Download or read book Analytical Estimation of CO2 Storage Capacity in Depleted Oil and Gas Reservoirs Based on Thermodynamic State Functions written by Ernesto Valbuena Olivares and published by . This book was released on 2012 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: Numerical simulation has been used, as common practice, to estimate the CO2 storage capacity of depleted reservoirs. However, this method is time consuming, expensive and requires detailed input data. This investigation proposes an analytical method to estimate the ultimate CO2 storage in depleted oil and gas reservoirs by implementing a volume constrained thermodynamic equation of state (EOS) using the reservoir?s average pressure and fluid composition. This method was implemented in an algorithm which allows fast and accurate estimations of final storage, which can be used to select target storage reservoirs, and design the injection scheme and surface facilities. Impurities such as nitrogen and carbon monoxide, usually contained in power plant flue gases, are considered in the injection stream and can be handled correctly in the proposed algorithm by using their thermodynamic properties into the EOS. Results from analytical method presented excellent agreement with those from reservoir simulation. Ultimate CO2 storage capacity was predicted with an average difference of 1.3%, molar basis, between analytical and numerical methods; average oil, gas, and water saturations were also matched. Additionally, the analytical algorithm performed several orders of magnitude faster than numerical simulation, with an average of 5 seconds per run.

Download or read book Natural Gas Processing from Midstream to Downstream written by Nimir O. Elbashir and published by John Wiley & Sons. This book was released on 2019-02-04 with total page 584 pages. Available in PDF, EPUB and Kindle. Book excerpt: A comprehensive review of the current status and challenges for natural gas and shale gas production, treatment and monetization technologies Natural Gas Processing from Midstream to Downstream presents an international perspective on the production and monetization of shale gas and natural gas. The authors review techno-economic assessments of the midstream and downstream natural gas processing technologies. Comprehensive in scope, the text offers insight into the current status and the challenges facing the advancement of the midstream natural gas treatments. Treatments covered include gas sweeting processes, sulfur recovery units, gas dehydration and natural gas pipeline transportation. The authors highlight the downstream processes including physical treatment and chemical conversion of both direct and indirect conversion. The book also contains an important overview of natural gas monetization processes and the potential for shale gas to play a role in the future of the energy market, specifically for the production of ultra-clean fuels and value-added chemicals. This vital resource: Provides fundamental chemical engineering aspects of natural gas technologies Covers topics related to upstream, midstream and downstream natural gas treatment and processing Contains well-integrated coverage of several technologies and processes for treatment and production of natural gas Highlights the economic factors and risks facing the monetization technologies Discusses supply chain, environmental and safety issues associated with the emerging shale gas industry Identifies future trends in educational and research opportunities, directions and emerging opportunities in natural gas monetization Includes contributions from leading researchers in academia and industry Written for Industrial scientists, academic researchers and government agencies working on developing and sustaining state-of-the-art technologies in gas and fuels production and processing, Natural Gas Processing from Midstream to Downstream provides a broad overview of the current status and challenges for natural gas production, treatment and monetization technologies.

Download or read book ANALYSIS OF THE EFFICACY OF CARBON DIOXIDE SEQUESTRATION IN DEPLETED SHALE GAS RESERVOIRS written by Ihsan Kulga and published by . This book was released on 2014 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: In this study, the possibility of industrial CO2 storage in shale gas reservoirs is investigated numerically by using one of the most advanced computational simulators in oil and gas industry, PSU-SHALECOMP, which is a compositional dual porosity, dual permeability, multi-phase reservoir simulator. A computationally inexpensive "stimulated reservoir volume" (SRV) model which has the ability to generate a similar behavior of an equivalent discrete fracture network model is defined and implemented. Three different commercial production profiles are history-matched by using the SRV approach effectively. It is re-proved that implementation of the horizontal borehole technology and hydraulic fracturing are the two most important factors that will increase the efficacy of methane production and carbon dioxide injection processes. It is observed that significantly large percentage of the produced gas originates from the fractured zone so as significantly large percentage of the injected gas will end up occupying the pore spaces in the fractured zone. Injection of carbon dioxide into undepleted shale gas reservoirs is not promising because of its ultra-tight permeability characteristics. Injection of carbon dioxide into shale gas reservoirs that have produced approximately 30\% of the initial gas in place is promising. It is observed that when 30\% of shale gas production is achieved, up to 70\% of the depleted gas volume is expected to be replaced by carbon dioxide.The storage capacity of the depleted shale gas reservoir can be increased by injecting carbon dioxide at a rather low rate. A low rate injection of carbon dioxide will increase its residence time in the flow domain increasing its chances for adsorption.If the SRV zones of the production and injection wells are not in direct communication, it is not expected to see carbon dioxide breakthrough at the producing well. It is also investigated that contribution of carbon dioxide in enhancing the shale gas recovery is negligible. The study includes developments of four artificial neural network tools that have different production of methane and injection of carbon dioxide constraints. These four forward tools can produce production and injection profiles of a given system within an error range of 3.83\% to 5.23\%. This part of the study also includes four additional artificial neural network tools that predicts wellbore design and hydraulic fracture characteristics within an error range of 8.24\% to 9.93\%.

