Academic literature on the topic 'Oil-water emulsions- Crude'
Create a spot-on reference in APA, MLA, Chicago, Harvard, and other styles
Consult the lists of relevant articles, books, theses, conference reports, and other scholarly sources on the topic 'Oil-water emulsions- Crude.'
Next to every source in the list of references, there is an 'Add to bibliography' button. Press on it, and we will generate automatically the bibliographic reference to the chosen work in the citation style you need: APA, MLA, Harvard, Chicago, Vancouver, etc.
You can also download the full text of the academic publication as pdf and read online its abstract whenever available in the metadata.
Journal articles on the topic "Oil-water emulsions- Crude"
1
Nagy, Roland, Andrea Elekes, László Bartha, and Árpád Vágó. "Rheological characterization of crude oil-water emulsions." Epitoanyag - Journal of Silicate Based and Composite Materials 68, no. 4 (2016): 98–104. http://dx.doi.org/10.14382/epitoanyag-jsbcm.2016.17.
Full text
2
Abouther Thalib Halboose, Mudhaffar Yacoub Hussein, and Raheem Jafar Aziz. "Study the effect of Water content and Temperature on the stability of Crude Oil/Water Emulsions." Journal of the College of Basic Education 20, no. 86 (February 2, 2023): 987–92. http://dx.doi.org/10.35950/cbej.v20i86.9912.
Full textAbstract:
During the crude oil production, water-in-oil stable emulsions may be created. Water which is naturally present in oil reservoirs mixes with crude oil to form very stable emulsions due to very high shear rates and zones of turbulence encountered at the wellhead and pipe of production. The formation of these emulsions is generally caused by the presence of resins, asphaltenes, wax and naphtenic acid which play the role of "natural emulsifiers. The aim of this study was to focus on some important factors in the formation and stabilize crude oil/water emulsions. These factors are the water content, which varies from oil field to another and to understand its role in the Stability of the emulsion, which vary depending on the oil fields. Another factor is the temperature at which the physicist has a role in a large non-oil emulsions Stability. The study deals with the effect of water content and temperature on the stability of crude oil emulsion. The emulsion was prepared by mixing the crude oil and desired content of water and shaking by hand. The volume percent of water were studied in this paper to the total volume of crude oil emulsion (10, 20, 30, 40, 50, 60) and temperature were (20, 30, 40, 50) OC. The results showed that, the emulsion stability decrease with increase water concentration. Change in temperature had a significant effect where the higher temperature became unstable emulsions
3
N. H. Abdurahman and H. A. Magdib. "Surfactant (UMP) for emulsification and stabilization of water-in-crude oil emulsions (W/O)." Maejo International Journal of Energy and Environmental Communication 2, no. 2 (May 22, 2020): 18–21. http://dx.doi.org/10.54279/mijeec.v2i2.245027.
Full textAbstract:
The purpose of this research is to look into the formulation and evaluation of concentrated water-in-oil (W/O) emulsions stabilized by UMP NS-19-02 surfactant and their application for crude oil emulsion stabilization using gummy Malaysian crude oil. A two-petroleum oil from Malaysia oil refinery, i.e., Tapis petroleum oil and Tapis- Mesilla blend, were utilized to make water-in-oil emulsions. The various factors influencing emulsion characteristics and stability were evaluated. It was discovered that the stability of the water-in-oil emulsion improved by UMP NS-19-02 improved as the surfactant content rises, resulting in the decline of the crude oil-water interfacial tension (IFT). Nevertheless, the most optimum formulation of W/O emulsion was a 50:50 W/O ratio with 1.0% surfactant. Additionally, raising the oil content, salt concentration, duration and mixing speed, and pH of the emulsion resulted in higher emulsion stability. It also raised the temperature of the initial mixing, which significantly decreased the formulated emulsions' viscosity. The results showed that stable emulsions could be formed using the UMP NS-19-02 surfactant.
4
Buist, Ian A., and Nick Glover. "IN SITU BURNING OF ALASKA NORTH SLOPE EMULSIONS." International Oil Spill Conference Proceedings 1995, no. 1 (February 1, 1995): 139–46. http://dx.doi.org/10.7901/2169-3358-1995-1-139.
