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1
Agharazi-Dormani, Nader. "Modeling of radial water/oil displacement in water-wet porous media." Thesis, University of Ottawa (Canada), 1991. http://hdl.handle.net/10393/5706.
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The effects of five operating variables and four dimensionless groups on oil recovery and finger formation during the immiscible radial displacement of oil by water in a consolidated water-wet porous medium were investigated using statistical model building techniques. Two different approaches were used. In the first approach, experiments were carried out according to a central composite design with partial replication over the following operating region: (UNFORMATTED TABLE OR EQUATION FOLLOWS)$$\vbox{\halign{#\hfil&&\quad#\hfil\cr &Flow rate of injection fluid&0.65 $\le$ Q $\le$ 510.00 (mL/h)\cr &Radius of breakthrough&2.5 $\le$ R $\le$ 7.0 (cm)\cr &Viscosity difference&15 $\le\mu\sb{\rm o}$-$\mu\sb{\rm w} \le 152$ (mPa.s)\cr &Permeability&13.33 $\le$ K $\le$ 77.41 ($\mu$m$\sp2$)\cr&Interfacial tension (IFT)&0.3 $\le \gamma \le$ 30.0 (mN/m)\cr}}$$(TABLE/EQUATION ENDS) A second-order polynomial of the general form $$\rm Y = \beta\sb{o} + \sum\sbsp{i=1}{5} \beta\sb{i}X\sb{i} + \sum\sbsp{i=1}{5} \sum\sbsp{j=1}{5} \beta\sb{ij}X\sb{i}X\sb{j}$$was fitted to the data. It was found that for water-wet systems, the recovery decreased as the viscosity difference increased and this effect became more significant as the flow rate increased. Conversely, as the breakthrough radius or permeability of the cell increased, the recovery increased. The effect of IFT was negative and depended on the level of viscosity difference and permeability. In addition, an increase in flow rate, breakthrough radius or the viscosity difference resulted in an increase in the number of fingers, while high permeability reduced the number of fingers. The operating variables were grouped together in dimensionless terms such as the capillary number and the viscosity ratio, and the parameters ($\beta\sbsp{\rm i}{\prime}$s) were estimated for these terms. The recovery was found to be enhanced with an increase in the ratio of breakthrough radius to the cell thickness (R/h). It was reduced as the viscosity ratio increased and this attenuating effect became more significant as the flow rate increased. The effect of ratio of the cell thickness to the square root of the permeability (h/$\sqrt{K})$ and capillary number depended on the value of other variables. The number of fingers increased as any of the above ratios was increased with the exception of (h/$\sqrt{K})$ where the effect was more complex. (Abstract shortened by UMI.)
2
VARGAS, KELLY MARGARITA COLMENARES. "OIL DISPLACEMENT IN MICRO MODELS OF POROUS MEDIA BY INJECTION OF OIL IN WATER EMULSION." PONTIFÍCIA UNIVERSIDADE CATÓLICA DO RIO DE JANEIRO, 2014. http://www.maxwell.vrac.puc-rio.br/Busca_etds.php?strSecao=resultado&nrSeq=35523@1.
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PONTIFÍCIA UNIVERSIDADE CATÓLICA DO RIO DE JANEIROCOORDENAÇÃO DE APERFEIÇOAMENTO DO PESSOAL DE ENSINO SUPERIOR
PROGRAMA DE EXCELENCIA ACADEMICA
O processo de recuperação de óleo pelo deslocamento com água é o método mais utilizado na indústria de petróleo. No entanto, as altas razões de mobilidade e baixas eficiências de varrido tornam o processo menos eficiente. Uma alternativa usada para minimizar este efeito é a aplicação de tecnologias que atuam como agentes de controle de mobilidade. Dentre eles, e em particular a injeção de emulsões de óleo em água tem sido estudada com relativo sucesso como um método de recuperação avançada de óleo. Alguns estudos indicam melhor varredura do reservatório devido a uma redução da mobilidade da água em regiões do reservatório já varridas por água, mediante a aglomeração e bloqueio parcial dos poros mais permeáveis com gotas da fase dispersa da emulsão. Contudo, ainda não há compreensão plena dos mecanismos associados ao escoamento de emulsões em meios porosos, assim, uma análise e visualização na escala microscópica dos fenômenos envolvidos se faz essencial para a melhora do entendimento do escoamento de emulsões em um reservatório. Neste trabalho, experimentos de escoamento de emulsões foram conduzidos em um micromodelo de vidro, estrutura artificial que busca representar alguns aspectos principais de um meio poroso e proporciona uma adequada visualização do comportamento das faces ao longo do escoamento. Nos experimentos foram realizadas alterações na molhabilidade e variou-se a vazão volumétrica a fim de avaliar diferentes números de capilaridade no meio poroso. Dentro dos resultados mais significativos, foi evidenciado como a fase dispersa da emulsão é capaz de bloquear os poros e gargantas de poro alterando a distribuição dos fluidos no meio poroso, melhorando a eficiência de deslocamento na escala de poro e com isso o fator de recuperação final. Os resultados mostram que, a altos números de capilaridade as forças interfaciais são menos importantes ao reduzir o efeito de bloqueio pelas gotas da fase dispersa nos poros do micromodelo. Estes resultados fornecem um grande aprendizado ao permitir conhecer características do escoamento de emulsões no meio poroso para uma futura aplicação no campo.
The oil recovery process by water-flooding is the most used method in the oil industry. However, the high mobility ratios and low sweep efficiencies make the process less effective. A common alternative to minimize this effect is the application of technologies that act as mobility control agents. Among them and in particular the injection of oil in water emulsions has been studied with relative success as an Enhanced Oil Recovery (EOR) method. Several studies indicate a better reservoir sweep due to the water mobility reduction in regions already swept by water. This reduction can be associated with partial blockage of porous media throats by droplets of emulsion dispersed phase. Nevertheless, there is still no full understanding of the mechanisms associated to the flow of emulsions in porous media, thus, an analysis and visualization at the microscopic scale of the involved phenomena is essential for the improvement of the comprehension of the flow of emulsions in a reservoir. In this work, experimental tests related to the flow of emulsions in a glass micro-model were performed, artificial device that represents some principal features of a porous medium and provides a proper visualization of the phase behavior. In the experiments, the effect of the capillary number on the oil recovery factor and the relative influence of the wettability of the porous medium on the oil displacement process were studied. The results evidence how the oil droplets in the emulsion are capable of block the pores and the pore throats modifying the fluids distribution in the porous medium, improving the displacement efficiency at pore scale and consequently the final oil recovery factor. It was also observed that at high capillary numbers, the blocking caused by the capillary pressure needed to deform the droplet becomes less intense. These results provide a great learning by allowing to know the characteristics of the flow of emulsions in porous media for a future field application.
3
Thirunavu, Subramanian. "Effects of buoyancy forces on immiscible oil/water displacements in porous media." Thesis, University of Ottawa (Canada), 1994. http://hdl.handle.net/10393/10231.
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The effects of buoyancy forces on liquid-liquid displacement processes occurring in porous media are important in a variety of practical situations, in particular during the displacement of oil from partially-depleted underground reservoirs by means of aqueous solutions. Most previous studies involving the visualization of water/oil displacements in porous media have been undertaken in horizontal two-dimensional porous medium cells. The objective of this work was to determine the effects of buoyancy forces on the fingering pattern and oil recovery by conducting immiscible displacement experiments in two-dimensional porous medium cells aligned in the vertical plane. A consolidated porous medium cell was utilized to perform the displacements, which permitted a wide range of experiments to be carried out within an identical porous medium. In order to obtain a clear understanding of the effects of buoyancy forces (both favourable and unfavourable) experiments were carried out in three different modes, namely horizontal, vertical upward, and vertical downward. As the effects of buoyancy forces are almost negligible, in the horizontal mode, recoveries obtained in this mode are used as a reference and compared to those obtained in the other two modes. For the system studied in this work, as the displacing liquid in all cases had a higher density than the displaced liquid, buoyancy forces were always favourable in the vertical upward mode and always unfavourable in the vertical downward mode. The immiscible system employed consisted of heavy paraffin oil and glycerol solution as the displaced and displacing phases respectively. The viscosity ratio was varied by changing the concentration of the glycerol solution. Displacements with five different viscosity ratios were studied. Breakthrough time was measured and fractional oil recovery was calculated. The effects of buoyancy, viscous and capillary forces as well as the injection flow rate were also observed. The results obtained indicate that the buoyancy forces are highly effective at very low flow rates and low viscosity ratios (or high density ratios), and even with a slight increase in the flow rate, buoyancy forces lose their importance quickly.
4
NUNEZ, VICTOR RAUL GUILLEN. "OIL DISPLACEMENT IN A POROUS MEDIA THROUGH INJECTION OF OIL-IN-WATER EMULSION: ANALYSIS OF LINEAR FLOW." PONTIFÍCIA UNIVERSIDADE CATÓLICA DO RIO DE JANEIRO, 2007. http://www.maxwell.vrac.puc-rio.br/Busca_etds.php?strSecao=resultado&nrSeq=10663@1.
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COORDENAÇÃO DE APERFEIÇOAMENTO DO PESSOAL DE ENSINO SUPERIORAGÊNCIA NACIONAL DE PETRÓLEO
A injeção de emulsão é um método comum para melhorar o varrido do reservatório e manter-lo pressurizado. A eficiência de recuperação de óleo no caso de óleos pesados é limitada pela alta razão de mobilidade entre a água injetada e o óleo. Um método de reduzir o problema relativo µa alta razão de viscosidade é por injeção de soluções poliméricas. Porem, a interação líquido- rocha, os grandes volumes e o preço associado dos polímeros podem fazer esta técnica não aplicável em caso de campos gigantes. Diferentes métodos de recuperação avançada de óleo estão sendo desenvolvidos como alternativas µa injeção de polímeros. A injeção de dispersões, em particular a injeção de emulsões, têm sido tratadas com relativo sucesso como um método de recuperação avançada de óleo, mas as técnicas não são totalmente desenvolvidas ou compreendidas. O uso de cada método requer uma completa análise dos diferentes regimes de fluxo de emulsões dentro do espaço poroso de um reservatório. A maioria das análises de fluxo de emulsões em um meio poroso utiliza uma descrição macroscópica. Esta aproximãção é só valida para emulsões com o tamanho da fase dispersa muito menor do que o tamanho do poro. Se o tamanho de gota da fase dispersa é da mesma ordem de magnitude do tamanho de poro, as gotas podem aglomera-se e particularmente podem bloquear o fluxo através dos poros. Este regime de fluxo pode ser utilizado para controlar a mobilidade do líquido injetado, conduzindo a um fator de recuperação maior. Neste trabalho, experimentos de deslocamento de óleo foram executados em um corpo de prova de arenito. Os resultados mostram que a injeção de uma emulsão mudou o fator de recuperação de óleo, elevando este desde 40%, obtido só por injeção de água, ate um valor aproximado de 75%, seja em modo primario ou depois do influxo da água.
