Download or read book Investigation of Waterflood Improvement for Heavy Oil Carbonate Reservoirs crude Oil brine rock Interactions written by Heron Gachuz Muro 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 Laboratory Investigation of Mechanisms Governing Low salinity Waterflooding in Oil wet Carbonate Reservoirs written by Gregory Kojadinovich and published by . This book was released on 2018 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: Improved oil recovery via wettability alteration by tuning the ionic composition of the injection water has been thoroughly researched in recent years. It has been well documented that seawater can increase the water wetness of chalk at high temperature. Forced displacement and spontaneous imbibition experiments have attributed the wettability alteration to interactions between active ions in the brine, Ca2+, Mg2+, and SO42-, the rock surface, and the oil phase. It has been suggested that the adsorption of SO42- onto the rock surface causes the bond between adsorbed carboxylic material in the crude oil and the rock surface to deteriorate which causes the release of the crude oil. Reduction in ionic strength of the injection water has also been proposed to trigger the effect of wettability alteration in carbonates. Although the numerous experiments devoted to understanding the mechanisms governing the low salinity effect in the past two decades, there has been no consensus about the dominant mechanisms driving wettability alteration. The purpose of this research is to improve the understanding of how reduced ionic strength and potentially determining ions (PDIs) contribute to oil recovery, as well as provide a direct comparison of their oil recovery performance for a synthetic oil versus crude oil during waterflooding. For this, a series of waterflood experiments were conducted in the laboratory at 90 C in Indiana limestone core plugs. Chemically tuned brines derived from seawater were used in secondary and tertiary recovery modes to displace synthetic oil. A waterflood with formation brine was also conducted as an experimental baseline to assess the advantages of low-salinity waterflooding over typical secondary recovery methods. Effluent analysis was conducted to evaluate the surface interactions occurring between the brine and rock surface. Gas chromatography-mass spectroscopy was performed to compare the chemical make-up of the synthetic and crude oil. Oil recovery curves from this study indicate that there was no benefit afterincreasing the concentration of PDIs in injection water compared to seawater (SW). However, the use of seawater and all chemically tuned brines derived from seawater resulted in an average 6.47% increase in oil recovery post water breakthrough, relative to the formation brine waterflood. The success of wettability alteration leading to improved oil recovery in carbonates has been noted as a strong function of the oil composition.

Download or read book Improved Oil Recovery by Sequential Waterflooding and by Injection of Low Salinity Brine written by Nina Loahardjo and published by . This book was released on 2009 with total page 331 pages. Available in PDF, EPUB and Kindle. Book excerpt: Waterflooding is by far the most commonly applied method of increasing oil recovery over that given by primary production. Reservoir wettability has been shown to be a key factor in determining the microscopic displacement efficiency in the swept regions of a waterflood. Reservoir wettability depends on complex crude oil/brine/rock (COBR) interactions. Numerous laboratory investigations and a growing number of pilot field studies show that oil recovery can be improved by injection of low salinity brine. This thesis includes study of the effect of low salinity flooding on oil recovery for selected reservoirs. Observations on the reproducibility of oil recovery behavior led to development of a new approach to improved oil recovery based on repeated waterflooding without change in brine composition. Laboratory studies indicated that the presence of the crude/oil interface was essential to oil recovery by sequential waterflooding. Crude properties have been measured for 27 crude oils. The oils were characterized according to density, viscosity, refractive index, surface tension, acid and base numbers, composition and vapor pressure. The effects of pH and salinity on interfacial tension were determined for a wide range of crude oils derived from both sandstone and carbonate reservoirs. A large majority of the oils exhibited low interfacial tensions at both low and high pH. For the selected COBR reservoir combinations, increase in oil recovery by low salinity waterflooding was often, but not always observed. The cost of recovering cores from a reservoir is very high. Furthermore, reservoir heterogeneity often limits the number of core samples that can be used in duplicate experiments. After testing, reservoir cores were therefore cleaned and reused. For a core that showed large response to reduction in injection brine salinity, it was found that the initial recovery, first measured for seawater, could not be reproduced, with recovery still being close to that given by the brine of lowest salinity. As a test of reproducibility, cores that had been waterflooded with high salinity brine were taken back to initial water saturation by oil flooding and re-flooded without change in the injection brine composition. For 15 out of 18 tests that included both sandstone and limestone, residual oil saturation decreased from one flood to the next. Reductions in residual oil saturation were not observed for recovery of refined oil. Material balances for sequential flooding were checked against Dean-Stark extraction and by tracer tests. The overall trend of reduction in residual oil saturation was confirmed by MRI imaging of changes in saturation distribution during sequential floods. Further investigation of this new approach to tertiary recovery is proposed through relatively low-cost single-well field tests.