Full textAbstract:
ABSTRACT The onset of water-in-oil emulsion formation in an oil slick often signals the closing of the window of opportunity for in-situ burning as a countermeasure. Water contents in excess of 25 percent in a stable emulsion generally preclude ignition of the slick. A study of in-situ burning of water-in-oil emulsions formed by weathered Alaska North Slope (ANS) crude oil has recently been completed by Alaska Clean Seas. The study consisted of three phases: laboratory-scale burns in Ottawa in a 0.13 m2 burn ring, small-scale burns in Prudhoe Bay in 1.2 m2 and 3.3 m2 pans, and meso-scale burns in a 69 m2 circle of 3M Fire Boom in a water-filled pit at Prudhoe Bay. The laboratory-scale tests showed that stable, weathered ANS crude emulsions could be ignited in-situ using conventional gelled fuel igniters only up to a water content of 25 percent. The combination of adding an oilfield emulsion breaker, Petrolite EXO 0894, and the use of gelled crude oil as an alternate igniter fuel, permitted ignition and efficient combustion of weathered ANS emulsions with water contents of 65 percent, the maximum achievable. The small-scale pan tests conducted in Prudhoe Bay proved the same: that normally unignitable emulsions of weathered ANS crude, up to 65 percent water content, could be successfully ignited and efficiently burned outdoors at 0° to 5°C in winds up to 32 km/h with the application of EXO 0894 one hour prior to ignition. Tests with the Helitorch igniter system suspended from a crane showed that a mixture of gelled gasoline and crude oil was the most effective ignition fuel for the emulsions. Attempts were made to ignite emulsion slicks with gelled igniter fuels containing the emulsion breaker; but this technique did not prove as effective as pre-mixing the breaker into the slick. These tests also indicated that the emulsion burns produced a lighter smoke than that from crude oil. Three meso-scale experimental burns were carried out: one involved approximately 13 m3 (80 bbl) of fresh ANS crude as a baseline; one used about 8 m3 (50 bbl) of a stable 50 percent water-in-weathered crude emulsion; and, the final burn was done with 17 m3 (105 bbl) of stable 60 percent water content emulsion. The oil removal efficiency for the fresh crude oil burn was approximately 98 percent. The oil removal efficiencies for the 50 and 60 percent water emulsions were 97 and 96 percent respectively.
5
Manthey, Frank A., John D. Nalewaja, and Edward F. Szelezniak. "Herbicide-Oil-Water Emulsions." Weed Technology 3, no. 1 (March 1989): 13–19. http://dx.doi.org/10.1017/s0890037x00031237.
Full textAbstract:
Oil-water emulsion stability was determined for crop origin and refinement of seed oils and their methyl esterified fatty acids (methylated seed oil) as influenced by emulsifiers and herbicides. Oil-in-water emulsion stability of one-refined, degummed, and crude seed oils was affected by the emulsifier. However, emulsion stability of methylated seed oil was not affected by the refinement of the seed oil used to produce the methylated seed oil or by the emulsifier. Oils without emulsifiers or emulsifiers alone added to formulated herbicide-water emulsions reduced emulsion stability depending upon the herbicide and emulsifier. Further, emulsion stability of formulated herbicides plus oil adjuvants was influenced by the oil type, the emulsifier in the oil adjuvant, and the herbicide. Oil-in-water emulsions improved or were not affected by increasing concentration of the emulsifier in the oil. However, T-Mulz-VO at a concentration greater than 10% with soybean oil or 5% with methylated soybean oil reduced emulsion stability with sethoxydim. Emulsion stability of herbicides with adjuvants depends upon the herbicide, the emulsifier, emulsifier concentration, and the crop origin, type, and refinement of oil.
6
Akbari, Sweeta, and Abdurahman Hamid Nour. "Stabilization of crude oil emulsions using different surfactants." International Journal of Innovative Research and Scientific Studies 1, no. 1 (September 21, 2018): 23–26. http://dx.doi.org/10.53894/ijirss.v1i1.6.
Full textAbstract:
Emulsions can be found in different industries such as petroleum, food, cosmetic and pharmaceutics. Generally, there are two types of emulsions in petroleum industries: water-in-oil (W/O) and oil-in-water (O/W). The aim of this research was to evaluate the stability of W/O emulsions using different emulsifiers such as Span 80, Span 83, Triton-x-100, DEA, and LSWR with different concentrations (1.5 and 2.5) vol%. All the emulsions were prepared at (20-80) vol% and 2000 rpm. The result of this study showed that the most stable emulsions were prepared by Span 80. However, LSWR formed the most unstable emulsions. In addition, it was also found that the concentration of emulsifier can significantly affect the emulsion stability.
7
Quej-Ake, L. M., A. Contreras, and Jorge Aburto. "The effect of non-ionic surfactant on the internal corrosion for X52 steel in extra-heavy crude oil-in-water emulsions." Anti-Corrosion Methods and Materials 65, no. 3 (May 8, 2018): 234–48. http://dx.doi.org/10.1108/acmm-03-2017-1770.
Full textAbstract:
Purpose The purpose of this research is to study different extra-heavy crude oil-in-water emulsions that can be found in practice for corrosion process of X52 steel adding 60 mg.L-1 of non-ionic surfactant and a corrosion inhibitor (CI). Electrochemical impedance spectroscopy and Tafel plots are carried out. Thus, Bode-modulus and Bode-phase angle plots are discussed. Adsorption isotherms obtained from corrosion rate (CR) values are taken into account. Design/methodology/approach Two-electrode arrangement is used to characterize the pseudo-capacitance values for X52 steel exposed to water and crude oil phases, mainly. Electrochemical evaluations for X52 steel exposed to extra-heavy crude oil-in-water emulsions are recorded in a conventional three-electrode cell to study the corrosion process as was documented in detail by Quej-Ake et al. (2015). Therefore, all electrodes are placed as close as possible to eliminate the iR-drop. Findings Pseudo-capacitance analysis shows that X52 steel immersed in oilfield produced water was more susceptible to corrosion than that immersed in ocean water solution and extra-heavy crude oil phase. After being analyzed, the X52 steel surface coverage and adsorption process for surfactant and CI could be concluded that surfactant could protect the metal surface. In a coalescence extra-heavy crude oil-in-water emulsion, the water medium generated a new solution that was more corrosive than the original water phase. Wash crude oil process was provoked in emulsion systems to sweep up the salts, mainly. Thus, corrosive species that can be recovered inside extra-heavy crude oil may appear, and in turn a new more corrosive solution could be obtained. Taking into account the straight line obtained in Bode-modulus plot for X52 exposed to extra-heavy crude oil, it is possible to point out that the negative value of the slope or R2 can be related to a coefficient (Jorcin et al., 2006). It is important to mention that electrochemical responses for X52 steel exposed to extra-heavy crude oil-in-water under coalescence emulsions revealed that corrosion and diffusion processes exist. Therefore, a possible good inhibitor is surfactant in emulsion systems. Originality/value CR and anodic and cathodic slopes suggest that the surfactant acted as mixed CI. Of these, susceptible anodic (MnS and perlite or cementite) and cathodic (ferrite) sites on steel surface could be affected, due to which physicochemical adsorption could happen by using electrochemical parameters analysis. Thus, no stable emulsions should be taken into account for extra-heavy crude oil transportation, because corrosion problems in atmospheric distillation process of the crude oil due to stable emulsion cannot be easily separated. In this manner, coalescent emulsions are more adequate for transporting extra-heavy crude oil because low energy to separate the water media is required.
8
Gentili Nunes, Denise, Jarlene Da Conceição Silva, Giovani Cavalcanti Nunes, Matheus Delduque Lopes da Silva, and Elizabete Fernandes Lucas. "Crude oils mixtures: compatibility and kinetics of water-in-oil emulsions separation." DYNA 89, no. 223 (September 9, 2022): 67–74. http://dx.doi.org/10.15446/dyna.v89n223.99911.
Full textAbstract:
Some oil fields produce from different reservoirs, which may be incompatible generating precipitates. These precipitates are often asphaltenes, which can be an emulsion stabilizing agent negatively affecting the oil treatment processes. In this work, the influence of oil incompatibility on the stabilization of water-in-oil emulsions was studied. Emulsions were evaluated from three different oils (A, B and C) and their mixtures (AB, AC, BC and ABC). The results showed that there is a relationship between separation kinetics of emulsions and asphaltene precipitation. The separation kinetics of the emulsions was faster for more compatible oils. We observed that oil A, which was the less stable regarding asphaltenes, and the ABC mixture, which was the most incompatible mixture, both presented the slowest kinetics of emulsion separation. On the other hand, mixture BC which had the highest compatibility among the other mixtures presented a faster kinetic of emulsion separation.
9
Maddah, Zenah Hani, and Tariq Mohammed Naife. "Demulsification of Water in Iraqi Crude Oil Emulsion." Journal of Engineering 25, no. 11 (November 1, 2019): 37–46. http://dx.doi.org/10.31026/j.eng.2019.11.03.
Full textAbstract:
Formation of emulsions during oil production is a costly problem, and decreased water content in emulsions leads to increases productivity and reduces the potential for pipeline corrosion and equipment used. The chemical demulsification process of crude oil emulsions is one of the methods used for reducing water content. The demulsifier presence causes the film layer between water droplets and the crude oil emulsion that to become unstable, leading to the accelerated of water coalescence. This research was performed to study the performance of a chemical demulsifier Chimec2439 (commercial) a blend of non-ionic oil-soluble surfactants. The crude oils used in these experiments were Basrah and Kirkuk Iraqi crude oil. These experimental work were done using different water to oil ratio. The study investigated the factors that have a role in demulsification processes such as the concentration of demulsifier, water content, salinity, pH, and asphaltene content. The results showed in measuring the droplet size distribution, in Basrah crude oil, that the average water droplet size was between (5.5–7.5) μm in the water content 25% while was between (3.3-4) μm in the water content 7%. The average water droplet size depends on the water content, and droplet size reduced when the water content of emulsion was less than 25%. In Kirkuk crude oil, in water content of 7%, it was between (4.5-6) μm, while in 20%, it was between (4-8) μm, and in 25% it was between (5-8.8) μm. It was found that the rate of separation increases with increasing concentration of demulsifier. For Basrah crude oil at 400ppm the separation was 83%, and for Kirkuk, crude oil was 88%. The separation of water efficiency was increased with increased water content and salt content. In Basrah crude oil, the separation rate was 84% at a dose of salt of 3% (30000) ppm and at zero% of salt, the separation was70.7%. In Kirkuk crude oil, the separation rate was equal 86.2% at a dose of salt equal 3% (30000) ppm, and at zero% of salt, the separation 80%.
10
Ghetiu, Iuliana, Ioana Gabriela Stan, Casen Panaitescu, Cosmin Jinescu, and Alina Monica Mares. "Surfactants Efficiency in Oil Reserves Exploatation." Revista de Chimie 68, no. 2 (March 15, 2017): 273–78. http://dx.doi.org/10.37358/rc.17.2.5435.
Full textAbstract:
The use of surfactants in the process of water separation from crude oil emulsions formed at extraction is an effective solution in the treatment of crude oil. But perfecting this technology to a higher degree of efficiency, in order to destabilize the emulsion formed, requires the determination of the parameters involved in the design and the correlation of the obtained results. This research also aims at finding optimal solutions that increase the degree of water separation from emulsions using surface-effective solutions to destabilize the emulsion layer. This research was basedon data from two wells that extract oil from Barc�u reservoir. To achieve this objective, the composition of crude oil was analyzed, the emulsion characteristics were established and the elected demulsifiers were tested. The study highlights the efficiency of destabilization up to 97.9 mass %.
Dissertations / Theses on the topic "Oil-water emulsions- Crude"
1
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.
Full textAbstract:
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
2
Mehta, Shweta D. "Making and breaking of water in crude oil emulsions." Thesis, Texas A&M University, 2005. http://hdl.handle.net/1969.1/3286.
Full textAbstract:
An understanding of the processes involved in oil spills, and how they interact to alter the composition and behavior of the oil with respect to time is essential to determine an effective oil spill response. The review of past research has shown more focus on the laboratory methods and computerized modeling schemes to estimate the formation and breaking of emulsions after an oil spill. However, relatively less effort has gone into the study of emulsions corresponding to actual field conditions. This research aims to simulate an oil spill at sea by developing a new technique to make water in oil emulsions, without disturbing the marine wildlife. Further, this research also attempts to analyze the viscosities of water in oil emulsions and determine appropriate emulsion breakers for different crude oil emulsions. The overall test design for the study includes a test apparatus for spreading and evaporation, three different crude oils, a mixing chamber to form the emulsion, and emulsion breakers. Experiments in this research attempt to gain a better understanding of the processes that occur after oil spills at sea. In particular, the rate of evaporation of different crude oils and the formation of crude oil emulsions on the sea surface have been investigated. It was observed that different crude oils behave differently when subjected to the same weathering procedure. Results indicate that the behavior of the crude oil on the sea surface, subjected to spreading, evaporation, and emulsification, can be predicted by using the new technique developed in this research. This technique can also assist the development of effective recovery equipments and materials.
3
Shakorfow, Abdelmalik Milad. "Process intensification in the demulsification of water-in-crude oil emulsions via crossflow microfiltration through a hydrophilic polyHIPE polymer (PHP)." Thesis, University of Newcastle Upon Tyne, 2012. http://hdl.handle.net/10443/1745.
Full textAbstract:
In petroleum industry, highly stable water-in-oil (w/o) emulsions are formed during extraction process and these emulsions are stabilized by the indigenous surface active species in the oil. The recovery of crude oil through emulsion breakdown and subsequent separation (demulsification) should be carried out at source in order to avoid costly pumping and cooling of emulsion which enhances emulsion stability. Although conventional methods available for emulsion breakdown using demulsifiers and electric field separation, in the case of viscous crude oils with large amounts of indigenous surfactants, such methods are not satisfactory to achieve on-site oil-water separation. Therefore, such emulsions may have to be chemically treated. It was previously shown that when hydrophilic micro-porous polymers, known as PolyHIPE Polymers (PHPs) were added to the emulsion, it caused emulsion to separate as a result of selective removal of surfactants. This separation process was further enhanced in the presence of electric field. This current study focuses on cross-flow microfiltration of w/o emulsions through a sulphonated hydrophilic microporous polymeric material in the absence or presence of electric field. However, sulphonated PHPs used in the experiments do not have an active membrane layer with pores at micron- or nano- scale. The thickness of the separation layer is ca. 4 mm and pore size is in 10 micrometer range. We used either 50 or 70 vol. % oil phase in the w/o emulsions. Effect of: pore size, crossflow velocity and electric field strength on permeate flux rate decay and separation efficiency of emulsions which are stable for more than 70 days otherwise was investigated. It was found that the permeate flux rate decayed rapidly with crossflow filtration time before the flux reached steady state. The application of electric field enhanced the permeate flux rate. Under steady state conditions, permeate flux rate was not significantly affected by the PHP pore size. Permeate from the crossflow filtration was collected in glass cylinders and allowed to separate under gravity as a function of time. It was found that the demulsification time was affected primarily by the applied electric field, emulsion water content, crossflow velocity and PHP pore size. Demulsification rate increased with increasing electric field and water fraction of emulsion and with decreasing pore size of PHP. Demulsification was achieved within 6-7 hr. The results were interpreted in terms of ‘confinement phenomenon’ in which it was postulated that the PHP filtration media selectively retained the surface active agents and; thus, causing the demulsification of the emulsions. The surface active agents were deposited within the pores of the separation media and; thus, causing flux decay. Although the deposits of surface active agents could break-up due to permeate flow through the separation media, they could not be re-distributed at the oil-water interface to re-stabilize the emulsion. However, some water can be trapped within the oil as oil-in-water-in-oil multiple emulsion which would be more resistant to demulsification.
4
Bresciani, Antonio Esio. "Análise do processo de dessalgação de petróleo - otimização do uso de água." Universidade de São Paulo, 2009. http://www.teses.usp.br/teses/disponiveis/3/3137/tde-20072009-101225/.
Full textAbstract:
Este trabalho visa o estudo da viabilidade da redução do uso de água no processo de dessalgação em refinarias de petróleo. Em uma primeira fase, foi necessário o estudo teórico da separação das emulsões água/óleo. Em seguida, foi desenvolvido um modelo matemático baseado nas forças atuantes nas gotas de água, o que possibilitou a determinação do tempo entre as colisões de pares de gotas e o estabelecimento do critério para que ocorra o fenômeno de coalescência. Esse modelo foi empregado em um sistema desenvolvido com base em autômatos celulares, o qual possibilitou o acompanhamento do processo micro e macroscópico, através do cálculo para o conjunto das gotas, e o acompanhamento visual até a separação da fase contínua. Os experimentos de laboratório, para os quais foi usado equipamento ótico para a medição da intensidade de luz transmitida ou espalhada pelas gotas, possibilitaram avaliar a influência da qualidade da água de mistura no tempo de separação das emulsões. Na unidade industrial, foram realizados testes que permitiram analisar o desempenho das dessalgadoras em diferentes situações operacionais. Os resultados obtidos através dos experimentos de laboratório e da simulação usando o modelo matemático desenvolvido mostraram-se compatíveis com os dados obtidos nos testes na unidade industrial. O trabalho mostrou ser possível alterar os esquemas de usos de água nas dessalgadoras, aumentando a taxa de reciclagem e possibilitando a otimização do consumo de água fresca neste processo, o que resultaria em redução substancial no consumo geral de água na refinaria.The aim of this work is the study of the reduction of water consumption in petroleum desalting processes. The study of the attraction forces acting on the droplets was necessary to know how the emulsion water/oil is separated. A mathematical model based upon these forces was built to calculate the time between each droplets collision and to establish criteria for their coalescence. This model was applied to a system developed based on cellular automata, which allows to follow the process micro and macroscopically. Computations were carried out to the ensemble of droplets and the visual progression, from the start of droplets separation of the continuous phase to the end of the process could be visualized. Laboratory experiments, in which optical equipment was used to measure the light intensity transmitted or scattered by the droplets, allowed to evaluate the influence of the type of mixing water in the separation time of the emulsions. Tests in the industrial unity allowed evaluating the performance of the desalting units at different operating conditions. Conclusions of the laboratory experiments and the results of the mathematical model were compared with results of the industrial tests, showing coherence between them. The work shows that it is possible to simulate the effect of the operating variables and to alter schemes of water use in desalting units, increasing the water recycling rate, allowing optimization of fresh water consumption in this process and reducing the total water consumption in the refinery.
5
Luzinova, Yuliya. "Mid-infrared sensors for hydrocarbon analysis in extreme environments." Diss., Georgia Institute of Technology, 2010. http://hdl.handle.net/1853/41156.
Full textAbstract:
A number of MIR sensing platforms and methods were developed in this research work demonstrating potential applicability of MIR spectroscopy for studying hydrocarbon systems in extreme environments.
First of all, the quantitative determination of the diamondoid compound adamantane in organic media utilizing IR-ATR spectroscopy at waveguide surfaces was established. The developed analytical strategy further enabled the successful detection of adamantane in real world crude oil samples. These reported efforts provide a promising outlook for detection and monitoring of diamondoid constituents in naturally occurring crudes and petroleum samples.
IR-ATR spectroscopy was further utilized for evaluating and characterizing distribution, variations, and origin of carbonate minerals within sediment formations surrounding a hydrocarbon seep site - MC 118 in the Gulf of Mexico. An analytical model for direct detection of 13C-depleted authigenic carbonates associated with cold seep ecosystems was constructed. Potential applicability of IR-ATR spectroscopy as direct on-ship - and in future in situ - analytical tool for characterizing hydrocarbon seep sites was demonstrated.
MIR evanescent field absorption spectroscopy was also utilized to expand the understanding on the role of surfactants during gas hydrate formation at surfaces. This experimental method allowed detailed spectroscopic observations of detergent-related surface processes during SDS mediated gas hydrate formation. The obtained IR data enabled proposing a mechanism by which SDS decreases the induction time for hydrate nucleation, and promotes hydrate formation. Potential of MIR fiberoptic evanescent field spectroscopy for studying surface effects during gas hydrate nucleation and growth was demonstrated.
Next, quantifying trace amounts of water content in hexane using MIR evanescent field absorption spectroscopy is presented. The improvement in sensitivity and of limit of detection was obtained by coating an optical fiber with layer of a hydrophilic polymer. The application of the polymer layer has enabled the on-line MIR detection of water in hexane at low ppm levels. These results indicate that the MIR evanescent filed spectroscopy method shows potential for in-situ detection and monitoring of water in industrial oils and petroleum products.
Finally, quantification of trace amounts of oil content in water using MIR evanescent field absorption spectroscopy is reported. Unmodified and modified with grafted hydrophobic polymer layer silver halide optical fibers were employed for the measurements. The surface modification of the fiber has enabled the on-line MIR analysis of crude oil in water at the low ppb level. Potential application of MIR fiber-optic evanescent field spectroscopy using polymer modified waveguides toward in-situ low level detection of crude oil in open waters was demonstrated.
6
Stoyel, Jason Alexander. "Fundamentals of drop coalescence in crude oil." Thesis, Imperial College London, 2000. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.312176.
Full text
7
Sinker, Alastair Brenton. "An experimental study droplet stability and separation performance in dewatering hydrocyclones." Thesis, University of Southampton, 1995. http://ethos.bl.uk/OrderDetails.do?uin=uk.bl.ethos.387899.
Full text
8
Xia, You. "Experiments on EHD injection, interaction and electrocoalescence of water droplet pairs in oil." Thesis, Université Grenoble Alpes (ComUE), 2016. http://www.theses.fr/2016GREAI039/document.
Full textAbstract:
Lorsque des champs électriques sont appliqués à des mélanges eau-huile, les petites gouttelettes d'eau sont attirées entre elles et se regroupent en gouttes plus grosses. Ce processus d’électrocoalescence rend plus efficace la séparation huile-eau par sédimentation.Des données expérimentales sur l’électrocoalescence de très petites gouttelettes sont nécessaires pour améliorer la compréhension de la dynamique de l'interface eau-huile et pour valider les modèles numériques. La configuration simple étudiée dans ce travail de thèse concerne une petite paire de gouttelettes tombant dans une cuve d'huile modèle et soumise à un champ électrique aligné avec l’axe de symétrie des gouttes et la gravité.La première partie du travail a consisté à générer de façon contrôlée d’une paire de très petites gouttelettes (dans la gamme de diamètres 20-200 microns) alignée avec le champ électrique. La génération de goutte à la demande, par méthode éléctrohydrodynamique (EHD) a été améliorée pour un meilleur contrôle du diamètre et de la charge électrique des gouttelettes injectées à partir d'une aiguille métallique unique. Ceci a été obtenu en appliquant à un ménisque d'eau pendant à l’extrémité de l’aiguille des impulsions électriques de forme optimisée.La caractérisation électrique et hydrodynamique des paires de gouttelettes et leur coalescence sont alors principalement déduites de l'analyse des vitesses de chute, avec et sans application d’un champ électrique à courant continu. Des données complètes de positions des gouttelettes et de leur vitesse en fonction du temps sont déduites de prises de vues vidéo. Une attention particulière a été accordée aux visualisations de très petites gouttelettes tombant à petites vitesses, associant des angles multiples de prise de vue, de forts zooms et des vidéos à grande vitesse.La modélisation des différents termes d'interactions hydrodynamiques et électrostatiques entre les gouttelettes permet de déduire des vitesses enregistrées leur masse charge électrique respectives. Quand se produit une coalescence des deux gouttelettes, un enregistrement de la vitesse de la gouttelette résultante, avec et sans tension électrique appliquée, permet de contrôler la conservation de la masse et de la charge électrique, et la validation du procédé.Un premier ensemble de données est constitué d'environ 70 cas différents, avec différentes paire des gouttelettes (dans une plage de diamètre limitée de façon à ce que les vitesses de chute soient comprises entre 0,1 et 0,3 mm/s) et en faisant varier la tension appliquée à courant continu ou alternatif. L'analyse des résultats et des incertitudes expérimentales et un exemple de comparaison possible avec des simulations numériques utilisant le logiciel Comsol Multiphysics ™, permettent d'effectuer des recommandations pour les travaux futurs.Ce travail a été financé par le projet “Fundamental understanding of electrocoalescence in heavy crude oils”; coordonné par SINTEF Energy Research. Le projet a été soutenu par The Research Council of Norway, dans le cadre du contrat n °: 206976 / E30, et par les partenaires industriels suivants: Wärtsilä Oil & Gas Systems AS, Petrobras et Statoil ASAWhen electric fields are applied in oil-water mixtures small water droplets are attracted to others and merge in larger drops. This electrocoalescence process makes more efficient the oil-water separation by sedimentation.Experimental data on the electrocoalescence of very small droplets will be useful to improve the understanding of the dynamics of water-oil interface and to validate numerical models. The simple configuration studied consists in a small droplet pair falling in stagnant model oil, under electric field aligned with the symmetry axis of the droplet pair and the direction of gravity.First part of the work consisted in the well-controlled generation of very small droplet pair (range 20-200 microns) aligned with electric field. Droplet-on-Demand generation by EHD method was improved for a better control of the diameter and electric charge of droplets injected from a single metallic needle. This was obtained by applying to a pendant water meniscus optimized multistage high voltage electric pulses.Electrical and hydrodynamic characterization of the droplet pairs and their coalescence are then mainly deduced from the analysis of falling velocities, with and without applied DC electric field. A complete data set of droplet position and velocity is deduced from video. A special attention was paid to the visualizations of very small droplet and small falling velocities, involving multiple angle of view, strong zooming and high speed video.Modelling the different terms of hydrodynamic and electrostatic interactions between droplets allows deducing from the recorded velocities their respective mass and electric charge. When coalescence occurs, a record of the resulting single droplet velocity, with and without applied voltage, allows controlling the mass and charge conservations and validating the method.A first data set was constituted of about 70 different cases, with varying droplets pair (with a limited diameter range to remain with falling velocities between 0.1 and 0.3 mm/s) and varying applied DC or AC voltage. Analyses of the results and experimental uncertainties, and example of possible comparison with numerical simulations using Comsol Multiphysics™ software, allow performing some recommendations for future work.This work was funded by the project “Fundamental understanding of electrocoalescence in heavy crude oils”; co-ordinated by SINTEF Energy Research. The project was supported by The Research Council of Norway, under the contract no: 206976/E30, and by the following industrial partners: Wärtsilä Oil & Gas Systems AS, Petrobras and Statoil ASA
9
Walavalkar, Ajey Y. "Combustion of water-in-oil emulsions of diesel and fresh and weathered crude oils floating on water." 2001. http://etda.libraries.psu.edu/theses/available/etd-0317101-204038/.
Full textBook chapters on the topic "Oil-water emulsions- Crude"
1
McMahon, Andrew J. "Interfacial Aspects of Water-in-Crude Oil Emulsion Stability." In Emulsions — A Fundamental and Practical Approach, 135–56. Dordrecht: Springer Netherlands, 1992. http://dx.doi.org/10.1007/978-94-011-2460-7_10.
