the post doctoral associates, doctoral students, and masters students supported by this project. The vast contributions to the scientific literature produced by this project demonstrate the significant impact that this project has on advancing basic science in this important area.

Download or read book Understanding the Plume Dynamics and Risk Associated with CO2 Injection in Deep Saline Aquifers written by Abhishek Kumar Gupta and published by . This book was released on 2011 with total page 506 pages. Available in PDF, EPUB and Kindle. Book excerpt: Geological sequestration of CO2 in deep saline reservoirs is one of the ways to reduce its continuous emission into the atmosphere to mitigate the greenhouse effect. The effectiveness of any CO2 sequestration operation depends on pore volume and the sequestration efficiency of the reservoir. Sequestration efficiency is defined here as the maximum storage with minimum risk of leakage to the overlying formations or to the surface. This can be characterized using three risk parameters i) the time the plume takes to reach the top seal; ii) maximum lateral extent of the plume and iii) the percentage of mobile CO2 present at any time. The selection among prospective saline reservoirs can be expedited by developing some semi-analytical correlations for these risk parameters which can be used in place of reservoir simulation study for each and every saline reservoir. Such correlations can reduce the cost and time for commissioning a geological site for CO2 sequestration. To develop such correlations, a database has been created from a large number of compositional reservoir simulations for different elementary reservoir parameters including porosity, permeability, permeability anisotropy, reservoir depth, thickness, dip, perforation interval and constant pressure far boundary condition. This database is used to formulate different correlations that relate the sequestration efficiency to reservoir properties and operating conditions. The various elementary reservoir parameters are grouped together to generate different variants of gravity number used in the correlations. We update a previously reported correlation for time to hit the top seal and develop new correlations for other two parameters using the newly created database. A correlation for percentage of trapped CO2 is also developed using a previously created similar database. We find that normalizing all risk parameters with their respective characteristic values yields reasonable correlations with different variants of gravity number. All correlations confirm the physics behind plume movement in a reservoir. The correlations reproduce almost all simulation results within a factor of two, and this is adequate for rapid ranking or screening of prospective storage reservoirs. CO2 injection in saline reservoirs on the scale of tens of millions of tonnes may result in fracturing, fault activation and leakage of brine along conductive pathways. Critical contour of overpressure (CoP) is a convenient proxy to determine the risk associated with pressure buildup at different location and time in the reservoir. The location of this contour varies depending on the target aquifer properties (porosity, permeability etc.) and the geology (presence and conductivity of faults). The CoP location also depends on relative permeability, and we extend the three-region injection model to derive analytical expressions for a specific CoP as a function of time. We consider two boundary conditions at the aquifer drainage radius, constant pressure or an infinite aquifer. The model provides a quick tool for estimating pressure profiles. Such tools are valuable for screening and ranking sequestration targets. Relative permeability curves measured on samples from seven potential storage formations are used to illustrate the effect on the CoPs. In the case of a constant pressure boundary and constant rate injection scenario, the CoP for small overpressures is time-invariant and independent of relative permeability. Depending on the relative values of overall mobilities of two-phase region and of brine region, the risk due to a critical CoP which lies in the two-phase region can either increase or decrease with time. In contrast, the risk due to a CoP in the drying region always decreases with time. The assumption of constant pressure boundaries is optimistic in the sense that CoPs extend the least distance from the injection well. We extend the analytical model to infinite-acting aquifers to get a more widely applicable estimate of risk. An analytical expression for pressure profile is developed by adapting water influx models from traditional reservoir engineering to the "three-region" saturation distribution. For infinite-acting boundary condition, the CoP trends depend on same factors as in the constant pressure case, and also depend upon the rate of change of aquifer boundary pressure with time. Commercial reservoir simulators are used to verify the analytical model for the constant pressure boundary condition. The CoP trends from the analytical solution and simulation results show a good match. To achieve safe and secure CO2 storage in underground reservoirs several state and national government agencies are working to develop regulatory frameworks to estimate various risks associated with CO2 injection in saline aquifers. Certification Framework (CF), developed by Oldenburg et al (2007) is a similar kind of regulatory approach to certify the safety and effectiveness of geologic carbon sequestration sites. CF is a simple risk assessment approach for evaluating CO2 and brine leakage risk associated only with subsurface processes and excludes compression, transportation, and injection-well leakage risk. Certification framework is applied to several reservoirs in different geologic settings. These include In Salah CO2 storage project Krechba, Algeria, Aquistore CO2 storage project Saskatchewan, Canada and WESTCARB CO2 storage project, Solano County, California. Compositional reservoir simulations in CMG-GEM are performed for CO2 injection in each storage reservoir to predict pressure build up risk and CO2 leakage risk. CO2 leakage risk is also estimated using the catalog of pre-computed reservoir simulation results. Post combustion CO2 capture is required to restrict the continuous increase of carbon content in the atmosphere. Coal fired electricity generating stations are the dominant players contributing to the continuous emissions of CO2 into the atmosphere. U.S. government has planned to install post combustion CO2 capture facility in many coal fired power plants including W.A. Parish electricity generating station in south Texas. Installing a CO2 capture facility in a coal fired power plant increases the capital cost of installation and operating cost to regenerate the turbine solvent (steam or natural gas) to maintain the stripper power requirement. If a coal-fired power plant with CO2 capture is situated over a viable source for geothermal heat, it may be desirable to use this heat source in the stripper. Geothermal brine can be used to replace steam or natural gas which in turn reduces the operating cost of the CO2 capture facility. High temperature brine can be produced from the underground geothermal brine reservoir and can be injected back to the reservoir after the heat from the hot brine is extracted. This will maintain the reservoir pressure and provide a long-term supply of hot brine to the stripper. Simulations were performed to supply CO2 capture facility equivalent to 60 MWe electric unit to capture 90% of the incoming CO2 in WA Parish electricity generating station. A reservoir simulation study in CMG-GEM is performed to evaluate the feasibility to recycle the required geothermal brine for 30 years time. This pilot study is scaled up to 15 times of the original capacity to generate 900 MWe stripping system to capture CO2 at surface.

