Download or read book Transient Flow Modelling of Carbon Dioxide CO2 Injection Into Depleted Gas Fields written by Revelation Jacob Samuel and published by . This book was released on 2019 with total page 249 pages. Available in PDF, EPUB and Kindle. Book excerpt: The internationally agreed global climate deal reached at the Paris Climate Conference in 2015 is intended to limit the increase in global average temperatures to "well below" 2°C above pre-industrial levels. This comes in addition to the European Union ambition for 80% to 95% reduction in the 1990 greenhouse gas emissions by 2050 in order to avoid dangerous climate change. Most scenario studies indicate that Carbon Capture and Storage (CCS) is essential for achieving such ambitious reductions. In CCS operations, depleted gas fields represent prime targets for large-scale storage of the captured CO2. Considering the relatively low wellhead pressure of such fields, the uncontrolled injection of the high-pressure dense phase CO2 will result in its rapid, quasi-adiabatic Joule-Thomson expansion leading to significant temperature drops. This could pose several risks, including blockage due to hydrate and ice formation following contact of the cold sub-zero CO2 with the interstitial water around the wellbore and the formation water in the perforations at the near well zone, thermal stress shocking and fracture of the wellbore casing steel and over-pressurisation accompanied by CO2 backflow into the injection system due to the violent evaporation of the superheated liquid CO2 upon entry into the wellbore. In order to minimise the above risks and develop best-practice guidelines for the injection of CO2, the accurate prediction of the CO2 pressure and temperature along the well during the injection process is of paramount importance. This thesis deals with the development and verification of a Homogeneous Equilibrium Mixture (HEM) model and a Homogenous Equilibrium Relaxation Mixture (HERM) model for simulating the transient flow phenomena taking place during the injection of dense phase CO2 into depleted gas fields. The HEM model assumes instantaneous interface mass, momentum and energy exchange between the constituent CO2 liquid and vapour phases. As such they remain at the same pressure, temperature and velocity, whence the corresponding fluid-flow may be described using a single set of mass, momentum and energy conservation equations. The HERM on the other hand presents an additional equation which accounts for the thermodynamic non-equilibrium thorough the introduction of a relaxation time. It also accounts for phase and flow dependent fluid/wall friction and heat transfer, variable well cross sectional area as well as deviation of the well from the vertical. At the well inlet, the opening of the upstream flow regulator valve is modelled as an isenthalpic expansion process; whilst at the well outlet, a formation-specific pressure-mass flow rate correlation is adopted to characterise the storage site injectivity. The testing of the models is based on their application to CO2 injection into the depleted 2582 m deep Goldeneye Gas Reservoir at Hewett field in the North Sea for which the required design and operational data are publically available. Varying injection scenarios involving the rapid (5 mins), medium (30 mins) and slow (2 hrs) linear ramping up of the injected CO2 flow rate to the peak nominal value of 33.5 kg/s are simulated. In each case, the simulated pressure and temperature transients at the top and bottom of the well are used to ascertain the risks of well-bore thermal shocking or interstitial ice formation leading to well blockage due to the rapid cooling of the CO2. Detailed sensitivity analysis of the most important parameters affecting the CO2 in-well flow behaviour, including the wellbore diameter variations, well inclination, upstream temperature, pressure and time variant injection mass flow rate are conducted. The simulation results obtained for a slow (2 hrs) flowrate ramp-up case using the HEM model produce a minimum wellhead temperature of - 11 oC. The corresponding minimum temperature using the HERM model on the other hand is - 21 oC, demonstrating the importance of accounting for non-equilibrium effects and the model"s usefulness as a tool for the development of optimal injection strategies for minimising the risks associated with the injection of CO2 into depleted gas fields.

Download or read book Experimental and Simulation Studies of Sequestration of Supercritical Carbon Dioxide in Depleted Gas Reservoirs written by Jeong Gyu Seo and published by . This book was released on 2004 with total page 238 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Carbon Dioxide Capture and Acid Gas Injection written by Ying Wu and published by John Wiley & Sons. This book was released on 2017-04-19 with total page 266 pages. Available in PDF, EPUB and Kindle. Book excerpt: This is the sixth volume in a series of books on natural gas engineering, focusing carbon dioxide (CO2) capture and acid gas injection. This volume includes information for both upstream and downstream operations, including chapters on well modeling, carbon capture, chemical and thermodynamic models, and much more. Written by some of the most well-known and respected chemical and process engineers working with natural gas today, the chapters in this important volume represent the most cutting-edge and state-of-the-art processes and operations being used in the field. Not available anywhere else, this volume is a must-have for any chemical engineer, chemist, or process engineer working with natural gas. There are updates of new technologies in other related areas of natural gas, in addition to the CO2 capture and acid gas injection, including testing, reservoir simulations, and natural gas hydrate formations. Advances in Natural Gas Engineering is an ongoing series of books meant to form the basis for the working library of any engineer working in natural gas today. Every volume is a must-have for any engineer or library.

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

Download or read book Numerical 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 Science of Carbon Storage in Deep Saline Formations written by Pania Newell and published by Elsevier. This book was released on 2018-09-06 with total page 447 pages. Available in PDF, EPUB and Kindle. Book excerpt: Science of Carbon Storage in Deep Saline Formations: Process Coupling across Time and Spatial Scales summarizes state-of-the-art research, emphasizing how the coupling of physical and chemical processes as subsurface systems re-equilibrate during and after the injection of CO2. In addition, it addresses, in an easy-to-follow way, the lack of knowledge in understanding the coupled processes related to fluid flow, geomechanics and geochemistry over time and spatial scales. The book uniquely highlights process coupling and process interplay across time and spatial scales that are relevant to geological carbon storage. Includes the underlying scientific research, as well as the risks associated with geological carbon storage Covers the topic of geological carbon storage from various disciplines, addressing the multi-scale and multi-physics aspects of geological carbon storage Organized by discipline for ease of navigation

Download or read book Modeling the Fluid Flow of Carbon Dioxide Through Permeable Media written by Rouzbeh Ghanbarnezhad Moghanloo and published by . This book was released on 2012 with total page 710 pages. Available in PDF, EPUB and Kindle. Book excerpt: This dissertation presents analytical solutions to address several unresolved issues on the modeling of CO2 flow in permeable media. Analytical solutions are important as numerical simulations do not yield explicit expressions in terms of the model parameters. In addition, simulations that provide the most comprehensive solutions to multiphase flow problems are computationally intensive. Accordingly, we address the following topics in this dissertation. The method of characteristics (MOC) solution of the overall mass conservation equation of CO2 in two-phase flow through permeable media is derived in the presence of compressibility. The formally developed MOC solutions rely on the incompressible fluid and rock assumptions that are rarely met in practice; hence, the incompressible assumption is relaxed and the first semi-analytic MOC solution for compressible flow is derived. The analytical solution is verified by simulation results. Fractional flow theory is applied to evaluate the CO2 storage capacity of one-dimensional (1D) saline aquifers. Lack of an accurate estimation of the CO2 storage capacity stands in the way of the fully implementation of CO2 storage in aquifers. The notion of optimal solvent-water-slug size is incorporated into the graphical solution of combined geochemical front propagation and fractional flow theory to determine the CO2 storage capacity of aquifers. The analytical solution is verified by simulation results. The limits of the Walsh and Lake (WL) method to predict the performance of CO2 injection is examined when miscibility is not achieved. The idea of an analogous first-contact miscible flood is implemented into the WL method to study miscibly-degraded simultaneous water and gas (SWAG) displacements. The simulation verifies the WL solutions. For the two-dimensional (2D) displacements, the predicted optimal SWAG ratio is accurate when the permeable medium is fairly homogeneous with a small cross-flow or heterogeneous with a large lateral correlation length (the same size or greater than the interwell spacing). We conclude that the WL solution is accurate when the mixing zone grows linearly with time. We examine decoupling of large and small-scale heterogeneity in multilayered reservoirs. In addition, using an analytical solution derived in this research, the fraction of layers in which the channeling occurs is determined as a function of the Koval factor and input dispersivity. We successfully present a simulation configuration to verify the off-diagonal elements of the numerical dispersion tensor. Numerical dispersion is inevitably introduced into the finite difference approximations of the 2D convection-dispersion equation. We show that the off-diagonal elements of the numerical dispersion tensor double when the flow velocity changes with distance. In addition, the simulation results reveal that the flow becomes more dispersive with distance travelled if there is convective cross-flow. In addition, local mixing increases with the convective cross-flow between layers. A numerical indicator is presented to describe the nature of CO2 miscible displacements in heterogeneous permeable media. Hence, the quantitative distinction between flow patterns becomes possible despite the traditionally qualitative approach. The correlation coefficient function is adopted to assign numerical values to flow patterns. The simulation results confirm the accuracy of the descriptive flow pattern values. The order-of-one scaling analysis procedure is implemented to provide a unique set of dimensionless scaling groups of 2D SWAG displacements. The order-of-one scaling analysis is a strong mathematical approach to determine approximations that are allowed for a particular transport phenomenon. For the first time, we implement the scaling analysis of miscible displacements while considering effects of water salinity, dissolution of CO2 in the aqueous phase, and complex configurations of injection and production wells.