Download or read book Numerical study of underground CO2 storage and the utilization in depleted gas reservoirs written by Cheng Cao and published by Cuvillier Verlag. This book was released on 2021-03-01 with total page 200 pages. Available in PDF, EPUB and Kindle. Book excerpt: Carbon capture and storage (CCS) is considered as the most promising technology for slowing down the atmospheric CO2 emissions. However, CCS has not been implemented on large scale because of the related risks and the lack of financial incentives. Regarding the risks associated with CCS, a parametric uncertainty analysis for CO2 storage was conducted and the general roles of different key geomechanical and hydrogeological parameters in response to CO2 injection were determined, which is beneficial for guiding time and effort spent mitigating the uncertainty to acquire trustworthy model forecasts and risk assessments. Regarding the financial incentives of CCS, co-injection of CO2 with impurities associated with enhanced gas recovery was analyzed, which is advantageous for decreasing the cost on gas separation and generating additional economic profit. In addition, the utilization of CO2 as cushion gas in the underground gas storage reservoir was proposed and analyzed, which can also be beneficial for improving the cost-effectiveness of CCS. Overall, this thesis is advantageous for promoting the application of CCS on large scale and mitigating the atmospheric CO2 emissions. Die Kohlenstoffabscheidung und –speicherung (CCS) gilt als die vielversprechendste Technologie zur Verlangsamung der atmosphärischen CO2–Emissionen. CCS wurde jedoch aufgrund der damit verbundenen Risiken und des Mangels an finanziellen Anreizen nicht in großem Umfang implementiert. In Bezug auf die mit CCS verbundenen Risiken wurde eine parametrische Unsicherheitsanalyse für die CO2-Speicherung durchgeführt und die allgemeinen Rollen verschiedener geomechanischer und hydrogeologischer Schlüsselparameter als Reaktion auf die CO2-Injektion ermittelt. Dies ist hilfreich, um den Zeit- und Arbeitsaufwand für die Minderung der Unsicherheit zu verringern, um vertrauenswürdig zu werden Modellprognosen und Risikobewertungen. In Bezug auf die finanziellen Anreize von CCS wurde die gleichzeitige Injektion von CO2 mit Verunreinigungen im Zusammenhang mit einer verbesserten Gasrückgewinnung analysiert. Dies ist vorteilhaft, um die Kosten für die Gastrennung zu senken und zusätzlichen wirtschaftlichen Gewinn zu erzielen. Darüber hinaus wurde die Verwendung von CO2 als Polstergas im unterirdischen Gasspeicher vorgeschlagen und analysiert, was auch zur Verbesserung der Wirtschaftlichkeit von CCS beitragen kann. Insgesamt ist diese These vorteilhaft, um die Anwendung von CCS in großem Maßstab zu fördern und die atmosphärischen CO2-Emissionen zu verringern.

Download or read book Data Driven Analytics for the Geological Storage of CO2 written by Shahab Mohaghegh and published by CRC Press. This book was released on 2018-05-20 with total page 282 pages. Available in PDF, EPUB and Kindle. Book excerpt: Data-driven analytics is enjoying unprecedented popularity among oil and gas professionals. Many reservoir engineering problems associated with geological storage of CO2 require the development of numerical reservoir simulation models. This book is the first to examine the contribution of artificial intelligence and machine learning in data-driven analytics of fluid flow in porous environments, including saline aquifers and depleted gas and oil reservoirs. Drawing from actual case studies, this book demonstrates how smart proxy models can be developed for complex numerical reservoir simulation models. Smart proxy incorporates pattern recognition capabilities of artificial intelligence and machine learning to build smart models that learn the intricacies of physical, mechanical and chemical interactions using precise numerical simulations. This ground breaking technology makes it possible and practical to use high fidelity, complex numerical reservoir simulation models in the design, analysis and optimization of carbon storage in geological formations projects.