Water injection is a common method to improve the reservoir sweep and maintain its pressure. The e±ciency of oil recovery in the case of heavy oils is limited by the high mobility ratio between the injected water and oil. A method of reducing the problem related to the high viscosity ratio is by polymer solution injection. However, the liquid-rock interaction, the large volume and the associated cost of polymer may make this technique not applicable in the case of giant fields. Different enhanced oil recovery methods are being developed and studied as alternatives to polymer injection. Dispersion injection, in particular oil-water emulsion injection, has been tried with relative success as an enhanced oil recovery method, but the techniques are not fully developed or understood. The use of such methods requires a complete analysis of the different flow regimes of emulsions inside the porous space of a reservoir. Most analyses of flow of emulsion in a porous media use a macroscopic description. This approach is only valid for dilute emulsion which the size of the disperse phase is much smaller of the pore throat. If the drop size of the disperse phase is of the same order of magnitude of the pore size, the drops may agglomerate and partially block the flow through pores. This flow regime may be used to control the mobility of the injected liquid, leading to higher recovery factor. In this work, experiments of oil displacement were performed in a sandstone plug. The results show that injection of an emulsion changed the oil recovery factor, raising it from approximately 40%, obtained with water injection alone, to approximately 75%, whether in primary mode or after water flooding.
5
Bristow, Robert Philip. "Micromodels of immiscible two-phase flow in porous media." Thesis, University of Cambridge, 1987. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.235763.
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The research is a study on the microscopic scale of the immiscible displacement of oil by water in a porous medium such as sandstone. Of particular interest (with application to the oil industry) are the residual saturation of oil, the permeability to water at residual oil saturation and the maximum trapped blob size. Initially the effects of gravity, surface tension and distribution of pore sizes were studied in a computer simulation of a buoyancy driven, quasi-static invasion. The rock was modelled as a three-dimensional lattice of spherical pores connected by narrow cylindrical throats. With the rock water-wet, the tendency of the surface tension to favour the invasion of smaller pores led to a larger residual oil saturation by pore volume than by pore numbers. Also bourne out were some scaling arguments based on percolation theory for the maximum trapped blob size as a function of the relative strength of buoyancy and surface tension forces. The second part of the research investigated the interaction of viscous and surface tension forces. As this is a much more complicated problem, involving the solution of flow equations, the invasion process was first simulated with exact equations of motion on small networks (up to 10x10), where surface tension effects dominate. From these simulations a simplified set of rules was developed to determine which pore in a locality on the oil-water interface is invaded and how long the invasion takes. These rules include a viscous correction to the dominant surface tension forces. Finally, some theory has been developed for the inclusion of the small-scale analysis into a larger model, allowing a full simulation of the viscous dominated invasion to be performed.
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Gholamhosseini, Masoud. "Visualization of water/oil displacement in porous media in the presence of chemical reaction." Thesis, University of Ottawa (Canada), 1991. http://hdl.handle.net/10393/7838.
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In enhanced oil recovery, low interfacial tension, optimum wettability condition, high pH value, and the electric charge density at the interface can improve the oil recovery percentage appreciably. However, the addition of sodium hydroxide changes the interfacial tension to an ultra-low value. Interfacial tension decreases as a result of the interfacial reaction between the surface active species in the oleic phase and the caustic in the aqueous phase. The surface active species also provide favorable wettability conditions and interfacial activity which improves the recovery percentage. This study has investigated the effects of caustic concentration in the aqueous phase on the recovery percentage, and on the displacement pattern in a radial cell. The caustic solutions were employed as the displacing phase being brought into contact with the acidic oil in the cell. The displacing aqueous phase contained different concentrations of sodium hydroxide ranging from 0.0 mM to 25 mM, and the displaced phase was a light paraffin oil containing 10 mM linoleic acid. In this research, the effect of flowrate on oil recovery percentage was also examined. (Abstract shortened by UMI.)
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Al-Zaidi, Ebraheam Saheb Azeaz. "Experimental studies on displacements of CO₂ in sandstone core samples." Thesis, University of Edinburgh, 2018. http://hdl.handle.net/1842/33183.
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CO2 sequestration is a promising strategy to reduce the emissions of CO2 concentration in the atmosphere, to enhance hydrocarbon production, and/or to extract geothermal heat. The target formations can be deep saline aquifers, abandoned or depleted hydrocarbon reservoirs, and/or coal bed seams or even deep oceanic waters. Thus, the potential formations for CO2 sequestration and EOR (enhanced oil recovery) projects can vary broadly in pressure and temperature conditions from deep and cold where CO2 can exist in a liquid state to shallow and warm where CO2 can exist in a gaseous state, and to deep and hot where CO2 can exist in a supercritical state. The injection, transport and displacement of CO2 in these formations involves the flow of CO2 in subsurface rocks which already contain water and/or oil, i.e. multiphase flow occurs. Deepening our understanding about multiphase flow characteristics will help us building models that can predict multiphase flow behaviour, designing sequestration and EOR programmes, and selecting appropriate formations for CO2 sequestration more accurately. However, multiphase flow in porous media is a complex process and mainly governed by the interfacial interactions between the injected CO2, formation water, and formation rock in host formation (e.g. interfacial tension, wettability, capillarity, and mass transfer across the interface), and by the capillary , viscous, buoyant, gravity, diffusive, and inertial forces; some of these forces can be neglected based on the rock-fluid properties and the configuration of the model investigated. The most influential forces are the capillary ones as they are responsible for the entrapment of about 70% of the total oil in place, which is left behind primary and secondary production processes. During CO2 injection in subsurface formations, at early stages, most of the injected CO2 (as a non-wetting phase) will displace the formation water/oil (as a wetting phase) in a drainage immiscible displacement. Later, the formation water/oil will push back the injected CO2 in an imbibition displacement. Generally, the main concern for most of the CO2 sequestration projects is the storage capacity and the security of the target formations, which directly influenced by the dynamic of CO2 flow within these formations. Any change in the state of the injected CO2 as well as the subsurface conditions (e.g. pressure, temperature, injection rate and its duration), properties of the injected and present fluids (e.g. brine composition and concentration, and viscosity and density), and properties of the rock formation (e.g. mineral composition, pore size distribution, porosity, permeability, and wettability) will have a direct impact on the interfacial interactions, capillary forces and viscous forces, which, in turn, will have a direct influence on the injection, displacement, migration, storage capacity and integrity of CO2. Nevertheless, despite their high importance, investigations have widely overlooked the impact of CO2 the phase as well as the operational conditions on multiphase characteristics during CO2 geo-sequestration and CO2 enhanced oil recovery processes. In this PhD project, unsteady-state drainage and imbibition investigations have been performed under a gaseous, liquid, or supercritical CO2 condition to evaluate the significance of the effects that a number of important parameters (namely CO2 phase, fluid pressure, temperature, salinity, and CO2 injection rate) can have on the multiphase flow characteristics (such as differential pressure profile, production profile, displacement efficiency, and endpoint CO2 effective (relative) permeability). The study sheds more light on the impact of capillary and viscous forces on multiphase flow characteristics and shows the conditions when capillary or viscous forces dominate the flow. Up to date, there has been no such experimental data presented in the literature on the potential effects of these parameters on the multiphase flow characteristics when CO2 is injected into a gaseous, liquid, or supercritical state. The first main part of this research deals with gaseous, liquid, and supercritical CO2- water/brine drainage displacements. These displacements have been conducted by injecting CO2 into a water or brine-saturated sandstone core sample under either a gaseous, liquid or supercritical state. The results reveal a moderate to considerable impact of the fluid pressure, temperature, salinity and injection rate on the differential pressure profile, production profile, displacement efficiency, and endpoint CO2 effective (relative) permeability). The results show that the extent and the trend of the impact depend significantly on the state of the injected CO2. For gaseous CO2-water drainage displacements, the results showed that the extent of the impact of the experimental temperature and CO2 injection rate on multiphase flow characteristics, i.e. the differential pressure profile, production profile (i.e. cumulative produced volumes), endpoint relative permeability of CO2 (KrCO2) and residual water saturation (Swr) is a function of the associated fluid pressure. This indicates that for formations where CO2 can exist in a gaseous state, fluid pressure has more influence on multiphase flow characteristics in comparison to other parameters investigated. Overall, the increase in fluid pressure (40-70 bar), temperature (29-45 °C), and CO2 injection rate (0.1-2 ml/min) caused an increase in the differential pressure. The increase in differential pressure with increasing fluid pressure and injection rate indicate that viscous forces dominate the multi-phase flow. Nevertheless, increasing the differential pressure with temperature indicates that capillary forces dominate the multi-phase flow as viscous forces are expected to decrease with this increasing temperature. Capillary forces have a direct impact on the entry pressure and capillary number. Therefore, reducing the impact of capillary forces with increasing pressure and injection rate can ease the upward migration of CO2 (thereby, affecting the storage capacity and integrity of the sequestered CO2) and enhance displacement efficiency. On the other hand, increasing the impact of the capillary force with increasing temperature can result in a more secure storage of CO2 and a reduction in the displacement efficiency. Nevertheless, the change in pressure and temperature can also have a direct impact on storage capacity and security of CO2 due to their impact on density and hence on buoyancy forces. Thus, in order to decide the extent of change in storage capacity and security of CO2 with the change in the above-investigated parameters, a qualitative study is required to determine the size of the change in both capillary forces and buoyancy forces. The data showed a significant influence of the capillary forces on the pressure and production profiles. The capillary forces produced high oscillations in the pressure and production profiles while the increase in viscous forces impeded the appearance of these oscillations. The appearance and frequency of these oscillations depend on the fluid pressure, temperature, and CO2 injection rate but to different extents. The appearance of the oscillations can increase CO2 residual saturation due to the re-imbibition process accompanied with these oscillations, thereby increasing storage capacity and integrity of the injected CO2. The differential pressure required to open the blocked flow channels during these oscillations can be useful in calculating the largest effective pore diameters and hence the sealing efficiency of the rock. Swr was in ranges of 0.38-0.42 while KrCO2 was found to be less than 0.25 under our experimental conditions. Increasing fluid pressure, temperature, and CO2 injection rate resulted in an increase in the KrCO2, displacement efficiency (i.e. a reduction in the Swr), and cumulative produced volumes. For liquid CO2-water drainage displacements, the increase in fluid pressure (60-70 bar), CO2 injection rate (0.4-1ml/min) and salinity (1% NaCl, 5% NaCl, and 1% CaCl2) generated an increase in the differential pressure; the highest increase occurred with increasing the injection rate and the lowest with increasing the salinity. On the other hand, on the whole, increasing temperature (20-29 °C) led to a reduction in the differential pressure apart from the gradual increase occurred at the end of flooding.
