Download or read book Coupled CO2 Sequestration and Enhanced Oil Recovery Optimization Using Experimental Design and Response Surface Methodology written by Jorge E. Ramirez Salazar and published by . This book was released on 2009 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Reservoir Simulation Studies for Coupled CO2 Sequestration and Enhanced Oil Recovery written by Yousef Ghomian and published by . This book was released on 2008 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: Compositional reservoir simulation studies were performed to investigate the effect of uncertain reservoir parameters, flood design variables, and economic factors on coupled CO2 sequestration and EOR projects. Typical sandstone and carbonate reservoir properties were used to build generic reservoir models. A large number of simulations were needed to quantify the impact of all these factors and their corresponding uncertainties taking into account various combinations of the factors. The design of experiment method along with response surface methodology and Monte-Carlo simulations were utilized to maximize the information gained from each uncertainty analysis. The two objective functions were project profit in the form of $/bbl of oil produced and sequestered amount of CO2 in the reservoir. The optimized values for all objective functions predicted by design of experiment and the response surface method were found to be close to the values obtained by the simulation study, but with only a small fraction of the computational time. After the statistical analysis of the simulation results, the most to least influential factors for maximizing both profit and amount of stored CO2 are the produced gas oil ratio constraint, production and injection well types, and well spacing. For WAG injection scenarios, the Dykstra-Parsons coefficient and combinations of WAG ratio and slug size are important parameters. Also for a CO2 flood, no significant reduction of profit occurred when only the storage of CO2 was maximized. In terms of the economic parameters, it was demonstrated that the oil price dominates the CO2 EOR and storage. This study showed that sandstone reservoirs have higher probability of need for CO2i ncentives. In addition, higher CO2 credit is needed for WAG injection scenarios than continuous CO2 injection. As the second part of this study, scaling groups for miscible CO2 flooding in a three-dimensional oil reservoir were derived using inspectional analysis with special emphasis on the equations related to phase behavior. Some of these scaling groups were used to develop a new MMP correlation. This correlation was compared with published correlations using a wide range of reservoir fluids and found to give more accurate predictions of the MMP.

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 Co optimization of CO2 Sequestration and Enhanced Oil Recovery and Co optimization of CO2 Sequestration and Methane Recovery in Geopressured Aquifers written by Serdar Bender and published by . This book was released on 2011 with total page 210 pages. Available in PDF, EPUB and Kindle. Book excerpt: In this study, the co-optimization of carbon dioxide sequestration and enhanced oil recovery and the co-optimization of carbon dioxide sequestration and methane recovery studies were discussed. Carbon dioxide emissions in the atmosphere are one of the reasons of global warming and can be decreased by capturing and storing carbon dioxide. Our aim in this study is to maximize the amount of carbon dioxide sequestered to decrease carbon dioxide emissions in the atmosphere and maximize the oil or methane recovery to increase profit or to make a project profitable. Experimental design and response surface methodology are used to co-optimize the carbon dioxide sequestration and enhanced oil recovery and carbon dioxide sequestration and methane recovery. At the end of this study, under which circumstances these projects are profitable and under which circumstances carbon dioxide sequestration can be maximized, are given.

Download or read book Optimal Process Design for Coupled CO2 Sequestration and Enhanced Gas Recovery in Carbonate Reservoirs written by Uchenna Odi Odi and published by . This book was released on 2014 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: Increasing energy demand combined with public concern for the environment obligates the oil industry to supply oil and natural gas to the public while minimizing the carbon footprint due to its activities. Today, fossil fuels are essential in meeting the global energy needs, but have the undesirable outcome of producing carbon dioxide. Carbon dioxide (CO2) injection in reservoirs is an appealing Enhanced Oil/Gas Recovery method for increasing hydrocarbon production by using the miscible interactions between hydrocarbon and carbon dioxide. Carbon dioxide flooding is beneficial to the environment and to petroleum producers, since it can store carbon dioxide while increasing oil and natural gas production. A practical challenge in combining CO2 Sequestration with Enhanced Gas Recovery (EGR) is determining the optimal process parameters that maximize the project value. This research describes the development of a procedure to determine the best process conditions for the CO2 EGR and Sequestration process. Analysis includes experimental work that illustrates that CO2 is able to reduce the dew point pressure of wet gas fluids and that reservoir fluid phase changes can be indicated by changes in total fluid compressiblity. In addition, compositional simulation illustrates that CO2 improves condensate and natural gas recovery. Studies show that the ideal reservoir management strategy for CO2 EGR is to set the CO2 injectors' bottom hole pressure to the initial reservoir pressure. An economic model is developed that illustrates the capital investment necessary for the CO2 EGR and Sequestration process for different capture technologies and levels of captured CO2 impurity. This economic model is utilized in conjunction with an optimization algorithm to illustrate the potential profitability of theCO2 EGR and Sequestration project. To illustrate the economic risk associated with CO2 EGR and Sequestration project, probabilistic analysis is used to illustrate scenarios where the technology is successful. This work is applicable to carbonate wet gas reservoirs that have significant gas production problems associated with condensate blockage. This work is also useful in modeling the economics associated with CO2 EGR and CO2 Sequestration. The strategy developed in this work is applicable to designing process conditions that correspond to optimal CO2 EGR and optimal CO2 Sequestration. The electronic version of this dissertation is accessible from http://hdl.handle.net/1969.1/151726