Download or read book Mathematical Modeling of Extended Interface During Gravity Drainage With Application to CO2 Sequestration written by Farshad Arfaei Malekzadeh and published by . This book was released on 2013 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: Removal of CO2 directly from anthropogenic sources (capture) and its disposal in geological formations can take place for medium-term time periods (storage), or it can be permanent (sequestration), with the CO2 eventually becoming dissolved in the aqueous phase. The latter is the main subject of this dissertation. Carbon dioxide sequestration covers a wide range of strategies and alternatives. The main objective of CO2 sequestration alternatives is secure disposal of carbon in large amounts and for a lengthy time scale (typically 1000 years). Injection of CO2 into subsurface formations is generally considered as the main option for CO2 sequestration. Geological sequestration through injection covers a broad variety of target formations: disposal in depleted oil and gas reservoirs, trapping in oil reservoirs, replacing CH4 in coal bed methane recovery processes, trapping in deep aquifers, and salt cavern placement are the major CCS alternatives in geologic formations. In this thesis, hydrogeologic interaction between the injectant (CO2) and the host fluid (saline water) during injection is the main subject of the project. Because of the density and viscosity contrast of displacing and displaced fluids, the pattern of saturation progression is complicated. A set of semi-analytical solutions is developed for quick estimation of the position of isosats (contours of saturation) during primary injection in homogenous cases with simple geometry. All of the mathematical solutions are developed based on two assumptions; incompressible fluids and rocks and vertical equilibrium (capillary-gravity condition) for geometries with large aspect ratio (L ” H). First, a series of analytical solutions for primary drainage for a set of linear relative permeability functions is developed. The first analytical solution is based on the assumption of locally linearized Leverett-J functions, and by using the method of characteristics, a formulation for the isosats' geometry is obtained. A semi-analytical solution is then proposed for calculation of the position of isosats with linearized relative permeability functions and arbitrary capillary-saturation correlation. The analytical solution is extended to incorporate a specific form of nonlinearity of the relative permeability function. Nonlinear relative permeability functions are also incorporated in another semi-analytical solution, and the positions of the isosats for any arbitrary Leverett-J function and relative permeability functions are developed. Sequential gas-saline injection is also modeled in that chapter. For approximate verification of the analytical solutions, a FEM numerical model is developed and the results of the analytical solutions are compared with the numerical solutions. These new analytical solutions provide powerful tools for prediction of saturation distribution during injection in vertical and horizontal wells, as well as for carrying out stochastic assessments (Monte Carlo simulations) and parametric weight assessment. The domain of applications of the new solutions go far beyond the limited question of CO2 sequestration: they can be used for injection of any less viscous fluid into a reservoir, whether the fluid is lighter or denser than the host fluid (gas injection, water-alternating gas injection, water injection into viscous oil reservoirs, solvent injection).

Download or read book Engineering Aspects of Geologic CO2 Storage written by Dayanand Saini and published by Springer. This book was released on 2017-03-22 with total page 85 pages. Available in PDF, EPUB and Kindle. Book excerpt: This timely book explores the lessons learned in and potentials of injecting supercritical CO2 into depleted oil and gas reservoirs, in order to maximize both hydrocarbon recovery and the storage capacities of injected CO2. The author provides a detailed discussion of key engineering parameters of simultaneous CO2 enhanced oil recovery and CO2 storage in depleted hydrocarbon reservoirs. These include candidate site selection, CO2 oil miscibility, maximizing CO2-storage capacity in enhanced oil recovery operations, well configurations, and cap and reservoir rock integrity. The book will help practicing professionals devise strategies to curb greenhouse gas emissions from the use of fossil fuels for energy production via geologic CO2 storage, while developing CO2 injection as an economically viable and environmentally sensible business model for hydrocarbon exploration and production in a low carbon economy.