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Fannir, Jamal. "Stability of the two-phase displacement in porous media studied by MRI techniques." Electronic Thesis or Diss., Université de Lorraine, 2019. http://www.theses.fr/2019LORR0330.
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Il est important de comprendre les forces motrices qui contrôlent l'écoulement de deux fluides immiscibles dans un milieu poreux. En effet, il existe une large gamme d'applications des écoulements diphasiques en milieux poreux, notamment ceux qui concernent la récupération assistée du pétrole (EOR). Le développement des techniques quantitatives d'imagerie par résonance magnétique (IRM) ouvre de nouvelles possibilités pour étudier et caractériser les flux multiphasiques en milieu poreux. Ce travail s’intéresse précisément à décrire le déplacement de deux fluides immiscibles (eau-huile) au sein d’un milieu poreux en utilisant les techniques d’IRM. Le milieu poreux est initialement saturé d’huile qu’on vient déplacer en injectant de l’eau par le bas, l’huile et l’eau pouvant s’évacuer par le haut. L’objectif général de l’étude est de déterminer le déplacement et la déformation du front (eau-huile) au cours du temps, et de préciser les mécanismes de piégeage des phases. Des expériences sont menées sur deux modèles poreux. L’un mouillant à l’huile consiste en un empilement de petites billes en polystyrène (0,4 mm < dp < 0,6 mm), l’autre mouillant à l’eau est un sable légèrement compacté (0,02 mm < dp < 0,50 mm). Nous avons utilisé un dispositif de micro-imagerie RMN fonctionnant à 14 T (résonance 1H à 600 MHz) pour acquérir des images à haute résolution (0.2 mm) à l’intérieur des milieux poreux au cours du déplacement des deux fluides. Les résultats obtenus ont montré que le profil de saturation en huile est fortement influencé par les propriétés du matériau poreux, telles que la porosité et la perméabilité de l'échantillon, le mouillage des phases, le débit d'injection de l’eau ou encore l’hétérogénéité de la matrice solide. L'influence du débit d’injection d’eau sur la saturation résiduelle en huile a été plus particulièrement étudiée. Les résultats expérimentaux permettent une compréhension fine du déplacement de deux fluides non miscibles pour deux types de milieux poreux, qui se différencient principalement par les effets de la mouillabilité. Dans le même temps, une simulation numérique du déplacement vertical ascendant de l’huile poussée par de l’eau dans une colonne poreuse a été réalisée et les résultats ont été comparés à nos expériences sous IRMIt is important to understand the driving forces that control the flow of two immiscible fluids in a porous medium. Indeed, there is a wide range of applications of two-phase flows in porous media, especially those relating to enhanced oil recovery (EOR). The development of quantitative magnetic resonance imaging (MRI) techniques opens up new possibilities for studying and characterizing multiphase flows in porous media. This work is specifically concerned with describing the displacement of two immiscible fluids (water-oil) in a porous medium using MRI techniques. The porous medium is initially saturated with oil which is displaced by injecting water from below, oil and water can be evacuated from above. The general objective of the study is to determine the displacement and the deformation of the front (water-oil) over time, and to specify the trapping mechanisms of the phases. Experiments are conducted on two porous models. One oil wetting consists of a stack of small polystyrene beads (0.4 mm < dp < 0.6 mm), the other wetting with water is a slightly compacted sand (0.02 mm < dp <0.50 mm). We used a 14 T NMR micro-imaging device (1H resonance at 600 MHz) to acquire high resolution images (0.2 mm) inside the porous media during the movement of the two fluids. The results obtained showed that the oil saturation profile is strongly influenced by the properties of the porous material, such as the porosity and the permeability of the sample, the wetting of the phases, the injection rate of the water or even the heterogeneity of the solid matrix. The influence of the water injection flow rate on the residual saturation of oil has been studied more particularly. The experimental results allow a fine understanding of the displacement of two immiscible fluids for two types of porous media, which mainly differ by the effects of wettability. At the same time, a numerical simulation of the upward vertical displacement of oil pushed by water in a porous column was performed and the results compared to our MRI experiments
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SOUZA, Márcio Rodrigo de Araújo. "Simulação Numérica de Escoamento Bifásico em reservatório de Petróleo Heterogêneos e Anisotrópicos utilizando um Método de Volumes Finitos “Verdadeiramente” Multidimensional com Aproximação de Alta Ordem." Universidade Federal de Pernambuco, 2015. https://repositorio.ufpe.br/handle/123456789/17248.
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Sob certas hipóteses simplificadoras, o modelo matemático que descreve o escoamento de água e óleo em reservatórios de petróleo pode ser representado por um sistema não linear de Equações Diferenciais Parciais composto por uma equação elíptica de pressão (fluxo) e uma equação hiperbólica de saturação (transporte). Devido a complexidades na modelagem de ambientes deposicionais, nos quais são incluídos camadas inclinadas, canais, falhas e poços inclinados, há uma dificuldade de se construir um modelo que represente adequadamente certas características dos reservatórios, especialmente quando malhas estruturadas são usadas (cartesianas ou corner point). Além disso, a modelagem do escoamento multifásico nessas estruturas geológicas incluem descontinuidades na variável e instabilidades no escoamento, associadas à elevadas razões de mobilidade e efeitos de orientação de malha. Isso representa um grande desafio do ponto de vista numérico. No presente trabalho, uma formulação fundamentada no Método de Volumes Finitos é estudada e proposta para discretizar as equações elíptica de pressão e hiperbólica de saturação. Para resolver a equação de pressão três formulações robustas, com aproximação dos fluxos por múltiplos pontos são estudadas. Essas formulações são abeis para lidar com tensores de permeabilidade completos e malhas poligonais arbitrárias, sendo portanto uma generalização de métodos mais tradicionais com aproximação do fluxo por apenas dois pontos. A discretização da equação de saturação é feita com duas abordagens com característica multidimensional. Em uma abordagem mais convencional, os fluxos numéricos são extrapolados diretamente nas superfícies de controle por uma aproximação de alta resolução no espaço (2ª a 4ª ordem) usando uma estratégia do tipo MUSCL. Uma estratégia baseada na Técnica de Mínimos Quadrados é usada para a reconstrução polinomial. Em uma segunda abordagem, uma variação de uma esquema numérico Verdadeiramente Multidimensional é proposto. Esse esquema diminui o efeito de orientação de malha, especialmente para malhas ortogonais, mesmo embora alguma falta de robustez possa ser observada pra malhas excessivamente distorcidas. Nesse tipo de formulação, os fluxos numéricos são calculados de uma forma multidimensional. Consiste em uma combinação convexa de valores de saturação ou fluxo fracionário, seguindo a orientação do escoamento através do domínio computacional. No entanto, a maioria dos esquemas numéricos achados na literatura tem aproximação apenas de primeira ordem no espaço e requer uma solução implícita de sistemas algébricos locais. Adicionalmente, no presente texto, uma forma modificada desses esquemas “Verdadeiramente” Multidimensionais é proposta em um contexto centrado na célula. Nesse caso, os fluxos numéricos multidimensionais são calculados explicitamente usando aproximações de alta ordem no espaço. Para o esquema proposto, a robustez e o caráter multidimensional também leva em conta a distorção da malha por meio de uma ponderação adaptativa. Essa ponderação regula a característica multidimensional da formulação de acordo com a distorção da malha. Claramente, os efeitos de orientação de malha são reduzidos. A supressão de oscilações espúrias, típicas de aproximações de alta ordem, são obtidas usando, pela primeira vez no contexto de simulação de reservatórios, uma estratégia de limitação multidimensional ou Multidimensional Limiting Process (MLP). Essa estratégia garante soluções monótonas e podem ser usadas em qualquer malha poligonal, sendo naturalmente aplicada em aproximações de ordem arbitrária. Por fim, de modo a garantir soluções convergentes, mesmo para problemas tipicamente não convexos, associados ao modelo de Buckley-Leverett, uma estratégia robusta de correção de entropia é empregada. O desempenho dessas formulações é verificado com a solução de problemas relevantes achados na literatura.
Under certain simplifying assumptions, the problem that describes the fluid flow of oil and water in heterogeneous and anisotropic petroleum reservoir can be described by a system of non-linear partial differential equations that comprises an elliptic pressure equation (flow) and a hyperbolic saturation equation (transport). Due to the modeling of complex depositional environments, including inclined laminated layers, channels, fractures, faults and the geometrical modeling of deviated wells, it is difficult to properly build and handle the Reservoir Characterization Process (RCM), particularly by using structured meshes (cartesian or corner point), which is the current standard in petroleum reservoir simulators. Besides, the multiphase flow in such geological structures includes the proper modeling of water saturation shocks and flow instabilities associated to high mobility ratios and Grid Orientation Effects (GOE), posing a great challenge from a numerical point of view. In this work, a Full Finite Volume Formulation is studied and proposed to discretize both, the elliptic pressure and the hyperbolic saturation equations. To solve the pressure equation, we study and use three robust Multipoint Flux Approximation Methods (MPFA) that are able to deal with full permeability tensors and arbitrary polygonal meshes, making it relatively easy to handle complex geological structures, inclined wells and mesh adaptivity in a natural way. To discretize the saturation equation, two different multidimensional approaches are employed. In a more conventional approach, the numerical fluxes are extrapolated directly on the control surfaces for a higher resolution approximation in space (2nd to 4th order) by a MUSCL (Monotone Upstream Centered Scheme for Conservation Laws) procedure. A least squares based strategy is employed for the polynomial reconstruction. In a second approach, a variation of a “Truly” Multidimensional Finite Volume method is proposed. This scheme diminishes GOE, especially for orthogonal grids, even though some lack of robustness can be observed for extremely distorted meshes. In this type of scheme, the numerical flux is computed in each control surface in a multidimensional way, by a convex combination of the saturation or the fractional flow values, following the approximate wave orientation throughout the computational domain. However, the majority of the schemes found in literature is only first order accurate in space and demand the implicit solution of local conservation problems. In the present text, a Modified Truly Multidimensional Finite Volume Method (MTM-FVM) is proposed in a cell centered context. The truly multidimensional numerical fluxes are explicitly computed using higher order accuracy in space. For the proposed scheme, the robustness and the multidimensional character of the aforementioned MTM-FVM explicitly takes into account the angular distortion of the computational mesh by means of an adaptive weight, that tunes the multidimensional character of the formulation according to the grid distortion, clearly diminishing GOE. The suppression of the spurious oscillations, typical from higher order schemes, is achieved by using for the first time in the context of reservoir simulation a Multidimensional Limiting Process (MLP). The MLP strategy formally guarantees monotone solutions and can be used with any polygonal mesh and arbitrary orders of approximation. Finally, in order to guarantee physically meaningful solutions, a robust “entropy fix” strategy is employed. This produces convergent solutions even for the typical non-convex flux functions that are associated to the Buckley-Leverett problem. The performance of the proposed full finite volume formulation is verified by solving some relevant benchmark problems.
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Ligiero, Leticia. "Crude oil/water interface characterization and its relation to water-in-oil emulsion stability." Thesis, Pau, 2017. http://www.theses.fr/2017PAUU3048/document.
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La formation d’émulsions stables eau/huile lors des processus de récupération et de raffinage du pétrole peut impacter défavorablement l’efficacité de ces opérations. Bien que résines et asphaltènes soient généralement tenus pour responsables de la stabilité des émulsions, la composition exacte des molécules présentes à l’interface eau/huile est en réalité assez mal connue. L’identification de ces molécules et la connaissance de leur influence sur la propriété des interfaces est une étape nécessaire pour mieux prédire les problèmes de stabilité des émulsions dans l’industrie pétrolière. Cette thèse présente des résultats de caractérisation analytique par GPC-ICP-HRMS et FTMS du matériel interfacial (IM) extrait de quatre bruts différents et des espèces transférées dans la phase aqueuse lorsque ces bruts contactent l’eau, ainsi que des propriétés rhéologiques en cisaillement et en dilatation des interfaces eau/huile en présence de ces composés. Les bruts ont été choisis en raison de leur capacité à former des émulsions eau-dans-huile de stabilités différentes. Les mesures d’élasticité de cisaillement ont montré que la majorité des interfaces eau/huile étudiées formaient une structure élastique susceptible de fausser la mesure du module dilatationnel de Gibbs par la méthode d’analyse du profil de goutte. Néanmoins, nous montrons à l’aide de simulations numériques que le module apparent Eapp mesuré dans un tel cas est proche de la somme du module de Gibbs et du module de cisaillement (G) multiplié par 2 du réseau interfacial dès lors que G reste petit (G < 10 mN/m), ce qui est très souvent le cas puisque nous observons que le réseau interfacial formé se rompt lors des expériences de dilatation. Une équation phénoménologique a été développée permettant d’attribuer un temps de relaxation unique aux processus de relaxation qui ont lieu aux interfaces eau/huile, ce qui nous permet de classer les différents systèmes entre eux. Nous avons également étudié les IM extraits des bruts selon la technique chromatographique dite « wet silica method » récemment développée par Jarvis et al. (Energy Fuels, 2015). Les expériences de rhéologie interfaciale confirment que cette méthode permet d’extraire les composés les plus tensioactifs présents aux interfaces eau-brut. Les analyses chimiques montrent que les IM sont partiellement composés d’asphaltènes et suggèrent que les composés contenant du soufre jouent un rôle important dans la stabilité des émulsions. Enfin, nous avons trouvé que les composés hydrosolubles transférés du brut à l’eau ont un comportement bénéfique, dans le sens où leur présence rend les émulsions eau-dans-brut moins stables. L’analyse FTMS de ces composés montre qu’ils appartiennent aux classes d’hétéroatomes suivant : O2, O3, S1, OS et O2S2 et qu’une partie de ces composés appartient à la classe des asphaltènesCrude oil recovery and refining operations rely on high consumption water processes, which may induce the formation of stable water-in-oil emulsions. Although asphaltenes and resins are known to influence the stability of crude oil emulsions, much is still unknown about the real composition of the w/o interfacial layer. Therefore, identifying these molecules and understanding their impact on the w/o interfacial properties are key points for better predicting emulsion problems in the petroleum industry. This thesis presents results on water/oil (w/o) interface characterization using shear and dilatational interfacial rheology as well as results on molecular characterization (GPC-ICP-HRMS and FTMS) of the crude oil interfacial material (IM) and of the amphiphilic crude oil species, which are transferred to the aqueous phase during the emulsification process. Four crude oils forming w/o emulsions of different stability were used in this study. Shear interfacial rheology experiments showed that most of the studied w/o interfaces were capable of forming an elastic interfacial network exhibiting shear elasticity G. A non-null G value interferes on drop deformation and thus on drop shape analysis (DSA) results. Nevertheless, the dilatational elasticity modulus measured by DSA (Eapp) was found to be representative of the sum of the Gibbs modulus plus 2 times G, as long as G 10 mN/m. This condition is generally satisfied since the asphaltene network is broken during dilatational experiments. Consequently, Eapp gives a good approximation of the real Gibbs modulus of the interface. A new phenomenological equation was proposed to fit the dilatational Eapp experimental data, allowing the assignment of a unique characteristic time to describe the w/o interfacial relaxation process and thus sample comparison. The IM of the crude oils was extracted using the “wet silica method” recently developed by Jarvis et al. (Energy Fuels, 2015). Results showed that this method collects the most-surface active compounds that adsorb in the time frame of the extraction procedure. Successive extractions collected species that were larger and less concentrated in the crude oil, but with higher adsorption energies. Molecular characterization revealed that the IM was partially composed of asphaltene compounds, and suggested that sulfur-containing compounds may play a major role in emulsion stability. Lastly, the oil-to-water transferred species were proven to impact the w/o interfacial properties and emulsion stability. Interestingly, concentrating these water-soluble species led to more efficient crude oil dehydration. FTMS analysis of the transferred species revealed that part of the compounds belonged to O2, O3, S1, OS and O2S2 heteroatom classes, and some of them have an asphaltene-type of molecules classification
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Hernandez, Barral A. "Stratified wavy oil-water flows." Thesis, University College London (University of London), 2014. http://discovery.ucl.ac.uk/1448338/.
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The structure of the oil-water interface of stratified flows in a 38 mm ID pipe is investigated in this Thesis with double-wire conductance probes. The fluids used – tap water and Exxsol™ D140 oil (ρo = 830 kgm-3; μo = 0.0055 kgm-1s-1) – are pumped into the facility and brought together in a “Y” inlet section, designed to minimize the mixing between phases (r = 0.6 – 2.4; Umix = 0.5 – 2.5 ms-1). The piping is made of acrylic and the flow was observed with the aid of high-speed imaging. The waves seen on the oil-water interface further downstream the inlet consists of small 3D fluctuations, rather than 2D structures. Conductance probes are used to investigate the oil-water interface in cases where clear wavy structures cannot be followed or analyzed. The signal of interface height in time is found to be stationary and follow a Gaussian distribution when the signal is collected at 256 Hz during 4 min. Based on these properties, a thorough methodology for analysis is presented, which allows estimating time-average parameters of the flow and the power spectrum of the interface. This analysis reveals that, in fully-developed flow conditions, oil and water phases show very little slip and tend to flow both at roughly the mixture velocity regardless of the flow conditions. The power spectrum detects a unique frequency of 19 Hz, but reveals that mechanic vibrations propagating through the facility are a major contribution to the structure of the interface. The 19 Hz frequency corresponds to clearly identifiable waves that develop at the inlet section only if the oil-to-water input ratio is different from 1. The power spectrum at the inlet tends to be dominated by this frequency. This finding is verified with the information of high-speed images. Wave characteristics and their evolution along the inlet are determined from high-speed images collected with a Phantom Miro 4 camera at 1,000 – 1,200 fps. The theoretical analysis of the stability of inlet waves suggests that their origin is a Kelvin-Helmholtz instability and characterizes the waves as dynamic in nature. The two types of oil-water interfaces seen (i.e. that at the inlet with 2D waves and that downstream the pipe with small 3D contributions) are discussed in this Thesis at length and abundant details are given.
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Gutkowski, Sarah. "Water-in-oil and oil-in-water emulsions stabilized by octenylsuccinic anhydride modified starch and adsorption of modified starch at emulsified oil/water interfaces." Thesis, Kansas State University, 2016. http://hdl.handle.net/2097/32842.
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Master of ScienceDepartment of Grain Science and Industry
Yong Cheng Shi
Emulsions are utilized to help control phase separation and are found in many products ranging from food to pharmaceuticals. Because of the hydrophobic properties of its functional group, octenylsuccinic anhydride (OSA) modified starch is commonly used in oil in water (o/w) emulsions. The first objective of this study was to investigate if OSA modified starch could be used in water in oil (w/o) emulsions. Experiments were designed to determine the effects of concentrations of OS starch, mineral oil and water on the stability of emulsions. High shear homogenizers and a microfluidizer were used to create stable o/w and w/o emulsions. The stability of the emulsions was examined by optical microscopy, gravitational separation, and electrical conductivity. The microfluidized samples always had a longer stability (days), no gravitational separation and did not exceed three microns, compared to the unmicrofluidized (o/w and w/o) samples. Stable (over 100 days of stability) o/w emulsions could be made without a microfluidizer if the emulsion was made of 2, 60, 38% (w/w) oil, water, starch, respectively. Stable o/w emulsions prepared with a microfluidizer were stable for over 100 days. The o/w emulsion prepared by 8, 66, 26% oil, water, and starch, respectively, was stable for over 600 days. The most stable w/o unmicrofluidized sample was made of 52, 22, 26% oil, water, starch, respectively, with a stability of 240 days. For the w/o emulsions from the microfluidizer, the most stable emulsion was made of 52, 34, 14% oil, water, starch, respectively, with a stability of 250 days. The most stable emulsion that could flow (under the 30,000 cP) was 56, 38, 6% oil, water, starch, respectively, with a stability of 150 days. The statistical mixture experiments models successfully predicted the stability for other ratios of oil, water, and starch for o/w and w/o emulsions. The second objective of the study was to determine the concentration of modified OS starch adsorbed to the mineral oil and the water phases for oil-in-water (o/w) emulsions. The percentage of the starch adsorbed at the mineral oil phase was determined and compared when different ratios of starch to oil and water were used. When the ratio of oil:starch was decreased, the emulsion particle size decreased. As the starch content increased, the percent starch adsorbed onto oil based on total oil increased. The adsorption yield and the level of starch in the emulsion did not show a trend. The surface load ranged from 1.6 to 6.98 mg/m². The sample with the highest concentration of starch (26 g/ml) had the highest surface load (6.98 mg/m²) and samples with low concentrations of starch (0.84 and 1.68 g/ml) had the second and third highest surface loads (6.82 and 4.70 mg/m², respectively). The ratio of oil:starch was increased to determine the emulsifying capacity. A high emulsifying capacity was achieved. Samples with an oil:starch ratio of 3:1 were stable for over 80 days while other samples with oil:starch ratios of 5:1 and 6:1 could be stable for one week.
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Evans, R. "Water quality requirement for oil industry water injection projects." Thesis, Cranfield University, 1992. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.333540.
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Dale, Sara E. "Physicochemical processes at oil/water interfaces." Thesis, University of Warwick, 2008. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.487805.
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Warisnoicharoen, Warangkana. "Pharmaceutical nonionic oil-in-water microemulsions." Thesis, King's College London (University of London), 1998. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.286790.
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NICOLEIT, CARLA NUNES DE OLIVEIRA. "RHEOLOGICAL CHARACTERIZATION OF WATER-OIL EMULSIONS." PONTIFÍCIA UNIVERSIDADE CATÓLICA DO RIO DE JANEIRO, 2014. http://www.maxwell.vrac.puc-rio.br/Busca_etds.php?strSecao=resultado&nrSeq=24874@1.
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PONTIFÍCIA UNIVERSIDADE CATÓLICA DO RIO DE JANEIROCOORDENAÇÃO DE APERFEIÇOAMENTO DO PESSOAL DE ENSINO SUPERIOR
PROGRAMA DE EXCELENCIA ACADEMICA
As emulsões se formam naturalmente nos reservatórios e durante a exploração do petróleo. A presença de agentes tensoativos, principalmente nos óleos pesados, ajuda na sua estabilização. A alta viscosidade dos óleos pesados gera uma maior dificuldade da sua exploração, e por isso o conhecimento da emulsão formada com esse óleo reduz seu custo de produção. O tipo de emulsão formada, o tamanho de gota e sua distribuição afetam o comportamento reológico da emulsão. Neste trabalho, emulsões foram criadas a partir de um óleo sintético newtoniano de viscosidade próxima à de um óleo pesado. A água utilizada na formação das emulsões era deionizada e com diferentes surfactantes. As características reológicas das emulsões foram medidas. Em sua maioria as caracterizações reológicas foram feitas a 10 graus Celcius, através de testes oscilatórios de pequena amplitude, testes de escoamento permanente, e testes de fluência. Todas as emulsões eram de água em óleo, formadas com 80 por cento de óleo. O tamanho das gotas de água era da ordem de 10 microns. As emulsões apresentaram comportamento elástico-dominante no regime viscoelástico linear. Os resultados dos testes de regime permanente mostraram que a viscosidade das emulsões é bem descrita pelo modelo de Herschel-Bulkley. Foram feitos testes de regime permanente também a 4 graus Celcius, para investigar a influência da temperatura na viscosidade, mas nenhuma mudança significativa foi observada. Finalmente, testes de fluência foram feitos com o objetivo de determinar a tensão limite de escoamento das emulsões.
Emulsions are formed naturally in the reservoirs and during oil exploration, and the surfactants primarily present in heavy oil, helps its stabilization. The high viscosity of heavy oil generates greater difficulty on the operation, so the knowledge of the emulsion formed with this kind of oil reduces its cost of production. The type of emulsion formed, the droplet size and its distribution affect the rheology of the emulsion. in this work, emulsions were created with a Newtonian synthetic oil whose viscosity is close to the one of a heavy oil. The water employed in the emulsion preparation was deionized and contained different surfactants. Rheological characterizations were performed at 10 degrees Celcius in most cases, and included small-amplitude oscillatory tests, steady-state flow tests and creep tests. All emulsions were oil-in-water, and were composed of 80 per cent of oil. The water droplet size was about 10 microns. The emulsions exhibited a predominantly elastic behavior in the linear viscoelastic regime. The steady-state flow test results showed that the emulsions possess tests and the results showed that the emulsion viscosity is well described by the Herschel-Bulkley model. Some tests were also done at 4 degrees Celcius, to investigate the influence of temperature on viscosity, but no significant change was found. Finally, creep tests were performed to determine the yield stress of the emulsions.
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Kida, Yuko. "Supercritical Water desulfurization of crude oil." Thesis, Massachusetts Institute of Technology, 2014. http://hdl.handle.net/1721.1/88904.
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Thesis: Ph. D., Massachusetts Institute of Technology, Department of Chemical Engineering, 2014.Cataloged from PDF version of thesis.
Includes bibliographical references.
Supercritical Water (SCW) desulfurization was investigated for both model sulfur compounds and Arab Heavy crude. In part 1, the reactions of alkyl sulfides in SCW were studied. During hexyl sulfide decomposition in SCW, pentane and CO+CO₂ were detected in addition to the expected six-carbon products. A multi-step reaction sequence for hexyl sulfide reacting with SCW is proposed which explains the surprising products. Intermediate studies were performed to confirm that the key intermediate hexanal forms and rapidly decomposes to pentane and CO. In part 2, Arab Heavy crude was treated with SCW and analyzed with comprehensive gas chromatography (GCxGC) coupled with two detectors, sulfur chemiluminescence detector (SCD) and a flame ionization detector (FID). SCD is a sulfur specific detector that allowed detailed analysis of the reactions that occur during SCW treatment of real fuel mixtures. It was shown that SCW treatment had two effects on sulfur compounds: cracking of heavy sulfur compounds into smaller compounds, mainly benzothiophenes (BT) and dibenziophenes (DBT), and cracking of long alkyl chains on these BTs and DBTs causing a shift to lower molecular weight BTs and DBTs. SCW was found to be ineffective in breaking the stable aromatic rings of these thiophenic compounds. Work in this thesis shed light into molecular level reactions during SCW treatment rather than changes in bulk properties which are often reported in work in the field of SCW desulfurization.
by Yuko Kida.
Ph. D.
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Teare, Declan O. H. "Cross-linked 'silicone oil'/water emulsions." Thesis, University of Bristol, 1997. http://hdl.handle.net/1983/0b48bef9-20fa-4ff4-a903-94c567606303.
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Thoraval, Carole. "Rheological properties of oil-soluble surfactants at the oil/water interfaces." Thesis, University of Reading, 1996. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.339483.
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Al, Aufi Mohammed. "Treating oil-field co-produced water by forward osmosis for low-salinity water injection and enhanced oil recovery." Thesis, University of Surrey, 2017. http://epubs.surrey.ac.uk/842050/.
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Co-produced water re-injection is a mature recovery technique for oil fields. Co-produced water that is not re-injected is the largest wastage stream in the oil industry. Handling, treatment and management (especially re-injection back into the reservoir) is an expensive operation. PWRI is a secondary oil recovery method with a small recovery factor in the range of 15-25% and contributes to many surface and subsurface issues, e.g., scaling and reservoir plugging, resulting in the decline of water injectivity, and thus lower oil recovery. This reduction, of course, impinges significantly on the revenue stream of major oil corporations. However, low-salinity (LowSal) water injection is an emerging method that boosts oil recovery by reducing the downsides of produced water re-injection. Using forward osmosis to produce low-salinity water for injection is a novel idea, in which the co-produced water will be the draw solution. In this concept, low-salinity water from water wells (brackish water) is used as the feed to dilute the co-produced water. The diluted co-produced water will then be re-injected as LowSal water. The obviously cheaper alternative of direct dilution of the co-produced water with the brackish water might not produce a water compatible with the oil reservoir in both ionic composition and strength. Data have been collected from different oil fields with various co-produced water and formation characteristics. Different co-produced water treatments were observed in each oil field due to differences in co-produced water chemistry. The water sample for analysis was taken at the skim tanks prior to the water injection stage. A theoretical resistance-in-series model for the forward osmosis stage is presented, which has been adapted from the literature, which incorporates the mass transfer equations, in which the boundary layer and thin-film theory for the membrane intrinsic layers are integrated. An improved shell mass transfer correlation is introduced in addition to the incorporation of a modified reflection coefficient into the resistance-in-series model. The collected data were then incorporated into the theoretical model to calculate and evaluate the forward osmosis performance and, in turn, the water chemistry before re-injection. A forward osmosis rig has been erected to use the latest hollow fibre membrane supplied by the Toyobo Company (Japan). Water and solute flux were measured to validate the model estimations. The model estimated results were at 95% confidence to the measured values. Analytical investigations (ion analysis) for the membrane filtrate at various flowrates and applied pressures were performed to determine the forward osmosis filtrate ion composition. The FO filtrate compositions were then simulated using ScaleChem studio software from OLI for scaling tendency. The software predicted a remarkable reduction in the scaling tendency in the injection water infrastructure (including the oil reservoir) and by more than 50% compared to conventional co-produced water re-injection. Parallel to the ScaleChem predictions, the FO filtrate water was experimentally investigated for scaling using the Differential Scaling Loop rig, in a third-party lab. The DSL results are in good agreement with the ScaleChem predictions. The experimental scaling tendency results show that the injection of forward osmosis filtrate has the minimum occurrence of scaling both in the surface and subsurface. This new concept to produce LowSal produced water re-injection has the potential to improve oil recovery by minimizing the oil reservoir plugging due to scaling.
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FARIAS, MANOEL LEOPOLDINO ROCHA DE. "IMPROVED HEAVY OIL RECOVERY BY INJECTION OF DILUTED OIL-IN-WATER EMULSIONS." PONTIFÍCIA UNIVERSIDADE CATÓLICA DO RIO DE JANEIRO, 2013. http://www.maxwell.vrac.puc-rio.br/Busca_etds.php?strSecao=resultado&nrSeq=23855@1.
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PONTIFÍCIA UNIVERSIDADE CATÓLICA DO RIO DE JANEIROA injeção de água é o método de recuperação secundário mais utilizado no mundo. Mesmo em situações em que esse método não é o mais adequado, a facilidade de implantação e os menores custos comparativos impõem esse método como a opção selecionada. Em campos de óleo pesado, a razão de mobilidade desfavorável e as heterogeneidades de reservatório precipitam a formação de digitações viscosas e altos valores de saturação residual de óleo, levando a baixos fatores finais de recuperação. Os poços produtores desses campos produzem com altas frações de água muito rapidamente. O tratamento da água produzida é o principal custo operacional desses campos. O uso de emulsões diluídas de óleo em água foi avaliado como método de controle de mobilidade. Foi desenvolvido um extenso programa experimental em sandpacks de areia de sílica e plugs de arenito (Berea e Bentheimer) de forma a comparar as recuperações finais de óleo, perfis de pressão de injeção e razões água-óleo acumuladas nos casos de injeção de água, injeção de surfactantes e macroemulsões. Todos os meios porosos ensaiados foram saturados com petróleo cru originário da Bacia de Campos (20 graus API). Um estudo paramétrico foi feito de forma a identificar a influência da vazão de injeção, distribuição de tamanhos de gotas de óleo emulsionadas, concentração de óleo e permeabilidade no desempenho das emulsões injetadas. O programa foi complementado com um ensaio 3D (arenito Castlegate na configuração um quarto de five-spot) onde o fluido injetado foi dopado com Iodeto de Potássio para permitir melhor visualização da modificação de saturações de óleo e água com um tomógrafo de raios X. Os resultados obtidos indicaram ganhos na produção de óleo e redução da razão água-óleo acumulada. A possibilidade de preparar as emulsões óleo-água a serem injetadas a partir da água produzida pelo próprio campo traz um grande ganho ambiental ao se reduzir o descarte superficial de água oleosa. O efluente se transforma em um recurso.
Water injection is the most used secondary recovery method in the world. This option is generally chosen even in situations where it is not the most efficient alternative to recover the oil due to its comparative simple implementation and lower operational costs. In heavy oilfields, the unfavorable mobility ratio between injection and displaced fluids in addition to reservoir heterogeneities cause water fingering phenomenon, high residual oil saturation and consequently poor final oil recoveries. Producer wells start to produce high water cuts very soon. Produced water treatment for surface disposal is the main operational cost in these oilfields. The use of diluted oil-in-water macroemulsions was evaluated as a mobility control method for these cases. An extensive experimental program was performed using silica sandpacks and sandstone plugs (Berea and Bentheimer) in order to evaluate final oil recovery factors, cumulative water-oil ratio and pressure behavior, comparing water injection, surfactant solution injection and oil-in-water injection. All porous media were saturated with crude oil from Campos Basin (20 degrees API). A parametric study was performed to identify the effect of injection rate, oil droplets size distributions, emulsion oil concentration and permeability level in emulsion injection performance. The experimental program was completed by an X-Ray computerized tomography monitored experiment in a Castlegate sandstone block (1/4 five-spot configuration). This block was submitted to an alternate water/emulsion/water injection. All injection fluids were doped with Potassium Iodide in order to better visualize oil and water saturations changes during this experiment. The results obtained have indicated final oil recovery improvement and cumulative water/oil reduction. The possibility, after some treatment, to prepare diluted oil-in-water emulsions using produced water from the oilfield brings the additional environmental benefit to emulsion injection. It would be a way to convert an effluent in a resource with clear environmental advantages.
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Akangbou, H. N. "Optimizing oil production in horizontal wells (water/oil cresting in horizontal wells)." Thesis, University of Salford, 2017. http://usir.salford.ac.uk/43678/.
Full textAbstract:
In recent years, the application of horizontal wells has been predominant in minimizing cresting scenarios due to significant reservoir exposure of its laterals. Cresting is known to occur in horizontal wells when the pressure drop supersedes the hydrostatic pressure existing between the phases in a typical reservoir. Cresting poses problems such as uneconomic oil production rates due to increasing volumes of effluent(s) (unwanted water and or gas) produced with oil over time as well as the overall recovery efficiency of oil reservoirs. Production optimization from crest-affected thick- and thin-oil rim homogeneous reservoirs were investigated experimentally by considering the effect of varying the inclined sections of a horizontal well at low angles of inclination (15o-30o), initial surface pressures (-4.351Psig), lateral length in reservoir (lr, = 0.305 m) and oil viscosity (50 cP) on oil recovery, oil produced and cumulative water produced during cresting. A strong bottom aquifer and considerable gas cap were modeled at constant bottom water injection rate of 41.68 cm3/s and at atmospheric pressure (14.7 Psi) respectively. An experimental proactive cresting control technique based on reservoir wettability, gravity segregation and effluent(s) breakthrough times were investigated for cresting control in thick- and thin-oil rim homogeneous reservoirs, using an electromagnetic valve installation. Numerical simulations were considered using Particle Image Velocimetry (PIV) to the determine the velocity of captured water cresting images and Computational Fluid Dynamics (CFD) to validate the oil withdrawal rate, Gas-Oil-Contact (GOC) and Water-Oil-Contact (WOC) by applying boundary conditions from the physical model. From results of varying the inclined section of the horizontal well, the Short radius wells with 30o angle of inclination and ratio of vertical displacement of the inclined section to reservoir height (Vd/Hr) of 0.079 resulted in 177.75 cm3 increment in oil recovered and reduction in cumulative water produced (258 cm3) at a production time of 300 s in thick-oil rim reservoirs while 250 cm3 increment in oil was observed with 356 cm3 reduction in cumulative water produced at a production time of 495 s in thick-oil rim reservoirs with Vd/Hr, 0.063. Further increment of 108.91 cm3 in oil produced and reduction in cumulative water produced (183.99 cm3), was observed when cresting was controlled proactively in thick-oil rim reservoirs. From varying the inclined section of the horizontal well, increment in oil produced of 163 cm3 and 134 cm3 cumulative reduction in produced water were observed at Vd/Hr equals 0.079 in thin-oil rim reservoirs at a simulation time of 210 s while a lower oil increment of 6.84 cm3 and cumulative water reduction of 10.98 cm3 were observed in thin-oil rim reservoirs when controlled proactively. The over predicted quantitative results as high as 75.06% using the CFD model compared with experimental data were due to two-dimensional (2D) model limitations in porous media as well as the corresponding grain sizes. To exemplify, for WOC the predicted results was about 28.56% compared to experimental data at 4.5 s. The average velocity profile from PIV analysis increased steadily from 0.113 to 2.08E-15 m/s from 10 to 90 s.
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Yao, Juncheng. "Characterization and Prediction of Water Droplet Size in Oil-Water Flow." Ohio University / OhioLINK, 2016. http://rave.ohiolink.edu/etdc/view?acc_num=ohiou1470741069.
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Vatn, Karsten Dånmark. "Optimization of water-borne crude oil transport." Thesis, Norwegian University of Science and Technology, Department of Engineering Cybernetics, 2007. http://urn.kb.se/resolve?urn=urn:nbn:no:ntnu:diva-9544.
Full textAbstract:
A ship scheduling problem in optimization of water-borne crude oil transportation has been investigated. The classic optimization problem the most closely related to the problem at hand is the Multi-Vehicle-Pick-up-and-Delivery Problem with Time Windows (m-PDPTW). In addition to the basic characteristics of the m-PDPTW, the studied problem has an additional degree of freedom due to having pick-ups and deliveries that are not matched. This extra freedom gives new possibilities when creating effective heuristics when dealing with transportation problems. The studied problem has been presented in relation to carefully selected background literature. On this basis a proposed heuristic has been developed, and implemented using some already existing structures in the commercial decision support system TurboRouter. The studied problem is an industrial shipping problem, an operational mode where the shipper owns the cargo to be transported. No income is therefore made directly from transporting goods. Therefore the objective function chosen was net income, which in this mode is the same as minimizing the net expenses. A multi-start local search with pre-matching of pick-ups and deliveries heuristic was chosen based on an assessment of problem size, problem type, real life applicability and existing software. This heuristic consists of three main parts. First the pick-ups and deliveries are matched and merged in a pre-matching heuristic, and then a large number of initial solutions are generated by an insertion heuristic. The best initial solutions are then improved by a local search. Two strategies were developed for pre-matching and then tested. The one with the best test results was subsequently used in the heuristic. This multi-start local search with pre-matching of pick-ups and deliveries heuristic has been subject to rigorous testing and was compared to a single-start local search and multiple initial solutions heuristic. The solutions generated by the multi-start local search heuristic were superior compared to those of the other heuristics, but the computation time necessary was high and higher than those of the heuristics which it was compared to. This high computation time is partially believed to be a result of flexible data sets resulting in broad solution spaces. In addition some computationally expensive heuristics were deployed, increasing the computation time. In real life applications, finding a solution relatively quickly is of importance. Therefore the heuristic may need to be simplified and used on "tighter" data sets than some sets used in testing to be real life applicable.
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Valle, Arne. "Three phase gas-oil-water pipe flow." Thesis, Imperial College London, 2000. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.248608.
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Girard, Nathalie Renee Claude. "Oil-in-water microemulsions and their polymerization." Thesis, Imperial College London, 1992. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.369502.
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MONTALVO, MIGUEL EDUARDO DEL AGUILA. "OIL WATER EMULSIONS FLOW THROUGH MICRO-CAPILLARIES." PONTIFÍCIA UNIVERSIDADE CATÓLICA DO RIO DE JANEIRO, 2008. http://www.maxwell.vrac.puc-rio.br/Busca_etds.php?strSecao=resultado&nrSeq=12535@1.
Full textAbstract:
CONSELHO NACIONAL DE DESENVOLVIMENTO CIENTÍFICO E TECNOLÓGICOEvidências experimentais demonstram o potencial da injeção de emulsões no aumento do fator de recuperação de óleo. O mecanismo responsável por esta melhor varredura do reservatório é a redução da mobilidade da água em regiões do reservatório já varridas por água. Esta redução pode ser associada ao bloqueio parcial de gargantas do meio poroso por gotas da fase dispersa da emulsão. A eficiência deste bloqueio parcial depende fortemente da geometria do poro, das características morfológicas e propriedades físicas da emulsão injetada. A utilização eficiente deste método de recuperação é limitada pela falta de entendimento fundamental de como emulsões escoam através de um meio poroso. Este trabalho tem como objetivo estudar o escoamento de emulsões através de gargantas de poros, que são modeladas fisicamente por micro- capilares com garganta nos experimentos desenvolvidos nesta pesquisa. Os resultados mostram como a permeabilidade varia com as propriedades e características morfológicas da emulsão e parâmetros geométricos do micro-capilar. Estes dados definem as propriedades necessárias de emulsões em função das características do reservatório para a obtenção do efeito de bloqueio parcial desejado e servem de entrada de dados para modelo de rede de capilares de escoamento de emulsões em meios porosos.
Experimental evidences show the potential of emulsion injection in the improvement of oil recovery factor. The responsible mechanism for this better reservoir sweep is the water mobility reduction in regions already swept by water. This reduction can be associated with partial blockage of porous media throats by droplets of emulsion dispersed phase. The efficiency of this partial blockade strongly depends on pore geometry, morphological characteristics and physical properties of the injected emulsion. The efficient use of this recovery method is limited by the lack of fundamental understanding of how emulsions flow through a porous medium. This work aims to study the flow of emulsions through pores throats, which are physically modeled by constricted micro- capillaries in the experiments presented here. The results show how permeability varies with geometrical parameters of micro-capillaries, emulsion properties and morphological characteristics. These data define the necessary properties of emulsions according to the reservoir characteristics to obtain the desired blocking effect and serve as input data to capillaries network model of flow of emulsions in porous media.
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MUNIZ, CYNTIA SIQUEIRA. "SHALE-SYNTHETICS OIL AND WATER FLUIDS INTERACTION." PONTIFÍCIA UNIVERSIDADE CATÓLICA DO RIO DE JANEIRO, 2005. http://www.maxwell.vrac.puc-rio.br/Busca_etds.php?strSecao=resultado&nrSeq=7635@1.
Full textAbstract:
COORDENAÇÃO DE APERFEIÇOAMENTO DO PESSOAL DE ENSINO SUPERIORAGÊNCIA NACIONAL DE PETRÓLEO
GRUPO DE TECNOLOGIA E ENGENHARIA DE PETRÓLEO - PUC-RIO
Este trabalho desenvolve uma metodologia para obter experimentalmente a pressão capilar de diferentes fluidos em contato com folhelhos, comparando-a com valores obtidos analiticamente a partir da caracterização dos fluidos e dos folhelhos individualmente. Foram realizados ensaios numa célula de difusão a qual permite simular as condições de pressão aplicadas no campo, avaliar a interação físico- química entre fluidos e rochas, além de determinar os parâmetros de transporte de massa devido a gradientes químicos e hidráulicos. Verifica-se que os valores de pressão capilar obtidos diretamente na célula de difusão são inferiores aos obtidos a partir da equação de pressão capilar utilizando a tensão interfacial, o ângulo de contato e o raio de poros do folhelho. Desta forma, conclui-se que caso seja realizada uma análise de estabilidade considerando a pressão capilar do fluido, este parâmetro deve ser determinado experimentalmente na célula de difusão. Caso contrário, valores superestimados poderão ser encontrados.
A methodology was developed to experimentally obtain the capillary pressure of different fluids in contact with shales and compare these values with analytical results from individual characterization of fluids and shales. Tests were carried out in a diffusion cell, which allows the simulation of in-situ pressure conditions, the evaluation of physical-chemical interactions between fluids and rocks and the determination of mass transport parameters due to hydraulic and chemical gradients. It is observed that the values of capillary pressure directly obtained in the diffusion cell are inferior to the ones obtained from the capillary pressure equation using the interfacial tension, the contact angle and the pore radius of shales. Thus, it can be concluded that, if a stability analysis considering the capillary pressure of the fluid is carried out, this parameter should be experimentally determined in the diffusion cell. Otherwise, overestimated values can be found.
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Banchik, Leonardo David. "Advances in membrane-based oil/water separation." Thesis, Massachusetts Institute of Technology, 2017. http://hdl.handle.net/1721.1/108950.
Full textAbstract:
Thesis: Ph. D., Massachusetts Institute of Technology, Department of Mechanical Engineering, 2017.Cataloged from student-submitted PDF version of thesis.
Includes bibliographical references (pages 117-124).
Oil is a widespread pollutant from oil spills to industrial oily wastewater in the oil and gas, metalworking, textile and paper, food processing, cosmetics, and pharmaceutical industries. A wastewater of particular concern is produced water, an oily waste stream from hydrocarbon extraction activities. Worldwide, over 2.4 billion US gallons of produced water is generated every day. Membrane technologies have emerged as the preferred method for treating these wastewaters; this has allowed operators to reclaim and reuse fresh water for potable, industrial, and agricultural use and to meet waste discharge regulations. Yet, despite their technological predominance, membranes can become severely fouled and irreversibly damaged when bulk and small stabilized oil droplets, emulsions, are present in intake streams. In this thesis, we seek to mitigate these deleterious effects through several means. First we seek to better understand fouling by oil-in-water emulsions on conventional polymeric ultrafiltration membranes. We investigate the decrease in water production over time using model and actual produced water samples with varying solution zeta potentials and make meaningful recommendations to operators based on our observations. Next, we develop a robust multifunctional membrane which can in one step degrade organic pollutants and separate bulk and surfactant-stabilized oil/water mixtures while achieving high fluxes, high oil rejection, and high degradation efficiencies. Finally, we investigate the potential of novel in-air hydrophilic/oleophobic microfiltration and reverse osmosis membranes for their anti-oil fouling performance relative to conventional hydrophilic/oleophilic membranes. Contrary to claims in literature of superior performance, we find that in-air oleophobicity does not aid in underwater anti-fouling due to surface reconstruction of mobile perfluoroalkyl chains in the presence of water. Based on these observations, we discuss opportunities for future research on oil anti-fouling membranes using fluorinated moieties.
by Leonardo David Banchik.
Ph. D.
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Boyd, Nathan Andrew. "Impact of sediment-water interactions upon overlying water quality in an urban water system." Thesis, Manchester Metropolitan University, 2001. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.366236.
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Knock, Mona Marie. "Monolayers of cationic surfactants at the air-water and oil-water interfaces." Thesis, University of Oxford, 2003. http://ora.ox.ac.uk/objects/uuid:c0cdaf66-716a-4b48-b22c-659d1fe2a342.
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Monolayers of the cationic surfactant hexadecyltrimethylammonium halide (CTAX, where X = F¯, Cl¯, Br¯, and I¯) have been studied at the air-water and oilwater interfaces. At the air-water interface, the effects of the halide counterion and the addition of counterion were investigated. Sum-frequency spectroscopy (SFS), ellipsometry, and surface tensiometry indicated that the counterion changed the efficiency and effectiveness of the surfactant, both decreasing in the order of Br¯> Cl¯>F¯. The addition of salt in the form of 0.1 M KX was found to reduce the cmc but had little effect on the limiting area per molecule attained at the cmc, which increased from 44 Å2 for CTAB to 65 Å2 for CTAC and ca. 94 Å2 for CTAF. Neither SFS nor ellipsometry provided any firm evidence for specific effects of the halide ions on the structure of the surfactant monolayers. For CTAB monolayers in the absence of excess electrolyte, the effect of area per molecule on the sum-frequency (SF) spectra was studied. Mixed monolayers of CTAB and tetradecane at the air-water interface exhibit a first-order phase transition from a conformationally disordered to a conformationally ordered state as the temperature is lowered. The phase transition occurs ca. 11 °C above the bulk melting point of tetradecane. A new experimental arrangement is described for acquiring SF spectra from surfactants at the oil-water interface. The key features of this approach are the stabilisation of a thin oil film between a sapphire prism and an aqueous phase, and the use of total internal reflection to enhance the total signal and discriminate against signals from other interfaces in the system. With this new methodology, the first SF vibrational spectra of surfactant monolayers at an alkane-water interface were obtained. Surface tensiometry was used to characterise the monolayers further. The structure of CTAB monolayers at the hexadecane-water interface was determined by SFS and compared with monolayers of CTAB at the air-water interface. At low concentrations, CTAB/hexadecane showed the expected features in the C-H stretching region, characteristic of a conformationally disordered monolayer. As the bulk concentration approached the critical micelle concentration, the spectra changed to one characteristic of a more ordered, upright conformation. Ellipsometric measurements supported this conclusion. This qualitative structural change is not observed in analogous monolayers at the air-water interface or CCl4-water interface, or in surfactant solutions in contact with a hydrophobic solid surface.
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Kambanellas, Chrysostomos Andreou. "Water consumption and recycling of grey water in Cyprus." Thesis, University of South Wales, 1991. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.333926.
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Stone, Andrew Colin. "Oil/water separation in a novel cyclone separator." Thesis, Cranfield University, 2007. http://dspace.lib.cranfield.ac.uk/handle/1826/5202.
Full textAbstract:
Conventional bulk oil-water separation is performed in large gravity separators that take
up large areas and potentially contain large volumes of hazardous material. An
intensified bulk separator has the potential to provide significant benefit in saving space,
especially where this is at a premium, and in improving safety.
The I-SEP, a novel geometry of Axial-Flow Cyclone (also known as Uniflow or
straight-through) separator, has been tested as an intensified bulk oil-water separator.
The objective of this work is to quantify performance by producing a map of separation
performance with variation of inlet conditions, using variation of outlet back pressure to
make the separator adaptable to variable inlet flow. A second objective is to compare
the experimental performance of the I-SEP with a mathematical model.
Using a Perspex test-unit with kerosene, or a silicone-based oil, and water in a batch
flow loop, a map has been produced for outlet compositions and separation efficiencies
at multiple inlet velocities. This was done for a range of inlet water cuts from 10% to
90% and with a geometry varied by lengthening the separating chamber of the test unit.
A Computational Fluid Dynamics model using the Reynolds-Stress model has been
developed with the FLUENT 6.0 CFD code. This has been compared with quantitative
flow visualisation data and drop sizing information to model the separation of the
cyclone by a discrete-phase technique.
An optimum configuration and operating conditions has been found, with peak
efficiencies in excess of 80%. This shows the important effect in improving
performance achieved by the manipulation of outlet flow splits using backpressure. This
Axial-Flow Cyclone design achieves a broader range of separation effect than published
Reverse-Flow Cyclone designs. However, the unit will need to undergo further
development to reduce shear and maximise residence time at high swirl.
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Sidiq, Hiwa. "Advance water abatement in oil and gas reservoir." Curtin University of Technology, Department of Chemical Engineering, 2007. http://espace.library.curtin.edu.au:80/R/?func=dbin-jump-full&object_id=17578.
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The control of excessive water production in oil and gas producing wells is of increasing importance to the field operator, primarily when trying to maintain the survivability of a mature field from shut in. During the last two decades many chemicals have been studied and applied under the name of relative permeability modifier (RPM) to combat this problem. These chemicals were mostly bullheaded individually into the affected zones, consequently their application resulted in low to medium success, particularly in treating reservoirs suffering from matrix flow. It has been found that the disproportionate permeability reduction depends on the amount of polymer dispersed or absorbed by the porous rock. If single polymers are employed to treat excessive water production in a matrix reservoir they cannot penetrate deep into the formation rock because the polymer will start to build as a layer on the surface of the rock grains. As a result the placement of polymer into the formation will no be piston like and the dispersion over the rock pores will be uneven. To improve water shutoff technology a method of injecting chemicals sequentially is recommended provided that the chemical’s viscosity is increasing successively with the chemicals injected.Experimentally confirmed, injecting chemicals sequentially provides better results for conformance control. The value of post treatment water mobility is conspicuously lowered by the method of applying injecting chemicals sequentially in comparison with the single chemical injection method. For instance, the residual resistance factor to water (Frrw) at the first cycle of brine flushing for this method is approximately five times higher than the Frrw obtained by injecting only one single chemical. Furthermore, for the second cycle of brine flushing Frrw is still higher by a ratio of about 2.5. In addition to this improvement residual resistance factor to oil Frro for this method is less than two which has been considered as the upper limit for conformance control in matrix reservoir. Accordingly injecting chemical sequentially can be applied for enhancing relative permeability modifier performance in matrix reservoir.
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Vedapuri, Damodaran. "Studies on oil-water flow in inclined pipelines." Ohio : Ohio University, 1999. http://www.ohiolink.edu/etd/view.cgi?ohiou1175282143.
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Park, Bum Jun. "Interactions between colloidal particles at oil-water interfaces." Access to citation, abstract and download form provided by ProQuest Information and Learning Company; downloadable PDF file, 96 p, 2008. http://proquest.umi.com/pqdweb?did=1475189581&sid=20&Fmt=2&clientId=8331&RQT=309&VName=PQD.
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Ratoi, Monica. "The design of lubricating oil in water emulsions." Thesis, Imperial College London, 1996. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.243558.
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Barker, David Colin. "The lubricating properties of oil-in-water emulsions." Thesis, Imperial College London, 1995. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.294971.
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Mlondo, Sibusiso Nkosikhona. "Directed assembley of nanostructures at water/oil interface." Thesis, University of Manchester, 2009. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.499861.
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Alanezi, Yousef H. "Crossflow microfiltration of oil from synthetic produced water." Thesis, Loughborough University, 2009. https://dspace.lboro.ac.uk/2134/8815.
