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Enhanced Oil Recovery Through Water Imbibition In Fractured Reservoirs Using Nuclear Magnetic Resonance
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Book Synopsis Enhanced Oil Recovery Through Water Imbibition in Fractured Reservoirs Using Nuclear Magnetic Resonance by : Rafael Alejandro Hervas Ordonez
Download or read book Enhanced Oil Recovery Through Water Imbibition in Fractured Reservoirs Using Nuclear Magnetic Resonance written by Rafael Alejandro Hervas Ordonez and published by . This book was released on 1994 with total page 172 pages. Available in PDF, EPUB and Kindle. Book excerpt:
Book Synopsis Aspects of Oil Recovery by Spontaneous Imbibition and Wettability Alteration by : Siluni Wickramathilaka
Download or read book Aspects of Oil Recovery by Spontaneous Imbibition and Wettability Alteration written by Siluni Wickramathilaka and published by . This book was released on 2011 with total page 271 pages. Available in PDF, EPUB and Kindle. Book excerpt: Spontaneous imbibition is one of the key mechanisms for oil production from naturally fractured reservoirs. The final oil recovery and the rate of oil recovery by spontaneous imbibition depend on many rock and fluid properties and wettability of the rock. Important factors that affect wettability are the rock type, initial water saturation, crude oil type, aging time, brine composition and salinity, and displacement temperature. Understanding wettability through spontaneous imbibition studies is crucial because wettability can affect the fluid location, fluid flow, and residual oil distributions of reservoirs. Many factors that affect imbibition oil recovery and wettability have not been studied extensively for carbonates. Better understanding of the effects of wettability and scaling laboratory spontaneous imbibition data is important to predicting oil recovery from fractured reservoirs. The objectives of the present study were to investigate various crude oil/brine/rock (COBR) interactions and factors which could affect wettability, to evaluate correlation of spontaneous imbibition data with various wetting conditions for carbonates, and to improve oil recovery by spontaneous imbibition with change in invading brine composition and salinity and by use of surfactants. Reproducibility of the spontaneous imbibition results is also emphasized. The variation of aqueous phase viscosity was performed for three distinct wettability conditions classed as Very Strongly Water-Wet (VSWW), Uniformly-Wet (UW-CO) and Mixed-Wet (MXW), to study the effects on spontaneous imbibition as well as to extend previous studies on spontaneous imbibition correlations. The Mason et al. (2010) scaling group (a modification of the Ma et al. (1997) scaling group) developed mainly for wide variation in aqueous phase viscosities of VSWW Berea sandstone was used to satisfactorily correlate most of the data obtained for VSWW carbonate spontaneous imbibition results. The mechanism of VSWW imbibition was investigated by use of Magnetic Resonance Imaging (MRI) to monitor oil recovery from spontaneous imbibition of brine. The saturation profiles and images obtained for linear and radial imbibition indicate that the pore structure plays a significant role during spontaneous imbibition of brine into an oil saturated rock. Formation of a sharp piston-like imbibition front also validates previous assumptions made for development of imbibition scaling groups. Under wettability conditions that made capillary forces very weak, imbibition was controlled by change in density of the aqueous phase. For UW-CO, improved correlation was given by using weighted viscosity terms. Data was correlated by scaling with respect to the product of dimensionless time (basically the ratio of capillary to viscous forces) times the ratio of gravity to capillary forces. The initial water saturation, crude oil type, aging time, and displacement temperature have been varied for selected rocks to evaluate wettability and its effects on oil recovery by spontaneous imbibition. Improved oil recovery was demonstrated for spontaneous imbibition through reduction in invading brine salinity and also by addition of various types of anionic, amphoteric, cationic, and nonionic surfactants. Increases in recovery were fastest and highest for nonionic surfactants.
Book Synopsis Fluid-fluid Interactions as Foundation for Enhanced Oil Recovery Design by : Griselda Garcia-Olvera
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.
Book Synopsis Masters Theses in the Pure and Applied Sciences by : Wade H. Shafer
Download or read book Masters Theses in the Pure and Applied Sciences written by Wade H. Shafer and published by Springer Science & Business Media. This book was released on 2012-12-06 with total page 427 pages. Available in PDF, EPUB and Kindle. Book excerpt: Masters Theses in the Pure and Applied Sciences was first conceived, published, and disseminated by the Center for Information and Numerical Data Analysis and Synthesis (CINDAS)* at Purdue University in 1957, starting its coverage of theses with the academic year 1955. Beginning with Volume 13, the printing and dis semination phases of the activity were transferred to University Microfilms/Xerox of Ann Arbor, Michigan, with the thought that such an arrangement would be more beneficial to the academic and general scientific and technical community. After five years of this joint undertaking we had concluded that it was in the interest of all concerned if the printing and distribution of the volumes were handled by an international publishing house to assure improved service and broader dissemination. Hence, starting with Volume 18, Masters Theses in the Pure and Applied Sciences has been disseminated on a worldwide basis by Plenum Publishing Corporation of New York, and in the same year the coverage was broadened to include Canadian universities. All back issues can also be ordered from Plenum. We have reported in Volume 39 (thesis year 1994) a total of 13,953 thesis titles from 21 Canadian and 159 United States universities. We are sure that this broader base for these titles reported will greatly enhance the value of this impor tant annual reference work. While Volume 39 reports theses submitted in 1994, on occasion, certain uni versities do report theses submitted in previous years but not reported at the time.
Book Synopsis Enhanced Oil Recovery Field Case Studies by : James J. Sheng
Download or read book Enhanced Oil Recovery Field Case Studies written by James J. Sheng and published by Elsevier Inc. Chapters. This book was released on 2013-04-10 with total page 21 pages. Available in PDF, EPUB and Kindle. Book excerpt: This chapter presents models of wettability alteration using surfactants and upscaling models related to oil recovery in fractured carbonate reservoirs. Chemicals used in carbonate reservoirs are reviewed. The presented field cases where surfactants were used to stimulate oil recovery are the Mauddud carbonate in Bahrain, the Yates field and the Cretaceous Upper Edwards reservoir in Texas, the Cottonwood Creek field in Wyoming, and the Baturaja formation in the Semoga field in Indonesia.
Book Synopsis Proceedings of the International Field Exploration and Development Conference 2023 by : Jia’en Lin
Download or read book Proceedings of the International Field Exploration and Development Conference 2023 written by Jia’en Lin and published by Springer Nature. This book was released on with total page 1909 pages. Available in PDF, EPUB and Kindle. Book excerpt:
Book Synopsis Altering Reservoir Wettability to Improve Production from Single Wells by : W. W. Weiss
Download or read book Altering Reservoir Wettability to Improve Production from Single Wells written by W. W. Weiss and published by . This book was released on 2006 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: Many carbonate reservoirs are naturally fractured and typically produce less than 10% original oil in place during primary recovery. Spontaneous imbibition has proven an important mechanism for oil recovery from fractured reservoirs, which are usually weak waterflood candidates. In some situations, chemical stimulation can promote imbibition of water to alter the reservoir wettability toward water-wetness such that oil is produced at an economic rate from the rock matrix into fractures. In this project, cores and fluids from five reservoirs were used in laboratory tests: the San Andres formation (Fuhrman Masho and Eagle Creek fields) in the Permian Basin of Texas and New Mexico; and the Interlake, Stony Mountain, and Red River formations from the Cedar Creek Anticline in Montana and South Dakota. Solutions of nonionic, anionic, and amphoteric surfactants with formation water were used to promote waterwetness. Some Fuhrman Masho cores soaked in surfactant solution had improved oil recovery up to 38%. Most Eagle Creek cores did not respond to any of the tested surfactants. Some Cedar Creek anticline cores had good response to two anionic surfactants (CD 128 and A246L). The results indicate that cores with higher permeability responded better to the surfactants. The increased recovery is mainly ascribed to increased water-wetness. It is suspected that rock mineralogy is also an important factor. The laboratory work generated three field tests of the surfactant soak process in the West Fuhrman Masho San Andres Unit. The flawlessly designed tests included mechanical well clean out, installation of new pumps, and daily well tests before and after the treatments. Treatments were designed using artificial intelligence (AI) correlations developed from 23 previous surfactant soak treatments. The treatments were conducted during the last quarter of 2006. One of the wells produced a marginal volume of incremental oil through October. It is interesting to note that the field tests were conducted in an area of the field that has not met production expectations. The dataset on the 23 Phosphoria well surfactant soaks was updated. An analysis of the oil decline curves indicted that 4.5 lb of chemical produced a barrel of incremental oil. The AI analysis supports the adage 'good wells are the best candidates.' The generally better performance of surfactant in the high permeability core laboratory tests supports this observation. AI correlations were developed to predict the response to water-frac stimulations in a tight San Andres reservoir. The correlations maybe useful in the design of Cedar Creek Anticline surfactant soak treatments planned for next year. Nuclear Magnetic Resonance scans of dolomite cores to measure porosity and saturation during the high temperature laboratory work were acquired. The scans could not be correlated with physical measurement using either conventional or AI methods.
Book Synopsis Enhanced Oil Recovery in Shale and Tight Reservoirs by : James J.Sheng
Download or read book Enhanced Oil Recovery in Shale and Tight Reservoirs written by James J.Sheng and published by Gulf Professional Publishing. This book was released on 2019-11-07 with total page 540 pages. Available in PDF, EPUB and Kindle. Book excerpt: Oil Recovery in Shale and Tight Reservoirs delivers a current, state-of-the-art resource for engineers trying to manage unconventional hydrocarbon resources. Going beyond the traditional EOR methods, this book helps readers solve key challenges on the proper methods, technologies and options available. Engineers and researchers will find a systematic list of methods and applications, including gas and water injection, methods to improve liquid recovery, as well as spontaneous and forced imbibition. Rounding out with additional methods, such as air foam drive and energized fluids, this book gives engineers the knowledge they need to tackle the most complex oil and gas assets. - Helps readers understand the methods and mechanisms for enhanced oil recovery technology, specifically for shale and tight oil reservoirs - Includes available EOR methods, along with recent practical case studies that cover topics like fracturing fluid flow back - Teaches additional methods, such as soaking after fracturing, thermal recovery and microbial EOR
Book Synopsis Proceedings of the ... Wyoming Enhanced Oil Recovery Symposium by :
Download or read book Proceedings of the ... Wyoming Enhanced Oil Recovery Symposium written by and published by . This book was released on 1993 with total page 352 pages. Available in PDF, EPUB and Kindle. Book excerpt:
Book Synopsis Oil Recovery Enhancement from Fractured, Low Permeability Reservoirs. Part 2, Annual Report, October 1, 1990--September 31, 1991 by :
Download or read book Oil Recovery Enhancement from Fractured, Low Permeability Reservoirs. Part 2, Annual Report, October 1, 1990--September 31, 1991 written by and published by . This book was released on 1991 with total page 56 pages. Available in PDF, EPUB and Kindle. Book excerpt: The results of the investigative efforts for this jointly funded DOE-State of Texas research project achieved during the 1990--1991 year may be summarized as follows: Geological Characterization -- Detailed maps of the development and hierarchical nature the fracture system exhibited by Austin Chalk outcrops were prepared. These results of these efforts were directly applied to the development of production decline type curves applicable to a dual fracture-matrix flow system. Analysis of production records obtained from Austin Chalk operators illustrated the utility of these type curves to determine relative fracture/matrix contributions and extent. Well-log response in Austin Chalk wells has been shown to be a reliable indicator of organic maturity. (VSP) Vertical-Seismic Profile data was used to use shear-wave splitting concepts to estimate fracture orientations. Several programs were to be written to facilitate analysis of the data. The results of these efforts indicated fractures could be detected with VSP seismic methods. Development of the (EOR) Enhanced Oil Recovery Imbibition Process -- Laboratory displacement as well as MRI and CT imaging studies have shown the carbonated water-imbibition displacement process significantly accelerates and increases recovery of an oil saturated, low permeability core material, when compared to that of a normal brine imbibition displacement process. A study of oil recovery by the application of a cyclic carbonated water imbibition process, followed by reducing the pressure below the bubble point of the CO2-water solution, indicated the possibility of alternate and new enhanced recovery method. The installation of an artificial solution gas drive significantly increased oil recovery. The extent and arrangement of micro-fractures in Austin Chalk horizontal cores was mapped with CT scanning techniques. The degree of interconnection of the micro-fractures was easily visualized.
Book Synopsis Development of Unconventional Reservoirs by : Reza Rezaee
Download or read book Development of Unconventional Reservoirs written by Reza Rezaee and published by MDPI. This book was released on 2020-04-16 with total page 522 pages. Available in PDF, EPUB and Kindle. Book excerpt: The need for energy is increasing and but the production from conventional reservoirs is declining quickly. This requires an economically and technically feasible source of energy for the coming years. Among some alternative future energy solutions, the most reasonable source is from unconventional reservoirs. As the name “unconventional” implies, different and challenging approaches are required to characterize and develop these resources. This Special Issue covers some of the technical challenges for developing unconventional energy sources from shale gas/oil, tight gas sand, and coalbed methane.
Book Synopsis Enhanced Oil Recovery from Fractured Carbonate Reservoirs Using Nanoparticles with Low-salinty Water and Surfactant by : Gideon Dordzie
Download or read book Enhanced Oil Recovery from Fractured Carbonate Reservoirs Using Nanoparticles with Low-salinty Water and Surfactant written by Gideon Dordzie and published by . This book was released on 2023 with total page 0 pages. Available in PDF, EPUB and Kindle. Book excerpt: The global significance of oil production in the face of increasing demand for energy and its resources cannot be overemphasized. Eco-friendly and effective oil recovery techniques have been diversely implemented in addition to traditional brine imbibition into porous matrix domains aimed at displacing substantial amounts of oil towards production wells for maximum oil recovery. Be that as it may, carbonate reservoirs, which contain more than half of the global oil reserves, are characterized by heterogeneities, natural fracture networks, and oil wetness, culminating in waterflooding inefficiency. Consequently, the performance of low salinity water (LSW), nanoparticles (NPs), and surfactants (abbreviated as LNS) in their individual and combined applications for enhanced oil recovery (EOR) purposes has been highlighted in several works. Again, an emerging technique involving the alternating injection of LNS has been previously employed for carbonates; however, their implementation in fractured carbonate reservoirs (FCRs) was yet to be investigated. One of the crucial applications of NPs for incremental oil recovery is their tendency to enhance mobility control via viscosity modification. Therefore, this work probes the viscosity behavior of a solution of NPs dispersed in different ionic components of brine with increasing concentrations of the NPs. Ultimately, the understanding of crude oil-brine-rock (COBR) interactions, the viscosity behavior of the nanofluids, and the previous performances of LNS are used to effectively design suitable coreflooding experiments for examining the performance of LNS in FCRs. The applicability of LNS is first probed in spontaneous imbibition (SI) tests and subsequently implemented in dynamic imbibition experiments utilizing specific NPs and an anionic surfactant. The oil recovery results obtained are herein presented and the corresponding mechanisms are highlighted. Furthermore, owing to the successful application of LNS with the usage of anionic surfactants, this investigation is extended to include non-ionic and cationic surfactants. The sequential injection of LNS into FCRs under the same experimental conditions used in previous studies is executed for a different solution of NPs and cationic surfactants following the subjection of the injected fluids to SI tests. The painstaking analysis of the observations as well as the relevant inferences deduced is thus presented in this investigation. Overall, the suitability of the alternating injection of LNS demonstrated in this study under extremely unfavorable conditions and potential impediments to incremental oil recovery indicates that it is well-fitted for EOR in FCRs.
Book Synopsis Compositional Modelling of Imbibition Oil Recovery Processes in Naturally-fractured Reservoirs by : Shamsuddin H. Shenawi
Download or read book Compositional Modelling of Imbibition Oil Recovery Processes in Naturally-fractured Reservoirs written by Shamsuddin H. Shenawi and published by . This book was released on 1994 with total page 334 pages. Available in PDF, EPUB and Kindle. Book excerpt:
Book Synopsis Advancements of Phase Behavior and Fluid Transport in Petroleum Reservoirs by : Xiaohu Dong
Download or read book Advancements of Phase Behavior and Fluid Transport in Petroleum Reservoirs written by Xiaohu Dong and published by Frontiers Media SA. This book was released on 2022-06-30 with total page 102 pages. Available in PDF, EPUB and Kindle. Book excerpt:
Book Synopsis Imbibition of Anionic Surfactant Solution Into Oil-wet Matrix in Fractured Reservoirs by : Mohammad Mirzaei Galeh Kalaei
Download or read book Imbibition of Anionic Surfactant Solution Into Oil-wet Matrix in Fractured Reservoirs written by Mohammad Mirzaei Galeh Kalaei and published by . This book was released on 2013 with total page 656 pages. Available in PDF, EPUB and Kindle. Book excerpt: Water-flooding in water-wet fractured reservoirs can recover significant amounts of oil through capillary driven imbibition. Unfortunately, many of the fractured reservoirs are mixed-wet/oil-wet and water-flooding leads to poor recovery as the capillary forces hinder imbibition. Surfactant injection and immiscible gas injection are two possible processes to improve recovery from fractured oil-wet reservoirs. In both these EOR methods, the gravity is the main driving force for oil recovery. Surfactant has been recommended and shown a great potential to improve oil recovery from oil-wet cores in the laboratory. To scale the results to field applications, the physics controlling the imbibition of surfactant solution and the scaling rules needs to be understood. The standard experiments for testing imbibition of surfactant solution involves an imbibition cell, where the core is placed in the surfactant solution and the recovery is measured versus time. Although these experiments prove the effectiveness of surfactants, little insight into the physics of the problem is achieved. This dissertation provides new core scale and pore scale information on imbibition of anionic surfactant solution into oil-wet porous media. In core scale, surfactant flooding into oil-wet fractured cores is performed and the imbibition of the surfactant solution into the core is monitored using X-ray computerized tomography(CT). The surfactant solution used is a mixture of several different surfactants and a co-solvent tailored to produce ultra-low interfacial tension (IFT) for the specific oil used in the study. From the CT images during surfactant flooding, the average penetration depth and the water saturation versus height and time is calculated. Cores of various sizes are used to better understand the effect of block dimension on imbibition behavior. The experimental results show that the brine injection into fractured oil-wet core only recovers oil present in the fracture; When the surfactant solution is injected, the CT images show the imbibition of surfactant solution into the matrix and increase in oil recovery. The surfactant solution imbibes as a front. The imbibition takes place both from the bottom and the sides of the core. The highest imbibition is observed close to the bottom of the core. The imbibition from the side decreases with height and lowest imbibition is observed close to the top of the core. Experiments with cores of different sizes show that increase in either the length or the diameter of the core causes decrease in the fractional recovery rate (%OOIP). Numerical simulation is also used to determine the physics that controls the imbibition profiles. %The numerical simulations show that the relative permeability curves strongly affect the imbibition profiles and should be well understood to accurately model the process. Both experimental and numerical simulation results imply that the gravity is the main driving force for the imbibition process. The traditional scaling group for gravity dominated imbibition only includes the length of the core to upscale the recovery for cores of different sizes. However based on the measurements and simulation results from this study, a new scaling group is proposed that includes both the diameter and the length of the core. It is shown that the new scaling group scales the recovery curves from this study better than the traditional scaling group. In field scale, the new scaling group predicts that the recovery from fractured oil-wet reservoirs by surfactant injection scales by both the vertical and horizontal fracture spacing. In addition to core scale experiments, capillary tube experiments are also performed. In these experiments, the displacement of oil by anionic surfactant solutions in oil-wet horizontal capillary tubes is studied. The position of the oil-aqueous phase interface is recorded with time. Several experimental parameters including the capillary tube radius and surfactant solution viscosity are varied to study their effect on the interface speed. Two different models are used to predict the oil-aqueous phase interface position with time. In the first model, it is assumed that the IFT is constant and ultra-low throughout the experiments. The second model involves change of wettability and IFT by adsorption of surfactant molecules to the oil-water interface and the solid surface. Comparing the predictions to the experimental results, it is observed that the second model provides a better match, especially for smaller capillary tubes. The model is then used to predict the imbibition rate for very small capillary tubes, which have equivalent permeability close to oil reservoirs. The results show that the oil displacement rate is limited by the rate of diffusion of surfactant molecules to the interface. In addition to surfactant flooding, immiscible gas injection can also improve recovery from fractured oil-wet reservoirs. In this process, the injected gas drains the oil in the matrix by gravity forces. Gravity drainage of oil with gas is an efficient recovery method in strongly water-wet reservoirs and yields very low residual oil saturations. However, many of the oil-producing fractured reservoirs are not strongly water-wet. Thus, predicting the profiles and ultimate recovery for mixed and oil-wet media is essential to design and optimization of improved recovery methods based on three-phase gravity drainage. In this dissertation, we provide the results from two- and three-phase gravity drainage experiments in sand-packed columns with varying wettability. The results show that the residual oil saturation from three-phase gravity drainage increases with increase in the fraction of oil-wet sand. A simple method is proposed for predicting the three-phase equilibrium saturation profiles as a function of wettability. In each case, the three-phase results were compared to the predictions from two-phase results of the same wettability. It is found that the gas/oil and oil/water transition levels can be predicted from pressure continuity arguments and the two-phase data. The predictions of three-phase saturations work well for the water-wet media, but become progressively worse with increasing oil-wet fraction.
Book Synopsis Fundamentals of Reservoir Surface Energy as Related to Surface Properties, Wettability, Capillary Action, and Oil Recovery from Fractured Reservoirs by Spontaneous Imbibition by :
Download or read book Fundamentals of Reservoir Surface Energy as Related to Surface Properties, Wettability, Capillary Action, and Oil Recovery from Fractured Reservoirs by Spontaneous Imbibition written by and published by . This book was released on 2006 with total page pages. Available in PDF, EPUB and Kindle. Book excerpt: The objective of this project is to increase oil recovery from fractured reservoirs through improved fundamental understanding of the process of spontaneous imbibition by which oil is displaced from the rock matrix into the fractures. Spontaneous imbibition is fundamentally dependent on the reservoir surface free energy but this has never been investigated for rocks. In this project, the surface free energy of rocks will be determined by using liquids that can be solidified within the rock pore space at selected saturations. Thin sections of the rock then provide a two-dimensional view of the rock minerals and the occupant phases. Saturations and oil/rock, water/rock, and oil/water surface areas will be determined by advanced petrographic analysis and the surface free energy which drives spontaneous imbibition will be determined as a function of increase in wetting phase saturation. The inherent loss in surface free energy resulting from capillary instabilities at the microscopic (pore level) scale will be distinguished from the decrease in surface free energy that drives spontaneous imbibition. A mathematical network/numerical model will be developed and tested against experimental results of recovery versus time over broad variation of key factors such as rock properties, fluid phase viscosities, sample size, shape and boundary conditions. Two fundamentally important, but not previously considered, parameters of spontaneous imbibition, the capillary pressure acting to oppose production of oil at the outflow face and the pressure in the nonwetting phase at the no-flow boundary versus time, will also be measured and modeled. Simulation and network models will also be tested against special case solutions provided by analytic models. In the second stage of the project, application of the fundamental concepts developed in the first stage of the project will be demonstrated. The fundamental ideas, measurements, and analytic/numerical modeling will be applied to mixed-wet rocks. Imbibition measurements will include novel sensitive pressure measurements designed to elucidate the basic mechanisms that determine induction time and drive the very slow rate of spontaneous imbibition commonly observed for mixed-wet rocks. In further demonstration of concepts, three approaches to improved oil recovery from fractured reservoirs will be tested; use of surfactants to promote imbibition in oil wet rocks by wettability alteration: manipulation of injection brine composition: reduction of the capillary back pressure which opposes production of oil at the fracture face.
Book Synopsis Fundamentals of Gas Shale Reservoirs by : Reza Rezaee
Download or read book Fundamentals of Gas Shale Reservoirs written by Reza Rezaee and published by John Wiley & Sons. This book was released on 2015-07-01 with total page 420 pages. Available in PDF, EPUB and Kindle. Book excerpt: Provides comprehensive information about the key exploration, development and optimization concepts required for gas shale reservoirs Includes statistics about gas shale resources and countries that have shale gas potential Addresses the challenges that oil and gas industries may confront for gas shale reservoir exploration and development Introduces petrophysical analysis, rock physics, geomechanics and passive seismic methods for gas shale plays Details shale gas environmental issues and challenges, economic consideration for gas shale reservoirs Includes case studies of major producing gas shale formations