Download or read book Techno economic Assessment of Industrial Co2 Storage in Depleted Shale Gas Reservoirs written by Farid Tayari and published by . This book was released on 2014 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: This research suggests two categories of carbon management methods to help control and reduce net CO2 emissions: increasing the efficiency of energy processes to reduce CO2 production and utilizing processes after CO2 production to reduce the amount of emission.Second chapter analyzes the use of remotely controllable household water heaters as a technique that can reduce the variability cost of wind power in the system. Produced wind power is variable and integrating large scale wind power with power system needs backup facility to keep the system reliable. Thus, variability of wind power imposes cost on the system which is called variability cost. Using a computational model, this research simulates a system of three elements: wind farm, household water heaters and grid (as power system) and suggests that using controllable water heaters as demand side management policy can help reducing variability cost of entire system. This chapter analyzes and compares three scenarios to show the effect of distributed thermal storage on variability of wind power. Third chapter develops a techno-economic model for assessment of industrial CO2 storage in Shale gas reservoirs. CO2 storage in underground deep formations can be a long-term efficient way for carbon management. In this method, CO2 needs to be captured from emitter (industrial plant), pressurized, transported with pipeline and then injected to the reservoir. CO2 sequestration for Enhanced Gas Recovery is technically feasible but its economic feasibility depends on many factors. This research has developed a techno-economic model, integrated with a reservoir simulation tool (SRM), to analyze costs associated with CO2 sequestration in Shale gas. Cost structure in techno-economic model has four parts (modules): Transportation, Injection, Production, and Post-Injection Site Care. Each module generates individual results and also contributes with other modules in producing overall results. Various scenarios defined and tested with the model to give a better understanding about sensitivity and importance of input parameters.Fourth chapter utilizes the upgraded version of techno-economic model to run stochastic, uncertainty, and sensitivity analysis. This chapter also studies the production and injection timing under uncertainty to find more efficient results. In addition to results in third chapter, subsurface and economic parameters have substantial impact on costs and revenue. Reservoir properties along with well characteristics determine CH4 production, CO2 injection, storage capacity, possible CO2 breakthrough in production and so on. Upgraded model has the capability of studying sensitivity of each single geologic property individually or any combination of them. Forth chapter will study the impact of influential variables to explore the sensitivity of outputs to major inputs.

Download or read book Analytical Solution for Joule Thomson Cooling During CO2 Geo sequestration in Depleted Oil and Gas Reservoirs written by and published by . This book was released on 2010 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: Mathematical tools are needed to screen out sites where Joule-Thomson cooling is a prohibitive factor for CO2 geo-sequestration and to design approaches to mitigate the effect. In this paper, a simple analytical solution is developed by invoking steady-state flow and constant thermophysical properties. The analytical solution allows fast evaluation of spatiotemporal temperature fields, resulting from constant-rate CO2 injection. The applicability of the analytical solution is demonstrated by comparison with non-isothermal simulation results from the reservoir simulator TOUGH2. Analysis confirms that for an injection rate of 3 kg s−1 (0.1 MT yr−1) into moderately warm (>40 C) and permeable formations (>10−14 m2 (10 mD)), JTC is unlikely to be a problem for initial reservoir pressures as low as 2 MPa (290 psi).

Download or read book Geologic Characterization and Modeling for Quantifying CO2 Storage Capacity of the High Island 10 L Field in Texas State Waters Offshore Gulf of Mexico written by Omar Ramirez Garcia and published by . This book was released on 2019 with total page 32 pages. Available in PDF, EPUB and Kindle. Book excerpt: Carbon dioxide capture and storage (CCS) is a promising technology for mitigating climate change by reducing CO2 emissions to the atmosphere and injecting captured industrial emissions into deep geologic formations. Deep subsurface storage in geologic formations is similar to trapping natural hydrocarbons and is one of the key components of CCS technology. The quantification of the available subsurface storage resource is the subject of this research project. This study focuses on site-specific geologic characterization, reservoir modeling, and CO2 storage resource assessment (capacity) of a depleted oil and gas field located on the inner continental shelf of the Gulf of Mexico, the High Island 10L field. lower Miocene sands in the Fleming Group beneath the regional transgressive Amphistegina B shale have extremely favorable geologic properties (porosity, thickness, extent) and are characterized in this study utilizing 3-D seismic and well logs. Key stratigraphic surfaces between maximum flooding surfaces (MFS-9 to MFS-10) demonstrate how marine regression and transgression impact the stacking pattern of the thick sands and overlying seals, influencing the overall potential for CO2 storage. One of the main uncertainties when assessing CO2 storage resources at different scales is to determine the fraction of the pore space within a formation that is practically accessible for storage. The goal of the modeling section of this project is to address the uncertainty related to the static parameters affecting calculations of available pore space by creating facies and porosity geostatistical models based on the spatial variation of the available data. P50 values for CO2 storage capacity range from 37.56 to 40.39 megatonnes (Mt), showing a narrow distribution of values for different realizations of the geostatistical models. An analysis of the pressure build-up effect on storage capacity was also performed, showing a reduction in capacity. This research further validates the impact of the current carbon tax credit program (45Q), applied directly to the storage resources results for the High Island field 10L using a simple NPV approach based on discounted cash flows. Several scenarios are assessed, where the main variables are the duration of the applicability of the tax credit, number of injection wells, and total storage capacity. Results are measured in terms of the cost of capture required for a project to be economic, given previous assumptions.