Download or read book Economic Incentives for Coupled Enhanced Oil Recovery EOR and CO2 Sequestration in Hydrocarbon Reservoirs written by Mehmet Barkin Urun and published by . This book was released on 2009 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: This study presents an engineering and economic analysis to estimate the financial incentives that may be required to motivate coupled enhanced oil recovery (EOR) and CO2 capture and storage (CCS) projects. Because CO2 is considered to be a major contributor to global warming, its storage in oil reservoirs could have long term economic and environmental benefits. The engineering foundations of the study are compositional reservoir simulations that accounts for all the major technical parameters, and provide data on the reservoir performance over time. In order to carry out the reservoir simulations in an efficient way, Computer Modelling Group GEM reservoir simulator was added to the UT IRSP platform. Experimental design and a project economic model were then applied to the reservoir simulation outputs to estimate the levels of CO2 credit required to motivate coupled EOR and storage. In the first part of the study, the effect of technical and economic variables on the CO2 credit was studied for the case of a mature oil reservoir. In the second part, a similar analysis was conducted for marginal (low quality) oil reservoirs. The results suggest that CO2 credit would necessarily have to be provided, in both low and high price scenarios, to motivate coupled EOR and CCS. Also, it appears that any credit scheme that is implemented must consider reservoir physical characteristics, CO2 injection method and the configuration of wells as the most significant variables.

Download or read book Integrated Reservoir Studies for CO2 Enhanced Oil Recovery and Sequestration written by Shib Sankar Ganguli and published by Springer. This book was released on 2017-03-30 with total page 147 pages. Available in PDF, EPUB and Kindle. Book excerpt: This book addresses the feasibility of CO2-EOR and sequestration in a mature Indian oil field, pursuing for the first time a cross-disciplinary approach that combines the results from reservoir modeling and flow simulation, rock physics modeling, geomechanics, and time-lapse (4D) seismic monitoring study. The key findings presented indicate that the field under study holds great potential for enhanced oil recovery (EOR) and subsequent CO2 storage. Experts around the globe argue that storing CO2 by means of enhanced oil recovery (EOR) could support climate change mitigation by reducing the amount of CO2 emissions in the atmosphere by ca. 20%. CO2-EOR and sequestration is a cutting-edge and emerging field of research in India, and there is an urgent need to assess Indian hydrocarbon reservoirs for the feasibility of CO2-EOR and storage. Combining the fundamentals of the technique with concrete examples, the book is essential reading for all researchers, students and oil & gas professionals who want to fully understand CO2-EOR and its geologic sequestration process in mature oil fields.

Download or read book CO2 EOR storage Design Optimization Under Uncertainty written by Amin Ettehadtavakkol and published by . This book was released on 2013 with total page 728 pages. Available in PDF, EPUB and Kindle. Book excerpt: A partnership between oilfield operators and the federal government in the coupled CO2 enhanced oil recovery (EOR) and storage projects brings long-term benefits for both. We quantify the win-win condition for this partnership in terms of an optimum storage tax credit. We describe the field-scale design optimization of coupled CO2-EOR and storage operations from the viewpoint of oilfield operators. We introduce a CO2 market model and investigate two special CO2 market problems, namely a fixed storage requirement and an integrated asset optimization. The first problem follows an environmental objective by giving priority to the storage element of CO2-EOR and storage; the second prioritizes the oil recovery and relies on the principles of a free market where CO2 is a commodity and the commitment to storage is made based on the economic benefits. We investigate the CO2 market sustainability conditions and quantitatively derive them for the fixed storage requirement and integrated asset optimization problems. Ultimately, we quantify the impact of storage tax credit on the operator benefits, the federal government benefits, and the optimum economic storage capacity of an oilfield. CO2 EOR-storage projects are long-term and capital-intensive and therefore vulnerable to the risks of the CO2 market. Two important uncertain economic parameters are investigated, the oil price and the storage tax credit. The government plays an important role in reducing the CO2 market risks because it has the leverage to regulate the storage tax credit. The stochastic optimization results show that a transparent storage tax credit reinforces the sustainability of the CO2 market and helps both the government and the oilfield operators boost their long-term benefits.

Download or read book Numerical Simulation and Optimization of Carbon Dioxide Utilization for Enhanced Oil Recovery from Depleted Reservoirs written by Razi Safi and published by . This book was released on 2015 with total page 80 pages. Available in PDF, EPUB and Kindle. Book excerpt: Due to concerns about rising CO2 emissions from fossil fuel power plants, there has been a strong emphasis on the development of a safe and economical method for Carbon Capture Utilization and Storage (CCUS). One area of current interest in CO2 utilization is the Enhanced Oil Recovery (EOR) from depleted reservoirs. In an Enhanced Oil Recovery system, a depleted or depleting oil reservoir is re-energized by injecting high-pressure CO2 to increase the recovery factor of the oil from the reservoir. An additional benefit beyond oil recovery is that the reservoir could also serve as a long-term storage vessel for the injected CO2. Although this technology is old, its application to depleted reservoirs is relatively recent because of its dual benefit of oil recovery and CO2 storage thereby making some contributions to the mitigation of anthropogenic CO2 emissions. Since EOR from depleted reservoirs using CO2 injection has been considered by the industry only recently, there are uncertainties in deployment that are not well understood, e.g. the efficiency of the EOR system over time, the safety of the sequestered CO2 due to possible leakage from the reservoir. Furthermore, it is well known that the efficiency of the oil extraction is highly dependent on the CO2 injection rate and the injection pressure. Before large scale deployment of this technology can occur, it is important to understand the mechanisms that can maximize the oil extraction efficiency as well as the CO2 sequestration capacity by optimizing the CO2 injection parameters, namely, the injection rate and the injection pressure. In this thesis, numerical simulations of subsurface flow in an EOR system is conducted using the DOE funded multiphase flow solver COZView/COZSim developed by Nitec, LLC. A previously developed multi-objective optimization code based on a genetic algorithm developed in the CFD laboratory of the Mechanical Engineering department of Washington University in St. Louis is modified for the use the COZView/COZSim software for optimization applications to EOR. In this study, two reservoirs are modeled. The first is based on a benchmark reservoir described in the COZSim tutorial; the second is a reservoir in the Permian Basin in Texas for which extensive data is available. In addition to pure CO2 injection, a Water Alternating Gas (WAG) injection scheme is also investigated for the same two reservoirs. Optimizations for EOR Constant Gas Injection (CGI) and WAG injection schemes are conducted with a genetic algorithm (GA) based optimizer combined with the simulation software COZSim. Validation of the obtained multi-objective optimizer was achieved by comparing its results with the results obtained from the built-in optimization function within the COZView graphic user interface. Using our GA based optimizer, optimal constant-mass and pressure-limited injection profiles are determined for EOR. In addition, the use of recycled gas is also investigated. Optimization of the EOR problem results in an increased recovery factor with a more efficient utilization of injected CO2. The results of this study should help in paving the way for future optimization studies of other systems such as Enhanced Gas Recovery (EGR) and Enhanced Geothermal Systems (EGS) that are currently being investigated and considered for CCUS.