Download or read book LABORATORY INVESTIGATION OF OIL COMPOSITION AFFECTING THE SUCCESS OF LOW SALINITY WATERFLOODING IN OIL WET CARBONATE ROCKS written by Gregory Kojadinovich and published by . This book was released on 2018 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: Improved oil recovery via wettability alteration by tuning the ionic composition of the injection water has been thoroughly researched in recent years. It has been well documented that seawater can increase the water wetness of chalk at high temperature. Forced displacement and spontaneous imbibition experiments have attributed the wettability alteration to interactions between active ions in the brine, Ca2+, Mg2+, and SO42-, the rock surface, and the oil phase. It has been suggested that the adsorption of SO42- onto the rock surface causes the bond between adsorbed carboxylic material in the crude oil and the rock surface to deteriorate which causes the release of the crude oil. Reduction in ionic strength of the injection water has also been proposed to trigger the effect of wettability alteration in carbonates. Although the numerous experiments devoted to understanding the mechanisms governing the low salinity effect in the past two decades, there has been no consensus about the dominant mechanisms driving wettability alteration. The purpose of this research is to improve the understanding of how reduced ionic strength and potentially determining ions (PDIs) contribute to oil recovery, as well as provide a direct comparison of their oil recovery performance for a synthetic oil versus crude oil during waterflooding. For this, a series of waterflood experiments were conducted in the laboratory at 90 C in Indiana limestone core plugs. Chemically tuned brines derived from seawater were used in secondary and tertiary recovery modes to displace synthetic oil. A waterflood with formation brine was also conducted as an experimental baseline to assess the advantages of low-salinity waterflooding over typical secondary recovery methods. Effluent analysis was conducted to evaluate the surface interactions occurring between the brine and rock surface. Gas chromatography-mass spectroscopy was performed to compare the chemical make-up of the synthetic and crude oil. Oil recovery curves from this study indicate that there was no benefit after increasing the concentration of PDIs in injection water compared to seawater (SW). However, the use of seawater and all chemically tuned brines derived from seawater resulted in an average 6.47% increase in oil recovery post water breakthrough, relative to the formation brine waterflood. The success of wettability alteration leading to improved oil recovery in carbonates has been noted as a strong function of the oil composition.

Download or read book Waterflooding written by G. Paul Willhite and published by . This book was released on 1986 with total page 358 pages. Available in PDF, EPUB and Kindle. Book excerpt: Waterflooding begins with understanding the basic principles of immiscible displacement, then presents a systematic procedure for designing a waterflood.

Download or read book Low Salinity and Engineered Water Injection for Sandstone and Carbonate Reservoirs written by Emad Walid Al Shalabi and published by Gulf Professional Publishing. This book was released on 2017-06-14 with total page 179 pages. Available in PDF, EPUB and Kindle. Book excerpt: Low Salinity and Engineered Water Injection for Sandstone and Carbonate Reservoirs provides a first of its kind review of the low salinity and engineered water injection (LSWI/EWI) techniques for today's more complex enhanced oil recovery methods. Reservoir engineers today are challenged in the design and physical mechanisms behind low salinity injection projects, and to date, the research is currently only located in numerous journal locations. This reference helps readers overcome these challenging issues with explanations on models, experiments, mechanism analysis, and field applications involved in low salinity and engineered water. Covering significant laboratory, numerical, and field studies, lessons learned are also highlighted along with key areas for future research in this fast-growing area of the oil and gas industry. After an introduction to its techniques, the initial chapters review the main experimental findings and explore the mechanisms behind the impact of LSWI/EWI on oil recovery. The book then moves on to the critical area of modeling and simulation, discusses the geochemistry of LSWI/EWI processes, and applications of LSWI/EWI techniques in the field, including the authors' own recommendations based on their extensive experience. It is an essential reference for professional reservoir and field engineers, researchers and students working on LSWI/EWI and seeking to apply these methods for increased oil recovery. - Teaches users how to understand the various mechanisms contributing to incremental oil recovery using low salinity and engineering water injection (LSWI/EWI) in sandstones and carbonates - Balances guidance between designing laboratory experiments, to applying the LSWI/EWI techniques at both pilot-scale and full-field-scale for real-world operations - Presents state-of-the-art approaches to simulation and modeling of LSWI/EWI

Download or read book Conventional and Carbonated Water Flooding in Heavy Oil Systems written by Tayebeh Jamshidi and published by . This book was released on 2018 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: Despite the severe viscosity contrast and low displacement efficiency in heavy oil reservoirs, conventional waterflooding is still considered as one of the feasible recovery processes for such reservoirs. On the other hand, conventional waterflooding has been well studied and has been suggested for light oil reservoirs. However, viability of carbonated waterflooding for heavy oil reservoir and impact of operational parameters, reservoir characteristics, and fluid properties on the performance of this technique are yet to be fully understood. In this study, the performances of conventional and carbonated waterflooding in heavy oil reservoirs were analyzed through various micromodel and coreflooding experiments. Prior to the main tests, a series of experiments were performed to investigate the effect of various parameters such as temperature, pressure, and oil API gravity on the fluid interactions in the binary systems of brine-CO2 and oil-CO2. The solubility of carbon dioxide in 20,000 ppm brine solution was measured at various experimental conditions and compared with previous studies. Furthermore, the solubility of CO2 in oil and the swelling factor for two heavy oils (Type-I, oAPI=20.44 and Type-II, oAPI=15.49) were experimentally measured at various conditions. In this regard, CO2 solubility was measured to be 10.13 and 5.72 (gr CO2/100 gr oil) in Type-I crude oil when temperature increased from T=21oC to 45oC at the constant pressure of Pexp=3.44 MPa. When pressure increased from Pexp=1.38 MPa to 3.44 MPa at the constant temperature of T=21oC, solubility of CO2 in Type-II crude oil was increased from 2.37 to 7.84 (gr CO2/100 gr oil). A reduction in oil API gravity had adverse effect on the CO2 solubility. For example, at the temperature of T=21oC and Pressure of Pexp=3.44 MPa, CO2 solubility decreased from about 10.13 (g CO2/100 gr in oil) Type-I to 7.84 (gr CO2/100 gr ii oil) in oil Type-II. Measured values of swelling factor showed that Type-I and Type-II crude oils could swell to the maximum of 1.079 and 1.052 times of their initial volume at the temperature of T=21oC and Pressure of Pexp=3.44 MPa. Effect of key parameters such as injection rate, temperature, oil API gravity and extreme heterogeneity on the performance of both conventional and carbonated waterflooding in heavy oil systems were extensively studied through series of experiments. Results of conventional waterflooding conducted with 1.6 PVs of injected water in the single permeability porous media showed ultimate recovery factors of 48%, 62% and 53.7% for water injection rates of qinj=0.025, 0.05, and 0.075 (cm3/min), respectively. Increasing the temperature from Texp=21oC to 30oC and 45oC improved the ultimate recovery factor of conventional waterflooding in single permeability porous media from 61% to 69.3% and 73%, respectively. These values were achieved at nearly 1.6 PVs of injected water. Analysis of the experimental results at qinj=0.05 (cm3/min) and Texp=21oC revealed an improvement of 2.44% in ultimate recovery factor when oil API gravity increased from oAPI=15.49 to 20.44. Results of this study showed that carbonated waterflooding (CWF) could improve the ultimate recovery factor by 24% compared to WF. Conventional and carbonated waterflooding tests conducted in a sand-packed model revealed that injection at higher carbonation pressure of 3.1 MPa results in 16.5% additional recovery factor in type-I heavy oil compared to heavier oil of type-II. Among API gravity, carbonation pressure, temperature and injection rate, it was found that the key success for CWF is oil API gravity and carbonation pressure.

Download or read book Enhanced Oil Recovery Field Case Studies written by James J.Sheng and published by Gulf Professional Publishing. This book was released on 2013-04-10 with total page 710 pages. Available in PDF, EPUB and Kindle. Book excerpt: Enhanced Oil Recovery Field Case Studies bridges the gap between theory and practice in a range of real-world EOR settings. Areas covered include steam and polymer flooding, use of foam, in situ combustion, microorganisms, "smart water"-based EOR in carbonates and sandstones, and many more. Oil industry professionals know that the key to a successful enhanced oil recovery project lies in anticipating the differences between plans and the realities found in the field. This book aids that effort, providing valuable case studies from more than 250 EOR pilot and field applications in a variety of oil fields. The case studies cover practical problems, underlying theoretical and modeling methods, operational parameters, solutions and sensitivity studies, and performance optimization strategies, benefitting academicians and oil company practitioners alike. - Strikes an ideal balance between theory and practice - Focuses on practical problems, underlying theoretical and modeling methods, and operational parameters - Designed for technical professionals, covering the fundamental as well as the advanced aspects of EOR

Download or read book Improved Water Flooding Through Injection Brine Modification written by Charles Phillip Thomas and published by . This book was released on 2003 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: Crude oil/brine/rock interactions can lead to large variations in thedisplacement efficiency of waterflooding, by far the most widely applied methodof improved oil recovery. Laboratory waterflood tests show that injection ofdilute brine can increase oil recovery. Numerous fields in the Powder Riverbasin have been waterflooded using low salinity brine (about 500 ppm) from theMadison limestone or Fox Hills sandstone. Although many uncertainties arise inthe interpretation and comparison of field production data, injection of lowsalinity brine appears to give higher recovery compared to brine of moderatesalinity (about 7,000 ppm). Laboratory studies of the effect of brine compositionon oil recovery cover a wide range of rock types and crude oils. Oil recoveryincreases using low salinity brine as the injection water ranged from a low of nonotable increase to as much as 37.0% depending on the system being studied. Recovery increases using low salinity brine after establishing residual oilsaturation (tertiary mode) ranged from no significant increase to 6.0%. Testswith two sets of reservoir cores and crude oil indicated slight improvement inrecovery for low salinity brine. Crude oil type and rock type (particularly thepresence and distribution of kaolinite) both play a dominant role in the effect thatbrine composition has on waterflood oil recovery.

Download or read book Wettability and Oil Recovery by Imbibition and Viscous Displacement from Fractured and Heterogeneous Carbonates written by Jill Buckley and published by . This book was released on 2006 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: About one-half of U.S. oil reserves are held in carbonate formations. The remaining oil in carbonate reservoirs is regarded as the major domestic target for improved oil recovery. Carbonate reservoirs are often fractured and have great complexity even at the core scale. Formation evaluation and prediction is often subject to great uncertainty. This study addresses quantification of crude oil/brine/rock interactions and the impact of reservoir heterogeneity on oil recovery by spontaneous imbibition and viscous displacement from pore to field scale. Wettability-alteration characteristics of crude oils were measured at calcite and dolomite surfaces and related to the properties of the crude oils through asphaltene content, acid and base numbers, and refractive index. Oil recovery was investigated for a selection of limestones and dolomites that cover over three orders of magnitude in permeability and a factor of four variation in porosity. Wettability control was achieved by adsorption from crude oils obtained from producing carbonate reservoirs. The induced wettability states were compared with those measured for reservoir cores. The prepared cores were used to investigate oil recovery by spontaneous imbibition and viscous displacement. The results of imbibition tests were used in wettability characterization and to develop mass transfer functions for application in reservoir simulation of fractured carbonates. Studies of viscous displacement in carbonates focused on the unexpected but repeatedly observed sensitivity of oil recovery to injection rate. The main variables were pore structure, mobility ratio, and wettability. The potential for improved oil recovery from rate-sensitive carbonate reservoirs by increased injection pressure, increased injectivity, decreased well spacing or reduction of interfacial tension was evaluated.

Download or read book A Mechanism of Improved Oil Recovery by Low Salinity Waterflooding in Sandstone Rock written by Ramez Masoud Azmy Nasralla and published by . This book was released on 2013 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: Injection of low-salinity water showed high potentials in improving oil recovery when compared to high-salinity water. However, the optimum water salinity and conditions are uncertain, due to the lack of understanding the mechanisms of fluid-rock interactions. The main objective of this study is to examine the potential and efficiency of low-salinity water in secondary and tertiary oil recovery for sandstone reservoirs. Similarly, this study aims to help in understanding the dominant mechanisms that aid in improving oil recovery by low-salinity waterflooding. Furthermore, the impact of cation type in injected brines on oil recovery was investigated. Coreflood experiments were conducted to determine the effect of water salinity and chemistry on oil recovery in the secondary and tertiary modes. The contact angle technique was used to study the impact of water salinity and composition on rock wettability. Moreover, the zeta potential at oil/brine and brine/rock interfaces was measured to explain the mechanism causing rock wettability alteration and improving oil recovery. Deionized water and different brines (from 500 to 174,000 mg/l), as well as single cation solutions were tested. Two types of crude oil with different properties and composition were used. Berea sandstone cores were utilized in the coreflood experiments. Coreflood tests indicated that injection of deionized water in the secondary mode resulted in significant oil recovery, up to 22% improvement, compared to seawater flooding. However, no more oil was recovered in the tertiary mode. In addition, injection of NaCl solution increased the oil recovery compared to injection of CaCl2 or MgCl2 at the same concentration. Contact angle results demonstrated that low-salinity water has an impact on the rock wettability; the more reduction in water salinity, the more a water-wet rock surface is produced. In addition, NaCl solutions made the rock more water-wet compared to CaCl2 or MgCl2 at the same concentration. Low-salinity water and NaCl solutions showed a highly negative charge at rock/brine and oil/brine interfaces by zeta potential measurements, which results in greater repulsive forces between the oil and rock surface. This leads to double-layer expansion and water-wet systems. These results demonstrate that the double-layer expansion is a primary mechanism of improving oil recovery when water chemical composition is manipulated. The electronic version of this dissertation is accessible from http://hdl.handle.net/1969.1/149468

Download or read book Experimental Insight Into Chemically Tuned Waterflooding in Oil wet Carbonate Reservoirs written by Prakash Purswani and published by . This book was released on 2017 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: Brine composition is known to affect the effectiveness of waterflooding during enhanced oil recovery from oilwet carbonate reservoirs. Salinity, pH and ion composition of the injecting brine have been identified as important factors toward altering the wettability of the carbonate rocks to a more waterwet system. In particular, the importance of Mg2+, Ca2+, and SO42- ions have been identified as critical for incremental oil recovery via wettability alteration. To further explore the chemical mechanism of wettability alteration and to evaluate the individual contribution of these ions toward improving oil recovery, a series of waterflood experiments with different ionic composition was performed at 90oC. Characterization techniques like Zeta potential, contact angle, and trace element analysis were performed to evaluate the surface interactions taking place among the rock, the brine solution, and the crude oil. Zeta potential measurements highlight the affinity of Mg2+, Ca2+, and SO42- ions toward the rock surface in chemically tuned brines, where, an increase in the magnitude of Zeta potential was observed corresponding to the increase in the concentration of each of these ions in the suspension. Oil recovery measurements show an increase for all chemically tuned brines, when compared to recoveries obtained from plain seawater injection. Relative permeability estimations and contact angle measurements show corresponding trends of increasing waterwetness. Maximum recovery of ~76% original oil in place (OOIP) was observed for the brine with increased Mg2+ ion concentration due to higher activity of Mg2+ ions and their ability to replace Ca2+ ions from the rock surface. A lower recovery of ~64% OOIP was seen for the brine with increased Ca2+ ion concentration due to lower activity of Ca2+ ions as opposed to Mg2+ ions. Further lower recovery of ~59% OOIP was seen for the brine with increased SO42- ion concentration due to the precipitation of these ions on the rock surface. These surface reactions including salt precipitation, crude oil desorption, and rock dissolution were confirmed through the ionic analysis of the effluent brine during each waterflooding experiment. These results help clarify the importance of chemical tuning of brines toward improving oil recovery and provide experimental insight into the chemical mechanism of wettability alteration.

Download or read book Fluid fluid Interactions as Foundation for Enhanced Oil Recovery Design written by Griselda Garcia-Olvera and published by . This book was released on 2016 with total page 185 pages. Available in PDF, EPUB and Kindle. Book excerpt: During the last decade, smart waterflooding has been developed as a promising IOR technology for carbonate and sandstone reservoirs. In general, decreasing the injection brine salinity may increase the oil recovery. Extensive research has been conducted to study the causative mechanisms for the additional oil recovery, yet no consensus among researchers has arisen. The main conclusion of previous studies suggest that is the rock wettability alteration towards more water conditions that helps to improve oil recovery. In contrast, we propose that fluid-fluid iteractions reflecting oil/brine visco-elastic interfacial buildup may minimize snap-off and favor coalescence of the oil during waterflooding, and as result, oil recovery is increased. The formation of the oil/brine interface depends on salinity and type of ions contained in solution, as well as asphaltenes and organic acids in oil. The presence of asphaltenes and sulfate ions in the system increases the interfacial visco-elasticity and organic acids weaken the interface. Our experiments suggest that low-salinity water injection is not always necessary to increase oil recovery, if an adequate high-salinity brine is designed to maximize fluid-fluid effects. On the other hand, the SP enhanced oil recovery process is tremendously affected by the carrying fluid, especially in the presence of Ca and Mg, aggravating more at high temperatures. These conditions can be a limitation for many surfactant and polymers in the market. We designed an SP formulation for an offshore, carbonate, heavy oil reservoir, where seawater was used as the carrying fluid. The forced imbibition results turned out promising in terms of oil recovery, reaching almost 90%. The protocol using Nuclear Magnetic Resonance (NMR) spectroscopy, developed during this dissertation, was used to estimate Critical Micelle Concentration (CMC) and individual component's concentration for coreflooding effluents and static adsorption estimation.

Download or read book Recovery of Crude Oil from Outcrop and Reservoir Sandstone by Low Salinity Waterflooding written by Hui Pu and published by . This book was released on 2010 with total page 279 pages. Available in PDF, EPUB and Kindle. Book excerpt: The importance of Enhanced Oil Recovery (EOR) technologies cannot be overemphasized, especially in the context of the surge in energy demand driven by rapid economic growth in developing countries as people strive to improve their living standards. Getting higher oil recovery from existing fields will be a key part of meeting the world's growing demand for energy. In the past decade, injection of brines of low salinity content and selected ionic composition in sandstone reservoirs has been developed into an emerging EOR technology. The advantage of low salinity waterflooding is that it is operationally comparable to conventional waterflooding and does not require expensive chemicals or carbon dioxide and nitrogen. The complexity of the crude oil/brine/rock interactions is well recognized and the mechanisms behind the low salinity EOR process have been debated in the literature for the last decade. The objective of this work is to explore by experimental study the effect of low salinity waterflooding on different outcrop and reservoir cores. Investigation of increased oil recovery by injection of low salinity water such as coalbed methane production water has been extended to reservoir cores from the Tensleep, Minnelusa and Phosphoria formations in Wyoming and outcrop cores (Berea and Bentheim). The Tensleep and Minnelusa formations are eolian sandstones of comparable depositional environment that contain interstitial anhydrite, dolomite and occasional calcite cements. The Phosphoria dolomite has pin-point to coarse vuggy pores lined by sparry dolomite crystals and also features patches of anhydrite. All the cores taken from pay zones showed increased oil recovery ranging from 5 to 8% original oil in place through injection of low salinity water. Increase in sulfate ion content of the effluent brine confirmed the dissolution of anhydrite, for all three reservoir rock types. Proposed mechanisms of recovery by low salinity flooding of sandstones which are tied to the presence of clay cannot apply because none of these rocks have significant clay content. Further evidence of the role of anhydrite dissolution was provided by the recovery behavior of Tensleep cores taken from the water-saturated aquifer zone of an oil reservoir. Anhydrite cement was sparse and only visible in occluded regions of pore space but not in regions that were clearly permeable. For these cores, there was no additional oil recovery when the injected brine was switched to low salinity water. The release of dolomite crystals and other fine embedded minerals which is likely associated with dissolution of anhydrite, may be a factor in the observed response to low salinity waterflooding. The movement of cement components is a possible contributing factor in the wide variety of observed relationships between pressure drop and oil recovery. For example, significant variation of relative permeability to brine at constant saturation is often observed.

Download or read book Chemical Enhanced Oil Recovery written by Patrizio Raffa and published by Walter de Gruyter GmbH & Co KG. This book was released on 2019-07-22 with total page 277 pages. Available in PDF, EPUB and Kindle. Book excerpt: This book aims at presenting, describing, and summarizing the latest advances in polymer flooding regarding the chemical synthesis of the EOR agents and the numerical simulation of compositional models in porous media, including a description of the possible applications of nanotechnology acting as a booster of traditional chemical EOR processes. A large part of the world economy depends nowadays on non-renewable energy sources, most of them of fossil origin. Though the search for and the development of newer, greener, and more sustainable sources have been going on for the last decades, humanity is still fossil-fuel dependent. Primary and secondary oil recovery techniques merely produce up to a half of the Original Oil In Place. Enhanced Oil Recovery (EOR) processes are aimed at further increasing this value. Among these, chemical EOR techniques (including polymer flooding) present a great potential in low- and medium-viscosity oilfields. • Describes recent advances in chemical enhanced oil recovery. • Contains detailed description of polymer flooding and nanotechnology as promising boosting tools for EOR. • Includes both experimental and theoretical studies. About the Authors Patrizio Raffa is Assistant Professor at the University of Groningen. He focuses on design and synthesis of new polymeric materials optimized for industrial applications such as EOR, coatings and smart materials. He (co)authored about 40 articles in peer reviewed journals. Pablo Druetta works as lecturer at the University of Groningen (RUG) and as engineering consultant. He received his Ph.D. from RUG in 2018 and has been teaching at a graduate level for 15 years. His research focus lies on computational fluid dynamics (CFD).

Download or read book Development Theories and Methods of Fracture Vug Carbonate Reservoirs written by Yang Li and published by Academic Press. This book was released on 2017-05-17 with total page 515 pages. Available in PDF, EPUB and Kindle. Book excerpt: Development Theories and Methods of Fracture-Vug Carbonate Reservoirs explores the theories and methods for successful development of a fracture-vug reservoir by presenting the developmental strategies used in the Tahe oilfield. Some of the theories and methods of developing the Tahe fracture-vug reservoirs have been inspired by two China national research projects: The 'Basic research on development of fracture-vug carbonate reservoirs' (2006-2010), and the 'Basic research on production mechanism and oil recovery enhancement of fracture-vugcarbonate reservoirs' (2011-2015), with support by the National Basic Research Program of China. These theories and methods have facilitated the successful development of the fracture-vug reservoir in the Tahe oilfield, providing effective technologies and inspirations to developing similar reservoirs everywhere. - Provides information on both theoretical developments and technological innovations - Applies the modern karst formation characterization and the fracture-vug hierarchical structure to geological investigations of fracture-vug carbonate reservoirs - Introduces the karst facies-controlling 3D geologic modeling of fracture-vug reservoir formations - Proposes the coupled-processing and equivalent multi-medium numerical simulation methods of fracture-vug reservoirs - Presents development methodologies and techniques of water/gas flooding

Download or read book Recovery Improvement written by Qiwei Wang and published by Gulf Professional Publishing. This book was released on 2022-09-06 with total page 614 pages. Available in PDF, EPUB and Kindle. Book excerpt: Oil and Gas Chemistry Management Series brings an all-inclusive suite of tools to cover all the sectors of oil and gas chemicals from drilling, completion to production, processing, storage, and transportation. The third reference in the series, Recovery Improvement, delivers the critical chemical basics while also covering the latest research developments and practical solutions. Organized by the type of enhanced recovery approaches, this volume facilitates engineers to fully understand underlying theories, potential challenges, practical problems, and keys for successful deployment. In addition to the chemical, gas, and thermal methods, this reference volume also includes low-salinity (smart) water, microorganism- and nanofluid-based recovery enhancement, and chemical solutions for conformance control and water shutoff in near wellbore and deep in the reservoir. Supported by a list of contributing experts from both academia and industry, this book provides a necessary reference to bridge petroleum chemistry operations from theory into more cost-efficient and sustainable practical applications. - Covers background information and practical guidelines for various recovery enhancement domains, including chapters on enhanced oil recovery in unconventional reservoirs and carbon sequestration in CO2 gas flooding for more environment-friendly and more sustainable initiatives - Provides effective solutions to control chemistry-related issues and mitigation strategies for potential challenges from an industry list of experts and contributors - Delivers both up-to-date research developments and practical applications, featuring various case studies