Full textAbstract:
Produced water is formed in underground formations and brought up to the surface along with crude oil during production. It is by far the largest volume byproduct or waste stream. The most popular preference to deal with produced water is to re-inject it back into the formation. Produced water re-injection (PWRI) needs a treatment before injection to prevent formation blockage. Due to the increase of produced water during oil production in the west of Kuwait, an effluent treatment and water injection plants were established and commissioned in 2004 so that produced water could be used for re-injection purposes. It is estimated that oil wells in the west of Kuwait produce 15 to 40 % of produced water. The main aim of this treatment train is to reduce not only the oil-in-water amount to less than 10 ppm, but also total suspended solids to 5 ppm which is the maximum allowable concentration for re-injection and disposal. Furthermore, with respect to the upper limit for injection, the maximum number of particles between 5 and 8 microns is 200 in 0.1 ml. In practice the number is found to exceed this limit by 10 times...
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Fernando, L. M. "Jet mixing of water in crude oil pipelines." Thesis, Cranfield University, 1990. http://dspace.lib.cranfield.ac.uk/handle/1826/8650.
Full textAbstract:
The jet mixing of water in crude oil pipelines by single nozzle and
multi-nozzle mixers was studied by dividing the mixing domain into to
three regions. the penetration. near field and farfield regions. At
the penetration region the quantitative experimental data were aided
by a flow visualisation study in an attempt to to form fundamental
semi-empirical correlations to estimate the entrainment rate of
stratified water from the bottom and the Sauter mean diameter of
the entrained water droplets for a single nozzle jet mixer.
The flow field diagnostics into the near field region. defined as the
region where high level of swirl and mixing is occuring. were
conducted theoretically using computational fluid dynamic code
"Phoenics" and experimentally through LOA measurements and flow
visualisation. The entrainment rate found in penetration region was
treated as a source term for theoretical analysis.
Experimental analysis of this region was conducted in single phase
flow for two mixer nozzles i) Single nozzle mixer and ii). Existing
multi-nozzle mixer. Experimental results have revealed that the swirl
velocities decay faster for higher velocity ratios and their
dependence on Reynolds number (in the range 27600 to 48400) is weak.
Higher velocity ratios would generate and dissipate higher levels of
energy, therefore break up water droplets to smaller sizes and
increase the eddy viscosity. The dispersion strength due to swirl
decays faster and the gravity settling begins earlier.
As the flow reaches downstream. approximately four diameters. the
distribution of velocities (mean and RMS) flattens out and their
magnitude begins to close up for the two mixers. when their momentum
ratios are equal.
It
was also shown that the swirl velocities (at
axis) die away. approximately at the same axial point for both of the
nozzles. The multi-nozzle mixer is shown to be better in two
characteristics; i). The mixing is faster and ii) The jet energy is
more evenly distributed in the vicinity of the injection cross
section. hence improving the quality of the droplet size distribution.
Besides providing information to aid understanding of the complex flow
in the mixer zone. the experimental data is believed to be of
sufficient quality and quantity to improve the present simple
modelling procedures as well as to be used as test cases for
assessment of the predictive accuracy of more elaborate computational
models.
Comparision with computational results (of low velocity ratios) shows
the agreement with swirl velocities is reasonable. but not always
acceptable for mean axial velocities. However. the computational model
predicts the near field jet trajectory reasonably well. The flow
visualisation of dispersion of passive contaminant agrees
qualitatively with the contours of the passive contaminant.
In the far field region. where the swirl has decayed. the flow behaves
two dimensionally. Therefore. an exact solution was obtained for two
dimensional water conservation equation. The boundary conditions were
specified by using sticking probability constants. A relationship was
obtained to specify eddy viscosity through turbulent kinetic energy.
The turbulent kinetic energy and swirl decay were estimated from LDA
experimental data. This solution can be used to study the developing
characteristics of water concentration profiles along the far field
region of the pipeline.
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Richmond, Howard N. "Phase inversion in nonionic surfactant-oil-water systems." Thesis, Loughborough University, 1992. https://dspace.lboro.ac.uk/2134/14713.
Full textAbstract:
This study has been concerned with the inversion of water in oil (W/0) emulsions, to oil in water (O/W) emulsions and vice-versa. It has been shown that there are two types of emulsion phase inversion that can occur in nonionic Surfactant-Oil-Water (nSOW) systems: (i) A "transitional" inversion, which is brought about by changing the nSOW phase behaviour, by altering the surfactant's affinity for the oil and water phases and, (ii) a "catastrophic" inversion, induced by increasing the dispersed phase fraction and occurs at closest packing of unstable dispersed phase drops. The inversion mechanism of the two inversion types has been characterised. The two inversion types can be represented as boundaries on a "map" relating nSOW phase behaviour with water to oil volume ratio. The form of the map depends on the nature of the oil. At the transitional point, the nSOW system can be 3 phase - an oil phase, a water phase and a surfactant phase microemulsion. Ultra-low interfacial tension exists between the phases - this property is of interest for producing extremely fine emulsions with low energy input. Transitional inversions are sometimes reversible. In nSOW systems, true catastrophic inversions can be induced by moving the water to oil ratio in one direction only. Double emulsion drops (W/O/W or O/W/O) are sometimes produced before inversion and inversion points are dependent on dynamic conditions. A thermodynamic relationship between nSOW phase behaviour, oil type, surfactant type, surfactant concentration and temperature has been derived, based on the partitioning of surfactant between oil, water and a surfactant micelle phase. It has been shown how this can be used to classify nonionic surfactants. The effect of agitation conditions, water addition rate and oil phase viscosity, on the drop types and drop sizes of emulsions present before and after inversion (for each inversion type) has been studied extensively. Surfactant type and concentration also affect drop behaviour and drop sizes. Various drop types have been identified and qualitative and quantitative analysis of the factors controlling the drop sizes of emulsions at each stage of a phase inversion has been developed.
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Ward-Smith, R. Stephen. "Protein - polysaccharide complexes at the oil/water interface." Thesis, University of Nottingham, 1995. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.262139.
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West, P. E. "Oil-in-water emulsions for intravenous drug delivery." Thesis, University of Nottingham, 1988. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.233707.
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Hu, Binjie. "Cross flow microfiltration of water in oil emulsion." Thesis, University of Newcastle Upon Tyne, 2001. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.366591.
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Al-Rabiah, Hassan. "Fractionation of petroleum crude oil using superheated water." Thesis, University of Leeds, 2003. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.399875.
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Ocampo-Barrera, Rene. "Combustion of Mexican heavy fuel oil/water emulsions." Thesis, University of Salford, 1997. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.244933.
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Sidiq, Hiwa H. Amin. "Advance water abatement in oil and gas reservoir /." Full text avaialble, 2007. http://adt.curtin.edu.au/theses/available/adt-WCU20080415.092908.
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SILVA, MARCOS AURELIO CITELI DA. "WATER AND OIL FLOW SIMULATION IN POROUS MEDIA." PONTIFÍCIA UNIVERSIDADE CATÓLICA DO RIO DE JANEIRO, 2002. http://www.maxwell.vrac.puc-rio.br/Busca_etds.php?strSecao=resultado&nrSeq=4779@1.
Full textAbstract:
COORDENAÇÃO DE APERFEIÇOAMENTO DO PESSOAL DE ENSINO SUPERIORMuitos problemas provenientes do mundo real podem ser modelados por sistemas de equações diferenciais parciais (EDP´s). No entanto, as equações resultantes da discretização produzem matrizes grandes e freqüentementes mal condicionadas. Este trabaho implementa o método de elementos finitos mistos para resolver numericamente um sistema de EDP´s oriundo de um modelo de escoamento de fluidos em meios porosos e melhora sua performance usando precondicionadores e processamento paralelo.
Many problems arising from real world can be represented by systems of partial diferential equations (PDE´s). However, the resulting discrete equations produce large and frequently bad conditioned matrices. This work implements the mixed finite element method to numerically solve a system of PDE´s coming from a multiphase flow in porous media model and improve its performance by preconditioners and parallel processing.
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BARRETO, GUILHERME LOPES. "CLATHRATE HYDRATE FORMING IN WATER-IN-OIL EMULSIONS." PONTIFÍCIA UNIVERSIDADE CATÓLICA DO RIO DE JANEIRO, 2018. http://www.maxwell.vrac.puc-rio.br/Busca_etds.php?strSecao=resultado&nrSeq=34572@1.
Full textAbstract:
PONTIFÍCIA UNIVERSIDADE CATÓLICA DO RIO DE JANEIROCOORDENAÇÃO DE APERFEIÇOAMENTO DO PESSOAL DE ENSINO SUPERIOR
PROGRAMA DE EXCELENCIA ACADEMICA
Uma combinação de fatores geológicos e econômicos exige que as empresas produzam petróleo e gás em campos com profundidades de água cada vez maiores. Muitas das vezes não é econômico, ou no pior dos casos impraticável, instalar uma plataforma sobre os cabeçotes dos poços, por isso acaba se tornando comum transportar petróleo e gás através de amarras submarinas que podem ser de até 145km ou mais. Geralmente isso significa que as temperaturas são baixas o bastante e as pressões altas o suficiente para tornar aquele ambiente dentro do que chamamos de envelope de formação de hidrato e ações deverão ser tomadas afim de evitar os plugs de hidrato. Como resultado, a indústria foi forçada a intensificar sua pesquisa em químicos e sistemas que evitasse a formação da estrutura cristalina. Uma dessas pesquisas em estudo é a avaliação de um fluido modelo, emulsão A/O, analisando suas principais características e verificando as propriedades reológicas da estrutura cristalina em formação. Para tornar a pesquisa viável, este hidrato é formado a pressão atmosférica utilizando moléculas hóspedes que proporcionam essa formação em tal pressão e baixa temperatura. Logo, é utilizada uma substância líquida chamada ciclopentano, que substituirá o gás natural e irá proporcionar a formação do hidrato nestas novas condições. Dessa forma, este trabalho apresentou diferentes emulsões A/O, de acordo com a porcentagem de água, e reologia do hidrato formado para cada uma delas.
A combination of geological and economic factors requires companies to produce oil and gas in fields with increasing water depths. It is often impractical to install a platform over the heads of the wells, so it is becoming common to transport oil and gas through underwater moorings that can be up to 145 km or more. Usually this means that the temperatures are low enough and the pressures high enough to make that environment into what we call a hydrate formation envelope and actions should be taken to avoid the hydrate plugs. As a result, the industry was forced to intensify its research into chemicals and systems that prevented the formation of the crystalline structure. One of these researches is the evaluation of a model fluid, A / O emulsion, analyzing its main characteristics and checking the rheological properties of the crystalline structure in formation. To make the search feasible, this hydrate is formed at atmospheric pressure using guest molecules that provide such formation at such pressure and low temperature. Therefore, a liquid substance called cyclopentane is used, which will replace the natural gas and will provide the formation of the hydrate under these new conditions. In this way, this work presented different A / O emulsions, according to the percentage of water, and rheology of the hydrate formed for each of them.