Download or read book Assessing the Effect of Timing of Availability for Carbon Dioxide Storage in the Largest Oil and Gas Pools in the Alberta Basin written by and published by . This book was released on 2007 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: Carbon dioxide capture from large stationary sources and storage in geological media is a technologically-feasible mitigation measure for the reduction of anthropogenic emissions of CO2 to the atmosphere in response to climate change. Carbon dioxide (CO2) can be sequestered underground in oil and gas reservoirs, in deep saline aquifers, in uneconomic coal beds and in salt caverns. The Alberta Basin provides a very large capacity for CO2 storage in oil and gas reservoirs, along with significant capacity in deep saline formations and possible unmineable coal beds. Regional assessments of potential geological CO2 storage capacity have largely focused so far on estimating the total capacity that might be available within each type of reservoir. While deep saline formations are effectively able to accept CO2 immediately, the storage potential of other classes of candidate storage reservoirs, primarily oil and gas fields, is not fully available at present time. Capacity estimates to date have largely overlooked rates of depletion in these types of storage reservoirs and typically report the total estimated storage capacity that will be available upon depletion. However, CO2 storage will not (and cannot economically) begin until the recoverable oil and gas have been produced via traditional means. This report describes a reevaluation of the CO2 storage capacity and an assessment of the timing of availability of the oil and gas pools in the Alberta Basin with very large storage capacity (>5 MtCO2 each) that are being looked at as likely targets for early implementation of CO2 storage in the region. Over 36,000 non-commingled (i.e., single) oil and gas pools were examined with effective CO2 storage capacities being individually estimated. For each pool, the life expectancy was estimated based on a combination of production decline analysis constrained by the remaining recoverable reserves and an assessment of economic viability, yielding an estimated depletion date, or year that it will be available for CO2 storage. The modeling framework and assumptions used to assess the impact of the timing of CO2 storage resource availability on the region's deployment of CCS technologies is also described. The purpose of this report is to describe the data and methodology for examining the carbon dioxide (CO2) storage capacity resource of a major hydrocarbon province incorporating estimated depletion dates for its oil and gas fields with the largest CO2 storage capacity. This allows the development of a projected timeline for CO2 storage availability across the basin and enables a more realistic examination of potential oil and gas field CO2 storage utilization by the region's large CO2 point sources. The Alberta Basin of western Canada was selected for this initial examination as a representative mature basin, and the development of capacity and depletion date estimates for the 227 largest oil and gas pools (with a total storage capacity of 4.7 GtCO2) is described, along with the impact on source-reservoir pairing and resulting CO2 transport and storage economics. The analysis indicates that timing of storage resource availability has a significant impact on the mix of storage reservoirs selected for utilization at a given time, and further confirms the value that all available reservoir types offer, providing important insights regarding CO2 storage implementation to this and other major oil and gas basins throughout North America and the rest of the world. For CCS technologies to deploy successfully and offer a meaningful contribution to climate change mitigation, CO2 storage reservoirs must be available not only where needed (preferably co-located with or near large concentrations of CO2 sources or emissions centers) but also when needed. The timing of CO2 storage resource availability is therefore an important factor to consider when assessing the real opportunities for CCS deployment in a given region.

Download or read book CO2 Reservoir Oil Miscibility written by Dayanand Saini and published by Springer. This book was released on 2018-06-25 with total page 104 pages. Available in PDF, EPUB and Kindle. Book excerpt: This SpringerBrief critically examines the latest experimental and non-experimental approaches used for the fast and reliable characterization and determination of CO2-reservoir oil miscibility in terms of the minimum miscibility pressure (MMP). This book serves as a one-stop source for developing an enhanced understanding of these available methods, and specifically documents, analyses, and evaluates their suitability and robustness for depicting and characterizing the phenomenon of CO2-reservoir oil miscibility in a fast and cost-effective manner. Such information can greatly assist a project team in selecting an appropriate MMP determination method as per the project’s need at a given project’s stage, be that screening, design, or implementation. CO2-Reservoir Oil Miscibility: Experiential and Non-Experimental Characterization and Determination Approaches will be of interest to petroleum science and engineering professionals, researchers, and undergraduate and graduate students engaged in CO2 enhanced oil recovery (EOR) and/or simultaneous CO2-EOR and storage projects and related research. It may also be of interest to engineering and management professionals within the petroleum industry who have responsibility for implementing CO2-EOR projects.