Download or read book Surface Process Transportation and Storage written by Qiwei Wang and published by Elsevier. This book was released on 2022-11-03 with total page 555 pages. Available in PDF, EPUB and Kindle. Book excerpt: Petroleum engineers search through endless sources to understand oil and gas chemicals, identify root cause of the problems, and discover solutions while operations are becoming more unconventional and driving toward more sustainable practice. Oil and Gas Chemistry Management Series brings an all-inclusive suite of tools to cover all the sectors of oil and gas chemistry-related issues and chemical solutions from drilling and completion, to production, surface processing, and storage. The fourth reference in the series, Surface Process, Transportation, and Storage delivers the critical basics while also covering latest research developments and practical solutions. Organized by the type of challenges, this volume facilitates engineers to fully understand underlying theories, practical solutions, and keys for successful applications. Basics include produced fluids treating, foam control, pipeline drag reduction, and crude oil and natural gas storage, while more advanced topics cover CO2 recovery, shipment, storage, and utilization. Supported by a list of contributing experts from both academia and industry, this volume brings a necessary reference to bridge petroleum chemistry operations from theory into more cost-effective and sustainable practical applications. Offers full range of oil field chemistry issues and more environmentally friendly alternatives, including chapters focused on methods to treat produced water for recycle, reuse, and disposal Gain effective control on problems and mitigation strategies from industry list of experts and contributors Delivers both up to date research developments and practical applications, bridging between theory and practice

Download or read book Modeling of Co2 Injection in Gas Condensate Reservoirs written by Haval Hawez and published by LAP Lambert Academic Publishing. This book was released on 2015-05-04 with total page 64 pages. Available in PDF, EPUB and Kindle. Book excerpt: Gas condensate reservoir has been demonstrated as a highly complex phase and flow properties as a result of the appearance of condensate blockage near the well-bore region. This challenge can cause a significant reduction of well productivity and even seized due to decrease in pressure around the well-bore. The reduction in the reservoir pressure could be treated by shutting in the well for a period in order to build-up the reservoir pressure. Likewise, injection fluids are preferably used to maintain the reservoir pressure above dew point to avoid retrograde condensation which can result in condensate blockage. An accurate prediction should be made to achieve informed and resourceful decisions of reservoir management and sustain well productivity. In this report, the improved productivity of hydrocarbon and maintaining the reservoir pressure of a gas condensate reservoir under water, carbon dioxide and water followed by CO2 injections were studied using ECLIPSE 300 compositional reservoir simulator for 1D, 2D and 3D models.

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 Fossil Energy Update written by and published by . This book was released on 1984 with total page 1126 pages. Available in PDF, EPUB and Kindle. Book excerpt:

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 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 Target Reservoirs for CO2 Miscible Flooding written by John H. Goodrich and published by . This book was released on 1980 with total page 406 pages. Available in PDF, EPUB and Kindle. Book excerpt:

Download or read book Advances in Carbon Dioxide Compression and Pipeline Transportation Processes written by Andrzej Witkowski and published by Springer. This book was released on 2015-05-25 with total page 141 pages. Available in PDF, EPUB and Kindle. Book excerpt: Providing a comprehensive analysis of CO2 compression, transportation processes and safety issues for post combustion CO2 capture applications for a 900 MW pulverized hard coal-fired power plant, this book assesses techniques for boosting the pressure of CO2 to pipeline pressure values with a minimal amount of energy. Four different types of compressors are examined in detail: a conventional multistage centrifugal compressor, integrally geared centrifugal compressor, supersonic shock wave compressor, and pump machines. The study demonstrates that the total compression power is closely related to the thermodynamic process and is not determined by compressor efficiency alone. Another problem addressed is that of CO2 pipeline transport from the compressor outlet site to a disposal site under heat transfer conditions. The book also features an analysis of simulations and models that are used to determine the maximum safe pipeline distance to subsequent booster stations as a function of inlet pressure, ambient temperature, thickness of the thermal insulation and ground-level heat flux conditions. This book focuses on compression as well as transportation processes with particular emphasis on the safety risks related to the transport of CO2. The most important problem in terms of environmental protection is ensuring precise and reliable hazard identification. As hazards can only be managed effectively if they are properly identified, problems involving the discharge and atmospheric dispersion of CO2 are also discussed.