Download or read book Co optimization of enhanced oil recovery and carbon sequestration written by Andrew J. Leach and published by . This book was released on 2009 with total page 30 pages. Available in PDF, EPUB and Kindle. Book excerpt: In this paper, we present what is to our knowledge the first theoretical economic analysis of CO2- enhanced oil recovery (EOR). This technique, which has been used successfully in a number of oil plays (notably in West Texas, Wyoming, and Saskatchewan), entails injection of CO2 into mature oil fields in a manner that reduces the oil's viscosity, thereby enhancing the rate of extraction. As part of this process, significant quantities of CO2 remain sequestered in the reservoir. If CO2 emissions are regulated, oil producers using EOR should therefore be able to earn sequestration credits in addition to oil revenues. We develop a theoretical framework that analyzes the dynamic co-optimization of oil extraction and CO2 sequestration, through the producer's choice at each point in time of an optimal CO2 fraction in the injection stream (the control variable). We find that the optimal fraction is likely to decline monotonically over time, and reach zero before the optimal termination time. Numerical simulations, based on an ongoing EOR project in Wyoming, confirm this result. They show also that cumulative sequestration is positively related to the oil price, and is in fact much more responsive to oil-price increases than to increases in the carbon tax. Only at very high taxes does a tradeoff between oil output and sequestration arise.

Download or read book Performance Evaluation of CO2 EOR in Tight Oil Formation with Complex Fracture Geometries written by Pável Zuloaga Molero and published by . This book was released on 2016 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: The recent development of tight oil reservoirs has led to an increase in oil production in the past several years due to the progress in horizontal drilling and hydraulic fracturing. However, the oil recovery factor expected is still very low even after the wells have been fractured and therefore, tight formations are considered good candidates for enhanced oil recovery (EOR). One of the most suitable solutions to improve the oil recovery is the carbon dioxide (CO2)-based EOR. Although the injection of CO2 is not new for conventional oil reservoirs, its practice in tight oil formations is still a relatively novel idea. Two injection-production strategies are often employed: continuous CO2 injection or flooding and CO2 Huff-n-Puff. However, it is not clear which scenario is the best strategy to achieve an optimal recovery, which highly depends on many uncertain reservoir and fracture parameters and it is not clearly understood until recently. Another challenge of the estimation of the incremental recovery of these injection approaches is to properly model the hydraulic fractures and CO2 transport mechanism. The actual hydraulic fracturing process often creates complex fracture networks, especially when the fracture propagates in a formation with a large amount of pre-existing natural fractures. In this study, the CO2-EOR effectiveness is simulated and analyzed by comparing the Huff-n-Puff and the continuous injection scenarios. The effect of matrix permeability on the comparison of well performance of these two scenarios was investigated. Subsequently, Design of Experiment and Response Surface Methodology is used to perform sensitivity studies with four uncertain parameters including matrix permeability, number of wells, well pattern, and fracture half-length to determine the best injection approach. In addition, an efficient methodology of embedded discrete fracture model (EDFM) is introduced to explicitly model complex fracture geometries. The effects of complex fracture geometries on well performance of CO2 Huff-n-Puff and CO2 continuous injection were also investigated as well as the effect of natural fractures. The analysis of the CO2-EOR effectiveness confirms that the appropriate modelling of the complex fractures geometry plays a critical role in estimation of the incremental oil recovery. This study provides new insights into a better understanding of the impacts of reservoir permeability, complex hydraulic fractures and natural fractures on well performance during CO2-EOR process in tight oil reservoirs and in the determination and design of the optimal injection-production scheme to maximize the oil recovery factor for multi-fractured horizontal wells.

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 115 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 Co optimization of Enhanced Oil Recovery and Carbon Sequestration written by Andrew Leach and published by . This book was released on 2009 with total page 30 pages. Available in PDF, EPUB and Kindle. Book excerpt: In this paper, we present what is to our knowledge the first theoretical economic analysis of CO2- enhanced oil recovery (EOR). This technique, which has been used successfully in a number of oil plays (notably in West Texas, Wyoming, and Saskatchewan), entails injection of CO2 into mature oil fields in a manner that reduces the oil's viscosity, thereby enhancing the rate of extraction. As part of this process, significant quantities of CO2 remain sequestered in the reservoir. If CO2 emissions are regulated, oil producers using EOR should therefore be able to earn sequestration credits in addition to oil revenues. We develop a theoretical framework that analyzes the dynamic co-optimization of oil extraction and CO2 sequestration, through the producer's choice at each point in time of an optimal CO2 fraction in the injection stream (the control variable). We find that the optimal fraction is likely to decline monotonically over time, and reach zero before the optimal termination time. Numerical simulations, based on an ongoing EOR project in Wyoming, confirm this result. They show also that cumulative sequestration is positively related to the oil price, and is in fact much more responsive to oil-price increases than to increases in the carbon tax. Only at very high taxes does a tradeoff between oil output and sequestration arise.