Download or read book Multiphase Flow in Porous Media with Phase Transitions written by Xiaojing Fu (Ph. D.) and published by . This book was released on 2017 with total page 175 pages. Available in PDF, EPUB and Kindle. Book excerpt: Ongoing efforts to mitigate climate change include the understanding of natural and engineered processes that can impact the global carbon budget and the fate of greenhouse gases (GHG). Among engineered systems, one promising tool to reduce atmospheric emissions of anthropogenic carbon dioxide (CO2) is geologic sequestration of CO2 , which entails the injection of CO2 into deep geologic formations, like saline aquifers, for long-term storage. Among natural contributors, methane hydrates, an ice-like substance commonly found in seafloor sediments and permafrost, hold large amounts of the world's mobile carbon and are subject to an increased risk of dissociation due to rising temperatures. The dissociation of methane hydrates releases methane gas-a more potent GHG than CO2-and potentially contributes to a positive feedback in terms of climatic change. In this Thesis, we explore fundamental mechanisms controlling the physics of geologic CO2 sequestration and natural gas hydrate systems, with an emphasis on the interplay between multiphase flow-the simultaneous motion of several fluid phases and phase transitions-the creation or destruction of fluid or solid phases due to thermodynamically driven reactions. We first study the fate of CO2 in saline aquifers in the presence of CO2 -brine-carbonate geochemical reactions. We use high-resolution simulations to examine the interplay between the density-driven convective mixing and the rock dissolution reactions. We find that dissolution of carbonate rock initiates in regions of locally high mixing, but that the geochemical reaction shuts down significantly earlier than shutdown of convective mixing. This early shutdown reflects the important role that chemical speciation plays in this hydrodynamics-reaction coupled process. We then study hydrodynamic and thermodynamic processes pertaining to a gas hydrate system under changing temperature and pressure conditions. The framework for our analysis is that of phase-field modeling of binary mixtures far from equilibrium, and show that: (1) the interplay between phase separation and hydrodynamic instability can arrest the Ostwald ripening process characteristic of nonflowing mixtures; (2) partial miscibility exerts a powerful control on the degree of viscous fingering in a gas-liquid system, whereby fluid dissolution hinders fingering while fluid exsolution enhances fingering. We employ this theoretical phase-field modeling approach to explain observations of bubble expansion coupled with gas dissolution and hydrate formation in controlled laboratory experiments. Unraveling this coupling informs our understanding of the fate of hydrate-crusted methane bubbles in the ocean water column and the migration of gas pockets in hydrate-bearing sediments.

