Download or read book Simulation of CO2 Exsolution for Enhanced Oil Recovery and CO2 Storage written by Scott R. McLaughlin and published by . This book was released on 2016 with total page 82 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 CO2 Exsolution Challenges and Opportunities in Subsurface Flow Management written by Lin Zuo and published by . This book was released on 2014 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: Carbon dioxide is known to be highly soluble in water/brine, up to 5% mass fraction under reservoir conditions. In geological carbon sequestration, a large amount of injected CO2 will dissolve in brine over time. Exsolution occurs when pore pressures decline and CO2 solubility in brine decreases, resulting in the formation of a separate CO2 phase. This scenario occurs in carbon sequestration reservoirs by upward migration of CO2 saturated brine, through faults, leaking boreholes or even seals. In this way, dissolved CO2 could migrate out of storage reservoir and form a gas phase at shallower depths. Questions such as how exsolved CO2 distributes and transports, and how multiphase flows and trapping are altered in a reservoir undergoing exsolution need to be answered to achieve better subsurface flow management and risk evaluation. This study summarizes the results regarding the implications of exsolution on storage security, including pore-scale and core-scale experiments, pore-scale modeling, and numerical simulations. Applications of CO2 exsolution in Enhanced Oil Recovery are also explored. Microscopic observation of CO2 exsolution in porous media under reservoir conditions have shown that, different from an injected CO2 phase, where the gas remains interconnected and distributes at capillary equilibrium, exsolved CO2 nucleates in various locations of a porous medium, forms disconnected bubbles and propagates by repeated expansion-snap off process under capillary instability. A good correlation between bubble size distribution and pore size distribution is observed, indicating that geometry of the pore space plays an important role in controlling the mobility of brine and exsolved CO2. Core-scale multiphase flow experiments demonstrate that in the process where growing gas bubbles displace water (drainage), the water relative permeability drops significantly and is disproportionately reduced compared to gas injection, and the CO2 relative permeability remains very low, 10^-5 to 10^-3, even when the exsolved CO2 saturation increases to over 40%. Furthermore, during imbibition, exsolved CO2 remains trapped even under relatively high capillary numbers (~ 10^-6), and the water relative permeability at the imbibition endpoint is one third to one half of that with water displacing injected CO2. A model is developed to simulate the growth of exsolved gas phase in porous media under capillarity. Results are compared with experimental observations using three dimensional micro X-ray tomography. Convective transfer in the aqueous phase has been demonstrated to play an important role in controlling bubble growth and accumulation. With a Stokes flow simulator, water relative permeability curves are estimated for various sedimentary rocks under different conditions. We are capable of matching modeled gas distribution and relative permeabilities with experimental data, and extrapolating expected phase mobility reductions under reservoir conditions. CO2 exsolution does not appear to create significant risks for storage security. Due to the low mobility of exsolved CO2 and its large impact on reducing water flow, if carbonated brine migrates upwards and exsolution occurs, brine migration would be greatly reduced and limited by the presence of exsolved CO2 and the consequent low relatively permeability to brine. Similarly, if an exsolved CO2 phase were to evolve in the seal, for example, after CO2 injection stops, the effect would be to reduce the permeability to brine and the CO2 would have very low mobility. It is also possible that CO2 exsolution could have an effect on CO2-EOR recovery. This flow blocking effect is studied in experiments with water/oil/CO2 for the purpose of water conformance and oil recovery enhancement. Experiments show that exsolved CO2 performs as a secondary residual phase in porous media that effectively blocks established water flow paths and deviates water to residual oil zones, thereby increasing recovery. Overall, our studies suggest that CO2 exsolution provides an opportunity for mobility control in subsurface processes. For example, CO2 exsolution generated intentionally increases water sweep efficiency in oil reservoirs and forms gas barriers to seal high permeability zones. However, while the experimental evidence for dramatic mobility reduction is clear, the lack of simulation capability that accounts for differences between the CO2 phase morphology resulting from gas injection and gas exsolution creates challenges for modeling and hence, designing studies to exploit the mobility reduction capabilities of CO2 exsolution. Not only is history dependent behavior (hysteresis) important, but also process dependent behavior is needed. Using traditional drainage multiphase flow parameterization in simulations involving exsolution will lead to overestimates of flows and large errors in transport rates. Development of process dependent parameterizations of multiphase flow properties will be a key next step and will help to unlock the benefits from gas exsolution.

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 Enhanced Oil Recovery Field Case Studies written by S. Lee and published by Elsevier Inc. Chapters. This book was released on 2013-04-10 with total page 62 pages. Available in PDF, EPUB and Kindle. Book excerpt: Based on the enhanced oil recovery (EOR) survey in Oil and Gas Journal (2010), approximately 280,000bbl of oil per day or 6% of US crude oil production was produced by carbon dioxide (CO2) EOR. Just like any other gas injection processes, field CO2 flooding projects suffer from poor sweep efficiency due to early gas breakthrough, unfavorable mobility ratio, reservoir heterogeneity, viscous fingering and channeling, and gravity segregation. Many of these problems are believed to be alleviated or overcome by foaming the injected CO2. Since the 1970s, CO2-foam flooding has been used as a commercially viable method for EOR processes. Foams, defined as a mixture of internal gas phase in a continuous external liquid phase containing surfactant molecules, can improve sweep efficiency significantly by reducing gas mobility, especially in the reservoirs with a high level of geological heterogeneity. This chapter consists of three main parts: the first part (Section 2.1) deals with fundamentals on foams in porous media and recent advances in this field of research, including three foam states (weak-foam, strong-foam, and intermediate states) and two steady-state flow regimes of strong foams; the second part (Section 2.2) overviews field examples of foam-assisted CO2-EOR processes; and the third part (Section 2.3) covers typical field injection and production responses if CO2-foam pilot or field-scale treatments are successful.

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 Forecasting CO2 Sequestration with Enhanced Oil Recovery written by William Ampomah and published by Mdpi AG. This book was released on 2022-12-14 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: The aim of carbon capture, utilization, and storage (CCUS) is to reduce the amount of CO2 released into the atmosphere and to mitigate its effects on climate change. Over the years, naturally occurring CO2 sources have been utilized in enhanced oil recovery (EOR) projects in the United States. This has presented an opportunity to supplement and gradually replace the high demand for natural CO2 sources with anthropogenic sources. There also exist incentives for operators to become involved in the storage of anthropogenic CO2 within partially depleted reservoirs, in addition to the incremental production oil revenues. These incentives include a wider availability of anthropogenic sources, the reduction of emissions to meet regulatory requirements, tax incentives in some jurisdictions, and favorable public relations. The United States Department of Energy has sponsored several Regional Carbon Sequestration Partnerships (RCSPs) through its Carbon Storage program which have conducted field demonstrations for both EOR and saline aquifer storage. Various research efforts have been made in the area of reservoir characterization, monitoring, verification and accounting, simulation, and risk assessment to ascertain long-term storage potential within the subject storage complex. This book is a collection of lessons learned through the RCSP program within the Southwest Region of the United States. The scope of the book includes site characterization, storage modeling, monitoring verification reporting (MRV), risk assessment and international case studies.

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 2017-04-06 with total page 134 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 Spinning Straw Into Black Gold written by United States. Congress. House. Committee on Natural Resources. Subcommittee on Energy and Mineral Resources and published by . This book was released on 2009 with total page 88 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 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 A Comprehensive Study of CO2 Enhanced Oil Recovery in the Langgak Field written by Dr.-Eng, Muslim and published by UIR Press. This book was released on 2021-04-08 with total page 185 pages. Available in PDF, EPUB and Kindle. Book excerpt: This book is based on the laboratory and field research on Langgak Field, operated by SPR Langgak as one of Province-Owned Oil Company. This book is written to be a guideline and to add knowledge related to enhanced oil recovery (EOR) activity, particularly CO2 Injection. The authors are aware that the information about EOR activity in Indonesia is still limited, so with the presence of this book, we hope it can be made as a reference, not only for students but also for engineers and other researchers who would like to carry out or perform EOR project using CO2 Injection. The authors realize that there are some flaws in the completion of this book. Nonetheless, the authors believe this book will serve as a foundation for other CO2 EOR projects in Indonesia and improve the readers' understanding of CO2 Injection activity. Special thanks are given to the Director of PT. SPR Langgak, Mr Ikin Faizal, who gave us excellent support in the making of this book.

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 CO2 Storage and Enhanced Oil Recovery written by Scott M. Frailey and published by . This book was released on 2012 with total page 196 pages. Available in PDF, EPUB and Kindle. Book excerpt: "The Midwest Geological Sequestration Consortium (MGSC) carried out a small-scale carbon dioxide (CO2) injection test in a sandstone within the Clore Formation (Mississippian System, Chesterian Series) in order to gauge the large-scale CO2 stoage that might be realized from enhanced oil recovery (EOR) of mature Illinois Basin oil fields via miscible liquid CO2 flooding." -- abstract

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 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 Multiphysical Simulation of CO2 Enhanced Oil Recovery in Unconventional Reservoirs written by Shihao Wang and published by . This book was released on 2019 with total page 167 pages. Available in PDF, EPUB and Kindle. Book excerpt: