CO2 Injection in the Network of Carbonate Fractures PDF Download
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Author: J. Carlos de Dios
Publisher: Springer Nature
ISBN: 3030629864
Category : Technology & Engineering
Languages : en
Pages : 245
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Book Description
This book presents guidelines for the design, operation and monitoring of CO2 injection in fractured carbonates, with low permeability in the rock matrix, for geological storage in permanent trapping. CO2 migration is dominated by fractures in formations where the hydrodynamic and geochemical effects induced by the injection play a key role influencing the reservoir behavior. CO2 injection in these rocks shows specific characteristics that are different to injection in porous media, as the results from several research studies worldwide reveal. All aspects of a project of this type are discussed in this text, from the drilling to the injection, as well as support works like well logging, laboratory and field tests, modeling, and risk assessment. Examples are provided, lesson learned is detailed, and conclusions are drawn. This work is derived from the experience of international research teams and particularly from that gained during the design, construction and operation of Hontomín Technology Development Plant. Hontomín research pilot is currently the only active onshore injection site in the European Union, operated by Fundación Ciudad de la Energía-CIUDEN F.S.P. and recognized by the European Parliament as a key test facility. The authors provide guidelines and tools to enable readers to find solutions to their problems. The book covers activities relevant to a wide range of practitioners involved in reservoir exploration, modeling, site operation and monitoring. Fluid injection in fractured media shows specific features that are different than injection in porous media, influencing the reservoir behavior and defining conditions for safe and efficient operation. Therefore, this book is also useful to professionals working on oil & gas, hydrogeology and geothermal projects, and in general for those whose work is related to activities using fluid injection in the ground.
Author: J. Carlos de Dios
Publisher: Springer Nature
ISBN: 3030629864
Category : Technology & Engineering
Languages : en
Pages : 245
Get Book Here
Book Description
This book presents guidelines for the design, operation and monitoring of CO2 injection in fractured carbonates, with low permeability in the rock matrix, for geological storage in permanent trapping. CO2 migration is dominated by fractures in formations where the hydrodynamic and geochemical effects induced by the injection play a key role influencing the reservoir behavior. CO2 injection in these rocks shows specific characteristics that are different to injection in porous media, as the results from several research studies worldwide reveal. All aspects of a project of this type are discussed in this text, from the drilling to the injection, as well as support works like well logging, laboratory and field tests, modeling, and risk assessment. Examples are provided, lesson learned is detailed, and conclusions are drawn. This work is derived from the experience of international research teams and particularly from that gained during the design, construction and operation of Hontomín Technology Development Plant. Hontomín research pilot is currently the only active onshore injection site in the European Union, operated by Fundación Ciudad de la Energía-CIUDEN F.S.P. and recognized by the European Parliament as a key test facility. The authors provide guidelines and tools to enable readers to find solutions to their problems. The book covers activities relevant to a wide range of practitioners involved in reservoir exploration, modeling, site operation and monitoring. Fluid injection in fractured media shows specific features that are different than injection in porous media, influencing the reservoir behavior and defining conditions for safe and efficient operation. Therefore, this book is also useful to professionals working on oil & gas, hydrogeology and geothermal projects, and in general for those whose work is related to activities using fluid injection in the ground.
Author: Hassan Hamam
Publisher:
ISBN:
Category :
Languages : en
Pages :
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Book Description
More than 60% of the original oil in place (OOIP) is left in the ground after the primary and secondary recovery processes. With the introduction of enhanced oil recovery (EOR), that number goes down to about 40% of the OOIP. Carbon dioxide (CO2) injection is one of the most effective EOR methods in naturally fractured reservoirs. The fracture network provides a faster means for fluid flow due to its high conductivity but it is also the cause of premature breakthrough of the injected fluids. However, if employed efficiently, fractures can help push the injected CO2 to the reservoir boundaries so that a large portion of the reservoir fluid interacts with the injected CO2. Zones swept by miscible CO2 reported the lowest residual oil saturation.Continuous CO2 injection is becoming more and more preferred to the popular cyclic pressure pulsing. Continuous CO2 injection has no down time and could potentially provide better CO2 interaction with the reservoir fluid which provides a higher recovery. In this research, artificial neural networks (ANNs) are used to construct robust proxy models with highly predictive capabilities for naturally fractured reservoirs undergoing continuous CO2 injection. The main purpose of this research is to shed more light and understanding on continuous CO2 injection in naturally fractured reservoirs and provide a tool that empowers engineers to make decisions on the fly while evaluating uncertainty and mitigating risk rather than wait months or years to do so. In light of the above, various ANN designs and configurations undergo development and evolution to ultimately be able to provide valuable insights regarding reservoir performance, history matching, and injection design for naturally fractured reservoirs undergoing CO2 injection. Initial ANN designs targeted specific reservoirs using specific fluid compositions from the literature. The designed ANNs were able to provide predictions with a low degree of error. ANN designs went over many complex adjustments, variations, and enhancements until final configurations were reached. The final ANN designs developed in this research surpass previously developed ANNs in similar projects with its capability to handle a huge range of reservoir properties, relative permeability, capillary pressure, and fluid compositions under uncertainty.The reservoir simulation model used in this research is a two-well, two-layer, miscible compositional simulation model working in a dual-porosity system. Critical parameters affected the accuracy and predictability of the ANN designs and they were an essential part of the final ANN configurations. The parameters that a major effect on continuous CO2 injection are reservoir fluid composition, fracture permeability, well spacing, bottomhole flowing pressure (BHFP), thickness, and CO2 injection amount under miscible conditions had the highest impact on recovered oil.The final ANN designs were encompassed inside a graphical user interface that equipped the ANN with uncertainty evaluation capabilities. The ease to use nature of the GUI allows anyone to use the developed ANNs in this research, as well as provide a simple intuitive interface to manipulate input data, run simultaneous sensitivity and uncertainty analysis. The developed ANNs in this research bring us a step closer to achieving real-time simulation for naturally fractured reservoirs undergoing CO2 injection. The correlations embedded in the ANNs were able to overcome reservoir fluid, relative permeability, and capillary pressure limitations that existed in the previous ANN studies.
Author: Zhiyuan Luo
Publisher:
ISBN:
Category :
Languages : en
Pages : 358
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Book Description
Large-scale geologic CO2 storage is a technically feasible way to reduce anthropogenic emission of green house gas to atmosphere by human beings. In large-scale geologic CO2 sequestration, high injection rate is required to satisfy economics and operational considerations. During the injection phase, temperature and pressure of the storage aquifers may vary significantly with the introduced CO2. These changes would re-distribute the in-situ stresses in formations and induce fracture initiation or even propagation. If fractures are not permitted by regulators, then the injection operation strategies must be supervised and designed to prevent fracture initiation, and the storage formations should be screened for risk of fracturing. In more flexible regulatory environment, if fractures are allowed, fractures would strongly influence the CO2 migration profile and storage site usage efficiency depending on fracture length and growth rate. In this dissertation, we built analytical heat transfer models for vertical and horizontal injection wells. The models account for the dependency of overall heat transfer coefficient on injection rate to more accurately predict the borehole temperature. Based on these models, we can calculate temperature change in formation surrounding wellbores and thus evaluate thermo-elastic stress around borehole as well as its impact on fracture initiation pressure. By considering the impact of thermo-elastic effect on fracturing pressure, we predicted maximum injection rate avoiding fracture initiation and provided injection and storage strategies to increase the maximum safe injection rate. The results show that thermo-elastic stress significantly limits maximum injection rate for no-fractured injection scenario, especially for horizontal injectors. To improve injection rate, partial perforation and pre-heating CO2 before injection have been designed, and results shows that these strategies can strongly negate thermo-elastic influence for various injection scenarios. On the other hand, the model provides parametric analysis on geological and operational conditions of CO2 storage project for site screening work. In the case of permitting fracture occurrence, a semi-analytical model was built to quantitatively describe fracture propagation and injected fluid migration profile of a fractured vertical injector for storage systems with various boundary conditions. We examined the correlation between fracture growth and CO2 migration in various injection scenarios. Two-phase fractional flow model of Buckley-Leverett theory has been extended to account for the CO2-brine three-region flow system (dry CO2, CO2-brine, and brine) from a fractured injector. In the sensitivity study, fracture growth and fluid migration greatly depend on Young's modulus of the formation rock and storage site boundary conditions. Consequently, the results show that fast growing, long fractures may yield a flooding pattern with large aspect ratio, as well as early breakthrough at the drainage boundary; in contrast, slow growing short fractures provides high injectivity without changing flooded area shape. We studied the physics for issues related to injection induced fractures in geologic CO2 sequestration in saline aquifers, assessed risk associated to them and developed low cost and quick analytical models. These models could easily provide predictions on maximum injection rate in no-fracture regulation CO2 storage projects as well as estimate fracture growth and injected fluid migration under fracture allowable scenarios. "Preferred storage aquifers" have following properties: larger permeability, deep formation, no over pressure, low Young's modulus and low Poisson's ratio and open boundaries. In many practical cases, however, injection strategies have to be designed if some properties of formation are out of ideal range. Besides applications in CO2 storage, the approach and model we developed can also be applied into any injection induced fracture topics, namely water/CO2 flooding and wasted water re-injection.
Author: Alice Wu
Publisher: John Wiley & Sons
ISBN: 1119592062
Category : Science
Languages : en
Pages : 384
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Book Description
This is the eighth volume in the series, Advances in Natural Gas Engineering, focusing on gas injection into geological formations and other related topics, very important areas of natural gas engineering. This volume includes information for both upstream and downstream operations, including chapters detailing the most cutting-edge techniques in acid gas injection, 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 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 in the industry. 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.
Author: Hang Zhang
Publisher:
ISBN:
Category :
Languages : en
Pages : 140
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Book Description
This work investigates the performance of CO2 soluble surfactants used for CO2 foam flooding in fractured carbonate reservoirs. Oil recovery associated with the reduction of CO2 mobility in fractures is assessed by monitoring oil saturation and pressure drops during injection of CO2 with aqueous surfactant solution in artificially fractured carbonate cores. Distinct novel CO2 soluble surfactants are evaluated as well as a conventional surfactant. Water flooding and pure CO2 injection are conducted as baseline. Characterization of fluids and rock are also reported which include Amott test, oil phase behavior and slim tube test. Transport and thermodynamic properties of surfactant and supercritical CO2 are used to evaluate the process on a core scale using a commercial reservoir simulator.
Author: M. Rafiqul Islam
Publisher: Elsevier
ISBN: 0128005947
Category : Technology & Engineering
Languages : en
Pages : 633
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Book Description
Natural gas, especially unconventional gas, has an increasingly important role in meeting the world's energy needs. Experts estimate that it has the potential to add anywhere from 60-250% to the global proven gas reserve in the next two decades. To maintain pace with increasing global demand, Unconventional Gas Reservoirs provides the necessary bridge into the newer processes, approaches and designs to help identify these more uncommon reservoirs available and how to maximize its unconventional potential. Loaded with reservoir development and characterization strategies, this book will show you how to: Recognize the challenges and opportunities surrounding unconventional gas reservoirs Distinguish among the various types of unconventional reservoirs, such as shale gas, coalbed methane, and tight gas formations Drill down and quantify the reservoir’s economic potential and other critical considerations Gain practical insights and tools to efficiently identify, appraise, and develop unconventional gas reservoirs Understand various techniques used to analyze reservoir parameters and performance as well as how they were applied to numerous real-world case studies Upgrade to the latest information on perspectives and insights with discussion of key differences used for today’s unconventional gas characterization versus original conventional methods that failed in the past
Author: Minh C. Nguyen
Publisher:
ISBN:
Category : Carbon sequestration
Languages : en
Pages : 164
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Book Description
The first study phase presents a science-based methodology for quantifying risk profiles at GCS sites as part of the US Department of Energy’s National Risk Assessment Partnership. The NRAP Integrated Assessment Model-Carbon Storage is implemented to a field scale project in a fractured saline aquifer located at Kevin Dome, Montana. Using NRAP-IAM-CS, the first phase finds that the potential amount of CO2 leakage is most sensitive to values of the target reservoir fracture permeability, fracture and matrix end-point CO2 relative permeability, hysteresis of CO2 relative permeability, capillary pressure, and permeability of confining rocks. Moreover, results estimate very low risk of CO2 leakage to the atmosphere unless the quality of the legacy well completions is extremely poor. In the second phase, an investigation of formation damage due to acidization and brine injection tests into the Middle Duperow Formation. The findings of the second phase of this study include: (1) well test analytical models indicate a positive total skin factor, i.e., permeability decline at the brine injection well, thus contradicting results of a previous study; (2) there are two possible scenarios that could lead to the interpreted positive total effective skin factor: partial penetration of the injection well screen and formation damage; (3) by matching the pressure buildup observed during three brine injection tests, numerical simulation results support the formation damage hypothesis; and (4) the formation damage could be explained by mechanical and chemical processes during brine injection that could clog the matrix/fracture system, for example, anhydrite fines migration and/or calcite precipitation.
Author: Wenlong Ding
Publisher: Frontiers Media SA
ISBN: 2832514855
Category : Science
Languages : en
Pages : 348
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Book Description
Author:
Publisher:
ISBN:
Category :
Languages : en
Pages :
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Book Description
The objective of this project is to perform unique laboratory experiments with artificial fractured cores (AFCs) and X-ray CT to examine the physical mechanisms of bypassing in HFR and NFR that eventually result in more efficient CO2 flooding in heterogeneous or fracture-dominated reservoirs. To achieve this objective, we divided the report into two chapters. The first chapter was to image and perform experimental investigation of transfer mechanisms during CO2 flooding in NFR and HFR using X-ray CT scanner. In this chapter, we emphasized our work on understanding the connection between fracture properties and fundamentals of transfer mechanism from matrix to fractures and fluid flow through fracture systems. We started our work by investigating the effect of different overburden pressures and stress-state conditions on rock properties and fluid flow. Since the fracture aperture is one of important parameter that governs the fluid flow through the fracture systems, the average fracture aperture from the fluid flow experiments and fracture aperture distribution derived from X-ray CT scan were estimated for our modeling purposes. The fracture properties and fluid flow have significant changes in response to different overburden pressures and stress-state conditions. The fracture aperture distribution follows lognormal distribution even at elevated stress conditions. Later, we also investigated the fluid transfers between matrix and fracture that control imbibition process. We evaluated dimensionless time for validating the scheme of upscaling laboratory experiments to field dimensions. In CO2 injection experiments, the use of X-ray CT has allowed us to understand the mechanisms of CO2 flooding process in fractured system and to take important steps in reducing oil bypassed. When CO2 flooding experiments were performed on a short core with a fracture at the center of the core, the gravity plays an important role in the recovery of oil even in a short matrix block. This results are contrary with the previous believes that gravity drainage has always been associated with tall matrix blocks. In order to reduce oil bypassed, we injected water that has been viscosified with a polymer into the fracture to divert CO2 flow into matrix and delay CO2 breakthrough. Although the breakthrough time reduced considerably, water ''leak off'' into the matrix was very high. A cross-linked gel was used in the fracture to avoid this problem. The gel was found to overcome ''leak off'' problems and effectively divert CO2 flow into the matrix. As part of our technology transfer activity, we investigated the natural fracture aperture distribution of Tensleep formation cores. We found that the measured apertures distributions follow log normal distribution as expected. The second chapter deals with analysis and modeling the laboratory experiments and fluid flow through fractured networks. We derived a new equation to determine the average fracture aperture and the amount of each flow through fracture and matrix system. The results of this study were used as the observed data and for validating the simulation model. The idea behind this study is to validate the use of a set of smooth parallel plates that is common in modeling fracture system. The results suggest that fracture apertures need to be distributed to accurately model the experimental results. In order to study the imbibition process in details, we developed imbibition simulator. We validated our model with X-ray CT experimental data from different imbibition experiments. We found that the proper simulation model requires matching both weight gain and CT water saturation simultaneously as oppose to common practices in matching imbibition process with weight gain only because of lack information from CT scan. The work was continued by developing dual porosity simulation using empirical transfer function (ETF) derived from imbibition experiments. This allows reduction of uncertainty parameter in modeling transfer of fluids from matrix to the fracture. The application of ETF approach not only reduces the computation times but also shows similar results when compared to the results from existing dual porosity simulator. During the development of our numerical modeling, we found that the grid orientation effect (GOE) is major problem plaguing reservoir simulators that employ finite difference schemes. The GOE is clearly seen when using conventional Cartesian grid blocks during CO2 flooding or unfavorable mobility ratio presence in the simulation model. We developed hybrid grid block (HGB) to reduce this effect. Using this grid block, the simulation is able to reduce the GOE even for unfavorable mobility ratio. The last chapter discusses a modeling approach to reduce oil bypassed in CO2 flood pattern.
Author: Augustine O. Ayeni
Publisher: Springer Nature
ISBN: 3030967212
Category : Technology & Engineering
Languages : en
Pages : 393
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Book Description
This book presents novel techniques, current trends, and cutting-edge technologies in energy and biochemical processes. The authors explore recent advances that solve challenges related to the implications and commercialization of these processes by introducing new techniques or modifying existing technologies to meet future demands for food materials, bioproducts, fossil fuels, biofuels, and bioenergy. Divided into three parts, the first section of the book addresses issues related to the utilization and management of energy towards the efficient characterization and conversion of wastes or raw-/bio- materials to useful products. The second section focuses largely on studies on molecular detection of analytes, purification, and characterization of products recovered from biochemical, enzymatic, food, and phytochemicals, as well as biostimulation and bioaugmentation processes. The final section discusses areas related to heat and mass transfer, fuel processing technologies, nanofluids, and their applications.