Download or read book Geological Storage of CO2 written by Jan Martin Nordbotten and published by John Wiley & Sons. This book was released on 2011-10-24 with total page 212 pages. Available in PDF, EPUB and Kindle. Book excerpt: Despite the large research effort in both public and commercial companies, no textbook has yet been written on this subject. This book aims to provide an overview to the topic of Carbon Capture and Storage (CSS), while at the same time focusing on the dominant processes and the mathematical and numerical methods that need to be employed in order to analyze the relevant systems. The book clearly states the carbon problem and the role of CCS and carbon storage. Thereafter, it provides an introduction to single phase and multi-phase flow in porous media, including some of the most common mathematical analysis and an overview of numerical methods for the equations. A considerable part of the book discusses the appropriate scales of modeling, and how to formulate consistent governing equations at these scales. The book also illustrates real world data sets and how the ideas in the book can be exploited through combinations of analytical and numerical approaches.

Download or read book Perspectives to CO2 Geological Storage and Greenhouse Gas Negative Emissions in South Southeastern Brazil written by Raíssa Moreira Lima Mendes Musarra and published by Blucher Open Access. This book was released on 2022-07-04 with total page 229 pages. Available in PDF, EPUB and Kindle. Book excerpt: This book presents the latest studies of the CNPq Research Group (Estudos para Armazenamento Geológico de Carbono – CCS) of the Institute of Energy and Environment/Research Centre for Greenhouse Gas Innovation, at the University of Sao Paulo. The studies are related to the technical and regulatory issues for implementing Carbon, Capture and Storage (CCS) technologies, especially CO2 geological storage in the Paraná and Santos Basins. The parent project, entitled "Carbon Geological Storage in Brazil: "Perspectives for CCS in unconventional petroleum reservoirs of onshore Paraná sedimentary basin and turbidites from offshore sedimentary basins in southeast Brazil", was funded by SHELL and FAPESP. The book intends to provide an overview of the potential for secured long-term CO2 storage in the Paraná and Santos basins with high prospects for CCS. The central academic findings refer to CO2 reservoir properties and main criteria for site selection to improve the Brazilian CCUS development's decision-making process and contribute to the R&D plan for greenhouse gas emissions mitigation of the Southeastern Region, with geological evaluations and regulatory analyses. The book aims to improve the decision-making process in greenhouse gases mitigation and energy/environmental governance; therefore, it captures the specialized and non-specialized audience.

Download or read book Engineering Aspects of Geologic CO2 Storage written by Dayanand Saini and published by . This book was released on 2017 with total page 73 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book CO2 Storage Coupled with Enhanced Oil Recovery written by Kun Sang Lee and published by Springer Nature. This book was released on 2020-03-09 with total page 114 pages. Available in PDF, EPUB and Kindle. Book excerpt: This book provides a comprehensive and detailed description of the various mechanisms of the CCS–EOR process. Whereas previous texts have primarily focused on carbon capture and storage (CCS) and enhanced oil recovery (EOR) separately, this book provides a general overview of both technologies when used together. Coupled CCS–EOR technology has become increasingly important, as it overcomes the respective shortcomings of the two technologies. The book presents an integrated numerical model including the hysteresis effect, solubility trapping, miscibility, and formation damage by asphaltene deposition. The experimental and model-based evaluation of fluid properties is also discussed. The book concludes by discussing the latest research into CO2 storage coupled with EOR, most notably performance control by including additives in CO2 injection, and CO2 injection into shale reservoirs. Ideally suited for graduate students and researchers in the fields of carbon capture, utilisation, and storage, the book shares essential insights into maximising the efficiency of CCS and EOR alike.

Download or read book Evaluating the Variability of Static Carbon Dioxide Storage Capacity Estimates Through Integrated Analysis of Reservoir Structure Aquifer Performance and Thermodynamic Behaviour written by Amy Louise Clarke and published by . This book was released on 2014 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: