[PDF] Coupled Co2 Sequestration And Enhanced Oil Recovery Optimization Using Experimental Design And Response Surface Methodology eBook

Author : Yousef Ghomian
Publisher :
Page : 0 pages
File Size : 50,94 MB
Release : 2008
Category : Enhanced oil recovery
ISBN :

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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.

Author : Kun Sang Lee
Publisher : Springer Nature
Page : 114 pages
File Size : 50,32 MB
Release : 2020-03-09
Category : Technology & Engineering
ISBN : 3030419010

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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.

Author : Serdar Bender
Publisher :
Page : 210 pages
File Size : 35,48 MB
Release : 2011
Category :
ISBN :

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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.

Author : Uchenna Odi Odi
Publisher :
Page : pages
File Size : 30,5 MB
Release : 2014
Category :
ISBN :

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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

Author : Mehmet Barkin Urun
Publisher :
Page : 0 pages
File Size : 26,49 MB
Release : 2009
Category :
ISBN :

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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.

Author : Shib Sankar Ganguli
Publisher : Springer
Page : 147 pages
File Size : 28,36 MB
Release : 2017-03-30
Category : Science
ISBN : 3319558439

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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.

Author : Amin Ettehadtavakkol
Publisher :
Page : 728 pages
File Size : 42,20 MB
Release : 2013
Category :
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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.

Author : Razi Safi
Publisher :
Page : 80 pages
File Size : 42,4 MB
Release : 2015
Category : Electronic dissertations
ISBN :

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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.

Author : Andrew J. Leach
Publisher :
Page : 30 pages
File Size : 42,98 MB
Release : 2009
Category : Carbon sequestration
ISBN :

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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.