Download or read book Large scale Impact of CO2 Storage in Deep Saline Aquifers written by and published by . This book was released on 2008 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: Large volumes of CO2 captured from carbon emitters (such as coal-fired power plants) may be stored in deep saline aquifers as a means of mitigating climate change. Storing these additional fluids may cause pressure changes and displacement of native brines, affecting subsurface volumes that can be significantly larger than the CO2 plume itself. This study aimed at determining the three-dimensional region of influence during/after injection of CO2 and evaluating the possible implications for shallow groundwater resources, with particular focus on the effects of interlayer communication through low-permeability seals. To address these issues quantitatively, we conducted numerical simulations that provide a basic understanding of the large-scale flow and pressure conditions in response to industrial-scale CO2 injection into a laterally open saline aquifer. The model domain included an idealized multilayered groundwater system, with a sequence of aquifers and aquitards (sealing units) extending from the deep saline storage formation to the uppermost freshwater aquifer. Both the local CO2-brine flow around the single injection site and the single-phase water flow (with salinity changes) in the region away from the CO2 plume were simulated. Our simulation results indicate considerable pressure buildup in the storage formation more than 100 km away from the injection zone, whereas the lateral distance migration of brine is rather small. In the vertical direction, the pressure perturbation from CO2 storage may reach shallow groundwater resources only if the deep storage formation communicates with the shallow aquifers through sealing units of relatively high permeabilities (higher than 10 x 18 m2). Vertical brine migration through a sequence of layers into shallow groundwater bodies is extremely unlikely. Overall, large-scale pressure changes appear to be of more concern to groundwater resources than changes in water quality caused by the migration of displaced saline water.

Download or read book Multiphase Flow During Contaminant Transport and Remediation in Subsurface written by May-ru Chen and published by . This book was released on 1995 with total page 350 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Issues Related to Seismic Activity Induced by the Injection of CO2 in Deep Saline Aquifers written by and published by . This book was released on 2001 with total page 15 pages. Available in PDF, EPUB and Kindle. Book excerpt: Case studies, theory, regulation, and special considerations regarding the disposal of carbon dioxide (CO2) into deep saline aquifers were investigated to assess the potential for induced seismic activity. Formations capable of accepting large volumes of CO2 make deep well injection of CO2 an attractive option. While seismic implications must be considered for injection facilities, induced seismic activity may be prevented through proper siting, installation, operation, and monitoring. Instances of induced seismic activity have been documented at hazardous waste disposal wells, oil fields, and other sites. Induced seismic activity usually occurs along previously faulted rocks and may be investigated by analyzing the stress conditions at depth. Seismic events are unlikely to occur due to injection in porous rocks unless very high injection pressures cause hydraulic fracturing. Injection wells in the United States are regulated through the Underground Injection Control (UIC) program. UIC guidance requires an injection facility to perform extensive characterization, testing, and monitoring. Special considerations related to the properties of CO2 may have seismic ramifications to a deep well injection facility. Supercritical CO2 liquid is less dense than water and may cause density-driven stress conditions at depth or interact with formation water and rocks, causing a reduction in permeability and pressure buildup leading to seismic activity. Structural compatibility, historical seismic activity, cases of seismic activity triggered by deep well injection, and formation capacity were considered in evaluating the regional seismic suitability in the United States. Regions in the central, midwestern, and southeastern United States appear best suited for deep well injection. In Ohio, substantial deep well injection at a waste disposal facility has not caused seismic events in a seismically active area. Current technology provides effective tools for investigating and preventing induced seismic activity. More research is recommended on developing site selection criteria and operational constraints for CO2 storage sites near zones of seismic concerns.

Download or read book Fluid Dynamics of Carbon Dioxide Disposal Into Saline Aquifers written by Julio Enrique García and published by . This book was released on 2003 with total page 308 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Flow Through Porous Media written by George Francis Pinder and published by . This book was released on 1983 with total page 146 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Numerical Modeling of Multiphase Transport of Multicomponent Organic Contaminants and Heat in the Subsurface written by Adeyinka Emmanuel Adenekan and published by . This book was released on 1992 with total page 458 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Multiphase Flow and Multispecies Transport in the Subsurface written by Wonyong Jang and published by . This book was released on 2008-07-01 with total page 176 pages. Available in PDF, EPUB and Kindle. Book excerpt: In order to protect groundwater resources from pollution and to clean up contaminated sites, we should understand the fate and transport of contaminants in the subsurface and physical-chemical-biological processes involving remediation. To enhance our understanding, numerical studies are performed on (i) multiphase flow and multispecies transport of volatile organic compounds (VOCs), (ii) biological transformations of contaminants, (iii) in-situ air sparging (IAS), and (iv) thermal enhanced venting in the subsurface. Among VOCs, trichloroethylene, dichloroethylenes, and vinyl chloride are chosen as target contaminants herein. The effects of density-driven advection of gas phase and biotransformation of contaminants on their fate and transport are analyzed under various environmental conditions involving infiltration, permeability, and bioreaction kinetics. Under IAS, the interactive dynamic flows of water and injected air through porous media in the subsurface are elucidated. A three-dimensional numerical model, called TechFlowMP, is developed, verified, and validated using analytical solutions and experimental data published in the literature.

Download or read book Influence of Relative Permeability Curves on Extent of CO2 Plume During Injection Into Deep Saline Aquifers written by Sang-yeop Park and published by . This book was released on 2007 with total page 388 pages. Available in PDF, EPUB and Kindle. Book excerpt: