Download or read book Modelling Enhanced Gas Recovery by CO2 Injection in Partially depleted Reservoirs written by Salim Goudarzi 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 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 CO2 Injection for Enhanced Gas Production and Carbon Sequestration written by and published by . This book was released on 2001 with total page 10 pages. Available in PDF, EPUB and Kindle. Book excerpt: Analyses suggest that carbon dioxide (CO2) can be injected into depleted gas reservoirs to enhance methane (CH4) recovery for periods on the order of 10 years, while simultaneously sequestering large amounts of CO2. Simulations applicable to the Rio Vista Gas Field in California show that mixing between CO2 and CH4 is slow relative to repressurization, and that vertical density stratification favors enhanced gas recovery.

Download or read book Reservoir Simulation of CO2 Sequestration and Enhanced Oil Recovery in Tensleep Formation Teapot Dome Field written by Ricardo Gaviria Garcia and published by . This book was released on 2006 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: Teapot Dome field is located 35 miles north of Casper, Wyoming in Natrona County. This field has been selected by the U.S. Department of Energy to implement a field-size CO2 storage project. With a projected storage of 2.6 million tons of carbon dioxide a year under fully operational conditions in 2006, the multiple-partner Teapot Dome project could be one of the world's largest CO2 storage sites. CO2 injection has been used for decades to improve oil recovery from depleted hydrocarbon reservoirs. In the CO2 sequestration technique, the aim is to "co-optimize" CO2 storage and oil recovery. In order to achieve the goal of CO2 sequestration, this study uses reservoir simulation to predict the amount of CO2 that can be stored in the Tensleep Formation and the amount of oil that can be produced as a side benefit of CO2 injection. This research discusses the effects of using different reservoir fluid models from EOS regression and fracture permeability in dual porosity models on enhanced oil recovery and CO2 storage in the Tensleep Formation. Oil and gas production behavior obtained from the fluid models were completely different. Fully compositional and pseudo-miscible black oil fluid models were tested in a quarter of a five spot pattern. Compositional fluid model is more convenient for enhanced oil recovery evaluation. Detailed reservoir characterization was performed to represent the complex characteristics of the reservoir. A 3D black oil reservoir simulation model was used to evaluate the effects of fractures in reservoir fluids production. Single porosity simulation model results were compared with those from the dual porosity model. Based on the results obtained from each simulation model, it has been concluded that the pseudo-miscible model can not be used to represent the CO2 injection process in Teapot Dome. Dual porosity models with variable fracture permeability provided a better reproduction of oil and water rates in the highly fractured Tensleep Formation.

Download or read book Carbon Sequestration in Natural Gas Reservoirs written by and published by . This book was released on 2003 with total page 8 pages. Available in PDF, EPUB and Kindle. Book excerpt: Natural gas reservoirs are obvious targets for carbon sequestration by direct carbon dioxide (CO2) injection by virtue of their proven record of gas production and integrity against gas escape. Carbon sequestration in depleted natural gas reservoirs can be coupled with enhanced gas production by injecting CO2 into the reservoir as it is being produced, a process called Carbon Sequestration with Enhanced Gas Recovery (CSEGR). In this process, supercritical CO2 is injected deep in the reservoir while methane (CH4) is produced at wells some distance away. The active injection of CO2 causes repressurization and CH4 displacement to allow the control and enhancement of gas recovery relative to water-drive or depletion-drive reservoir operations. Carbon dioxide undergoes a large change in density as CO2 gas passes through the critical pressure at temperatures near the critical temperature. This feature makes CO2 a potentially effective cushion gas for gas storage reservoirs. Thus at the end of the CSEGR process when the reservoir is filled with CO2, additional benefit of the reservoir may be obtained through its operation as a natural gas storage reservoir. In this paper, we present discussion and simulation results from TOUGH2/EOS7C of gas mixture property prediction, gas injection, repressurization, migration, and mixing processes that occur in gas reservoirs under active CO2 injection.

Download or read book Modelling CO2 Injection Into Depleted Gas Reservoirs and Saline Aquifers written by Brendan Michael Feather and published by . This book was released on 2010 with total page 250 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book CLEAN written by Michael Kühn and published by Springer Science & Business Media. This book was released on 2012-12-14 with total page 202 pages. Available in PDF, EPUB and Kindle. Book excerpt: The project CLEAN (CO2 Large-Scale Enhanced Gas Recovery in the Altmark Natural Gas Field) provides site specific knowledge for a potential future pilot project. This contributed volume gives an overview and final results of the entire project which is finalized to the end of 2012.