Download or read book Computational Optimization Methods and Algorithms written by Slawomir Koziel and published by Springer. This book was released on 2011-06-17 with total page 292 pages. Available in PDF, EPUB and Kindle. Book excerpt: Computational optimization is an important paradigm with a wide range of applications. In virtually all branches of engineering and industry, we almost always try to optimize something - whether to minimize the cost and energy consumption, or to maximize profits, outputs, performance and efficiency. In many cases, this search for optimality is challenging, either because of the high computational cost of evaluating objectives and constraints, or because of the nonlinearity, multimodality, discontinuity and uncertainty of the problem functions in the real-world systems. Another complication is that most problems are often NP-hard, that is, the solution time for finding the optimum increases exponentially with the problem size. The development of efficient algorithms and specialized techniques that address these difficulties is of primary importance for contemporary engineering, science and industry. This book consists of 12 self-contained chapters, contributed from worldwide experts who are working in these exciting areas. The book strives to review and discuss the latest developments concerning optimization and modelling with a focus on methods and algorithms for computational optimization. It also covers well-chosen, real-world applications in science, engineering and industry. Main topics include derivative-free optimization, multi-objective evolutionary algorithms, surrogate-based methods, maximum simulated likelihood estimation, support vector machines, and metaheuristic algorithms. Application case studies include aerodynamic shape optimization, microwave engineering, black-box optimization, classification, economics, inventory optimization and structural optimization. This graduate level book can serve as an excellent reference for lecturers, researchers and students in computational science, engineering and industry.

Download or read book Enhanced Heavy Oil Recovery Using CO2 Huff N Puff Process written by Xiang Zhou and published by . This book was released on 2019 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: CO2 based enhanced oil recovery methods, such as continuous CO2 injection, intermittent CO2 injection, water-alternating CO2 injection, and CO2 huff 'n' puff, are successfully implemented in heavy oil reservoirs. Among them, the CO2 huff 'n' puff method has been proved as an applicable recovery method. Although many previous researches were conducted on the CO2 huff 'n' puff process applied in heavy oil reservoirs, some technical issues are still not investigated, such as non-equilibrium phase behaviors of foamy oil flow, CO2 diffusion into heavy oil, and the production performance in CO2 huff 'n' puff process coupled with non-equilibrium phase behaviors and CO2 diffusion. Therefore, this study aims at addressing the following major topics. Non-equilibrium phase behaviors of foamy oil flow. In order to investigate the foamy oil flow behavior in the primary production process, experimental studies on nonequilibrium phase behaviors of heavy oil-methane system are implemented in a pressure/volume/temperature cell with different pressure decline methods. The experimental results indicate that, with pressure decline rate increases, the pseudo-bubblepoint pressure decreases, leading to longer pressure duration of foamy oil, so that the foamy oil stability becomes stronger under higher pressure depletion rate. To study foamy oil stability in the production stage of the CO2 huff 'n' puff process, the non-equilibrium phase behaviors are investigated using the heavy oil-CO2 system. The same experimental methods are applied with that in the heavy oil-methane system, but the gas transfers rates (solution gas transfers to dispersed gas, dispersed gas transfers to free gas) in heavy oil- CO2 system are much higher than that observed in the heavy oil-methane system. A dynamic reaction rate model is developed to match the foamy oil stability using heavy oil- CO2 system, and high agreements are achieved. The reaction rate constants (k1 and k2) among different gas phases are determined through the history match. The performance of foamy oil flow, in the production stage of the CO2 huff 'n' puff process, highly relates to the amount of CO2 dissolves into heavy oil during the soaking stage. To understand the CO2 diffusion process in the heavy oil, CO2 diffusion coefficient is measured in both bulk phase (high pressure cell) and porous media (real reservoir core). The CO2 diffusion coefficient determination process mainly includes: (1) experimental study is conducted to measure the pressures in the diffusion process using the pressure decay method; (2) mathematical modeling study is carried out to calculate the CO2 diffusion coefficients using the history match method. Based on the understandings of the non-equilibrium phase behaviors and CO2 diffusion, the heavy oil production performance in CO2 huff 'n' puff process coupled with non-equilibrium phase behavior and CO2 diffusion is investigated. Six CO2 huff 'n' puff experiments are carried out using long cores (60 cm). The main affect parameters are studied, including pressure depletion rates (0.5, 1, 4, and 16 kPa/min), soaking time (5, 10, and 20 hours) and cycle numbers. Via experimental study, an equation which indicates the relationship of the cumulative oil and gas production in each cycle and each test is gained with high agreement. The experimental results indicate that the CO2 huff 'n' puff process can be an efficient approach to enhance heavy oil production with a recovery factor of 38.02%. The optimized pressure depletion rates, soaking time and cycle numbers are 1 kPa/min, 5 hours and 3 cycles, respectively, and the optimization parameters are upscaled for field application using scaling criteria.

Download or read book CO2 Sequestration and EOR Cooptimization in a Mature Field written by Yang Chang and published by . This book was released on 2014 with total page 70 pages. Available in PDF, EPUB and Kindle. Book excerpt: CO2 Enhanced Oil Recovery (CO2 -EOR) has been a mature technology for more than 40 years. This EOR process offers opportunities to mitigate CO2 emissions through co-optimization of CO2 sequestration and EOR. In this thesis, we focus on the Tensleep Sandstone to simulate CO2 -EOR and sequestration, and analyzed the effect of different injection scenarios. Research has been conducted to study mechanisms in CO2 -EOR and CO2 -sequestration, respectively. CO2 -EOR mechanisms in the simulation included CO2 dissolution in crude oil to decrease viscosity and swelling crude oil. For CO2 sequestration, CO2 was allowed to get trapped in the pore space by hysteresis effects and dissolved in formation water through solubility. Based on a geostatistical model with detailed information on the reservoir geology, a dynamic model was built using the compositional simulator CMG-GEM. Simulation results for CO2 -EOR and sequestration in Tensleep B sandstone will serve future economic evaluations and reservoir development design. The sequence of injection influences oil recovery; the best timing for CO2 injection to obtain a maximum oil recovery is the beginning of reservoir exploitation. When it comes to CO2 sequestration, the best timing of CO2 injection leading to the maximum storage volume is after continuous water injection. For water-alternating-gas scenarios, six month cycles are recommend, based on the high oil recovery observed and perceived lower operating cost.

Download or read book Carbon Dioxide Enhanced Oil Recovery and Sequestration in the Orion Oil Field in the North Slope Region of Alaska written by Banabas D. Dogah and published by . This book was released on 2021 with total page 238 pages. Available in PDF, EPUB and Kindle. Book excerpt: Carbon dioxide flooding in viscous oil systems has been proven to improve oil recovery and store CO2 in several geologic basins worldwide. With global energy steadily transitioning towards decarbonization, CO2-EOR and Sequestration can reduce the carbon footprint from crude oil production. Although well accepted globally, the potential of improved oil recovery and CO2 storage capacity has not been extensively studied in Alaska. Since the CO2 injection process involves phase transition, reservoir simulation becomes more complex. It requires reliable techniques to estimate the ultimate recovery factor, oil production rate, and CO2 storage volumes precisely. This study focuses on carbon dioxide enhanced oil recovery (CO2-EOR) and storage in the Orion satellite field of Alaska, its ability to reduce greenhouse gases, and the technical and economic feasibility of a CO2 flooding project. In this study, the Peng-Robinson equation of state is tuned to model fluid behavior from the respective sands accurately. Core flooding results from the Orion Oil Pool in the Schrader Bluff Formation provided the basis for developing relative permeability curves for the various layers in the geological model. The geological model was then coupled with the developed fluid model and introduced into a compositional simulator capable of handling the heterogeneous complexity to simulate CO2 injection. Simulations suggested that the CO2 gas injection is partially miscible in the Orion reservoir at pressures close to the average initial reservoir pressure. Consequently, CO2 mixes with oil in the reservoir, reduces oil viscosity, increases oil mobility, and improves oil recovery. Different simulation scenarios were considered and compared, including the effects of fluid injection mixtures on oil recovery, well trajectory effects, and production bottom hole pressure effects on oil recovery. A considerable volume of injected CO2 is expected to be sequestered in the reservoir, for which economic analysis is conducted for tax credit purposes. The results show that 40% Enriched CO2 injection achieved the highest oil recovery, which highlights the importance of selecting the appropriate injector and producer well trajectory. This work provides insights into the optimum CO2 gas flooding controlling parameters for incremental oil production through sensitivity analysis. The study's novelty is further expanded by quantifying the potential of CO2 sequestration in each layer of the Orion oil field.