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 CO2 Geological Sequestration and Utilization for Enhanced Gas oil Recovery from Molecular Perspectives written by Mingshan Zhang and published by . This book was released on 2022 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: Atmospheric CO2 concentration has been gradually growing since the industrial revolution, leading to climate change and global warming. As a result, carbon capture, utilization, and sequestration (CCUS) has become utterly important for human society. CO2 geological sequestration in depleted shale gas reservoirs is regarded as a promising strategy to mitigate the emission of CO2. As one of the typical clay minerals in shale reservoirs, kaolinite presents two structurally and chemically distinct basal surfaces known as siloxane and gibbsite surfaces which can significantly affect CO2 adsorption in kaolinite nanopores, especially in the presence of water. Nevertheless, due to the complicated surface properties and pore structures, it is practically impossible to distinguish the contributions from two distinct kaolinite surfaces for CO2 adsorption. In addition, to the best of our knowledge, the effect of moisture on CO2 adsorption in different kaolinite nanopores is rarely reported. We systematically explored CO2 adsorption in partially water-saturated kaolinite nanopores by molecular dynamics (MD) and Grand canonical Monte Carlo (GCMC) simulations using the flexible clay model. In the absence of water, CO2 presents a stronger adsorption ability on gibbsite surfaces. In gibbsite pores, the water tends to spread out on the surface forming a thin film while water bridges are observed in siloxane pores. In siloxane mesopores, a more CO2-wet surface appears as pressure increases, while it is not obvious in micropores because of stronger confinement effects. In general, the presence of water will result in the reduction of CO2 sequestration in both gibbsite and siloxane pores, while a slight enhancement is observed in siloxane mesopores when the pressure is quite low. CO2 utilization for enhancing gas recovery has been attracting extensive attention as it can greatly alleviate the financial burden from CO2 capture while it can also achieve CO2 sequestration in the deep formations. Compared with the conventional reservoirs, shale has heterogeneous rock compositions consisting of organic and inorganic matters and some shale formations contain anextensive number of heavier alkanes, such as ethane (C2) and propane (C3). While CO2 huff-n-puff is proved to be an effective method to enhance recovery of methane (C1), competitive adsorption between shale gas mixtures (C1-C2-C3) and CO2 in organic and clay minerals remains unexplored. On the other hand, the different recovery mechanisms of hydrocarbon mixtures during pressure drop, CO2 huff, and CO2 huff are still unclear. We used Grand Canonical Monte Carlo (GCMC) simulations to study competitive sorption of C1-C2-C3 and C1-C2-C3-CO2 mixtures in shale organic and inorganic nanopores under different production schemes. We found that while C1 in the adsorption layer can be readily recovered during pressure drawdown, C2 and C3 are trapped in pores, especially in organic micropores. CO2 injection can effectively recover each component in the adsorption layer in organic pores, while in inorganic pores, the adsorption layer is dominated by CO2 molecules, displacing all hydrocarbon components. Additionally, application of CO2 responsive surfactants provides a novel idea for economical and sustainable oil production. While the experimental work can test and design a promising smart surfactant formula for efficient O/W emulsification and demulsification processes, the microscopic structural properties and interface hydration structures related to CO2 switching mechanisms from molecular perspectives remain unclear. MD simulations are employed to carefully study the interfacial properties of n-heptane/water emulsion before and after purging CO2 using lauric acids (LA) as the surfactant. Before purging CO2, the deprotonated lauric acid (DLA) help to form and stabilize O/W emulsion droplets in aqueous solution due to high interface activity and strong surface electrostatic repulsion, whereas the protonation of lauric acid (PLA) arising from CO2 injection results in the coalescence of emulsion droplets thanks to the increased IFT and surface charge neutralization, which is also in line the potential mean force (PMF) calclation resutls.

Download or read book Numerical Study of Underground CO2 Storage and the Utilization in Depleted Gas Reservoirs written by Cheng Cao and published by . This book was released on 2021-03 with total page 200 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Numerical Simulation and Optimization of Carbon Dioxide Utilization and Storage in Enhanced Gas Recovery and Enhanced Geothermal Systems written by James H. Biagi and published by . This book was released on 2014 with total page 75 pages. Available in PDF, EPUB and Kindle. Book excerpt: With rising concerns surrounding CO2 emissions from fossil fuel power plants, there has been a strong emphasis on the development of safe and economical Carbon Capture Utilization and Storage (CCUS) technology. Two methods that show the most promise are Enhanced Gas Recovery (EGR) and Enhanced Geothermal Systems (EGS). In Enhanced Gas Recovery a depleted or depleting natural gas reservoir is re-energized with high pressure CO2 to increase the recovery factor of the gas. As an additional benefit following the extraction of natural gas, the reservoir would serve as a long-term storage vessel for the captured carbon. CO2 based Enhanced Geothermal Systems seek to increase the heat extracted from a given geothermal reservoir by using CO2 as a working fluid. Carbon sequestration is accomplished as a result of fluid losses throughout the life of the geothermal system. Although these technologies are encouraging approaches to help in the mitigation of anthropogenic CO2 emissions, the detailed mechanisms involved are not fully understood. There remain uncertainties in the efficiency of the systems over time, and the safety of the sequestered CO2 due to leakage. In addition, the efficiency of both natural gas extraction in EGR and heat extraction in EGS are highly dependent on the injection rate and injection pressure. Before large scale deployment of these technologies, it is important to maximize the extraction efficiency and sequestration capacity by optimizing the injection parameters. In this thesis, numerical simulations of subsurface flow in EGR and EGS are conducted using the DOE multiphase flow solver TOUGH2 (Transport of Unsaturated Groundwater and Heat). A previously developed multi-objective optimization code based on a genetic algorithm is modified for applications to EGR and EGS. For EGR study, a model problem based on a benchmark-study that compares various mathematical and numerical models for CO2 storage is considered. For EGS study a model problem based on previous studies (with parameters corresponding to the European EGS site at Soultz) is considered. The simulation results compare well with the computations of other investigators and give insight into the parameters that can influence the simulation accuracy. Optimizations for EGR and EGS problems are carried out with a genetic algorithm (GA) based optimizer combined with TOUGH2, designated as GA-TOUGH2. Validation of the optimizer was achieved by comparison of GA based optimization studies with the brute-force run of large number of simulations. Using GA-TOUGH2, optimal time-independent and time-dependent injection profiles were determined for both EGR and EGS. Optimization of EGR problem resulted in a larger natural gas production rate, a shorter total operation time, and an injection pressure well below the fracture pressure. Optimization of EGS problem resulted in a precise management of the production temperature profile, heat extraction for the entire well life, and more efficient utilization of CO2. The results of these studies will hopefully pave the way for future GA-TOUGH2 based optimization studies to improve the modeling of CCUS projects.

Download or read book Carbon Dioxide Flooding Basic Mechanisms and Project Design written by Mark A. Klins and published by Springer. This book was released on 1984-09-10 with total page 296 pages. Available in PDF, EPUB and Kindle. Book excerpt:

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 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 Enhanced Oil Recovery and Carbon Dioxide Sequestration in Zama Keg River F Pool written by Adal Al-Dliwe and published by . This book was released on 2005 with total page 352 pages. Available in PDF, EPUB and Kindle. Book excerpt: Carbon dioxide (CO2) injection is an effective and promising technology for enhanced oil recovery and for reducing anthropogenic gas emissions. In this process, CO2 develops miscibility with the oil under reservoir conditions and leads to additional oil recovery. Proper reservoir characterization has a significant influence on implementing a successful CO2 flood in a reservoir. Computer simulation is an important tool for reservoir characterization and predicting optimal tradeoffs between maximum oil recovery and CO2 storage. This thesis presents the results of reservoir characterization analysis and simulation in Zama Keg River F Pool located in Northern Alberta, Canada, which was selected as a candidate for CO2 injection. This reef has a thick oil column spanned over a small area and two wells drilled on the same side of the reef. Open-hole logs and core analysis data were available for only one of the two wells. Data analyses disclosed a number of challenges that could adversely affect the results of any simulation for predicting the performance of CO2 displacement in this field. These challenges included, but were not limited to, the existence of two no-flow barriers with unknown extensions, lack of other data such as relative permeability, and lack of information on lateral distribution of the reservoir properties. Material balance analysis indicated the maximum oil in place was 4.7 MMSTB with a weak water support. A fully compositional reservoir simulation model was used to improve the understanding of the reservoir characteristics, investigate the potential amount of CO2 stored, and study the effect of CO2 injection on oil recovery using different injection strategies. Effects of different operational parameters on pore scale displacement efficiency and the overall displacement efficiency were studied. These parameters include production and injection rates, injection gas composition, well completion, mode of injection, and the timing of injection. Results of this thsesi show that by using a combination of two vertical injectors and one horizontal producer, maximum incremental oil would be recovered while a large volume of CO2 would be stored, a high net utilization factor was obtained, and maximum NPV was generated as compared to other injection-production schemes.

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 Development of coupled THM models for reservoir stimulation and geo energy production with supercritical CO2 as working fluid written by Jianxing Liao and published by Cuvillier Verlag. This book was released on 2020-07-28 with total page 180 pages. Available in PDF, EPUB and Kindle. Book excerpt: In this dissertation, two specific numerical models have been developed to address the issues associated with utilization of supercritical CO2, like fracture creation, proppant placement and fracture closure in unconventional gas reservoirs, reservoir stimulation, heat production and CO2 sequestration in deep geothermal reservoirs, respectively. In unconventional gas reservoir, the model consisting of classic fracture model, proppant transport model as well as temperature-sensitive fracturing fluids (CO2, thickened CO2 and guar gum) has been integrated into the popular THM coupled framework (TOUGH2MP-FLAC3D), which has the ability to simulate single fracture propagation driven by different fracturing fluids in non-isothermal condition. To characterize the fracture network propagation and internal multi fluids behavior in deep geothermal reservoirs, an anisotropic permeability model on the foundation of the continuum anisotropic damage model has been developed and integrated into the popular THM coupled framework (TOUGH2MP-FLAC3D) as well. This model has the potential to simulate the reservoir stimulation and heat extraction based on a CO2-EGS concept.