Full text
2
Stockwell, A., A. S. Taylor, and D. G. Thompson. "The Rheological Properties of Water-in-Crude-Oil Emulsions." In Surfactants in Solution, 1617–32. Boston, MA: Springer US, 1986. http://dx.doi.org/10.1007/978-1-4613-1833-0_39.
Full text
3
LEE, YEIN MING, SYLVAN G. FRANK, and JACQUES L. ZAKIN. "Rheology of Concentrated Viscous Crude Oil-in-Water Emulsions." In ACS Symposium Series, 471–87. Washington, D.C.: American Chemical Society, 1985. http://dx.doi.org/10.1021/bk-1985-0272.ch030.
Full text
4
Giordano, J. P., T. H. Plegue, S. G. Frank, J. L. Zakin, and D. H. Fruman. "A study of concentrated viscous crude oil-in-water emulsions." In Progress and Trends in Rheology II, 302–5. Heidelberg: Steinkopff, 1988. http://dx.doi.org/10.1007/978-3-642-49337-9_102.
Full text
5
Mingyuan, Li, Alfred A. Christy, and Johan Sjøblom. "Water-in-Crude Oil Emulsions from the Norwegian Continental Shelf Part-VI — Diffuse Reflectance Fourier Transform Infrared Characterization of Interfacially Active Fractions from North Sea Crude Oil." In Emulsions — A Fundamental and Practical Approach, 157–72. Dordrecht: Springer Netherlands, 1992. http://dx.doi.org/10.1007/978-94-011-2460-7_11.
Full text
6
Grosso, Jorge L., Maria I. Briceńo, Jose Paterno, and Ignacio Layrisse. "Influence of Crude Oil and Surfactant Concentration on the Rheology and Flowing Properties of Heavy Crude Oil-in-Water Emulsions." In Surfactants in Solution, 1653–73. Boston, MA: Springer US, 1986. http://dx.doi.org/10.1007/978-1-4613-1833-0_41.
Full text
7
Anand, Vikky, and Rochish M. Thaokar. "Stability and Destabilization of Water-in-Crude Oil Emulsion." In Catalysis for Clean Energy and Environmental Sustainability, 707–28. Cham: Springer International Publishing, 2021. http://dx.doi.org/10.1007/978-3-030-65021-6_22.
Full text
8
Akay, G., Z. Z. Noor, and M. Dogru. "Process Intensification in Water-in-Crude Oil Emulsion Separation by Simultaneous Application of Electric Field and Novel Demulsifier Adsorbers Based on Polyhipe Polymers." In ACS Symposium Series, 378–92. Washington, DC: American Chemical Society, 2005. http://dx.doi.org/10.1021/bk-2005-0914.ch023.
Full text
9
Rajamanickam, Karthika. "Technologies Involved in the Demulsification of Crude Oil." In Crude Oil - New Technologies and Recent Approaches [Working Title]. IntechOpen, 2021. http://dx.doi.org/10.5772/intechopen.99743.
Full textAbstract:
Due to the use of enhanced recovery processes that necessitate the use of a considerable amount of water, mature petroleum reservoirs generate crude oil with huge amounts of water. The majority of this water gets emulsified into crude oil during production, increasing viscosity and making flow more difficult, resulting in production, transportation, and refining operational challenges that have an influence on corporate productivity. Natural surfactants with a strong potential to create stable emulsions are naturally mixed with crude oils. Because crudes with a high amount of stable emulsion have a lower value, the stable emulsion must be adequately processed to meet industrial requirements. As a result, basic research on natural surfactants that contribute to emulsion stability is examined in order to effectively separate emulsions into oil and water. This would need a review of various emulsification methods as well as the proper formulation for effective demulsification. The petroleum industry recognizes the importance of an efficient demulsification procedure for treating emulsions. Numerous studies on the mechanisms of emulsification and demulsification have been undertaken for decades. To guarantee optimal hydrocarbon output, effective treatment is required. The present paper is to review reported works on the formation of petroleum emulsions, demulsification treatments, and characteristics of fit-for-purpose demulsifiers as well as research trends in emulsion treatment.
10
Edema, Noyo. "Effects of Crude Oil Contaminated Water on the Environment." In Crude Oil Emulsions- Composition Stability and Characterization. InTech, 2012. http://dx.doi.org/10.5772/36105.
Full textConference papers on the topic "Oil-water emulsions- Crude"
1
Kuo, Tzu-Chi, Adam Schmitt, Arash Nowbahar, Daniel Miller, Decai Yu, Heather Wiles, Kathryn Grzesiak, et al. "Mechanistic Approaches to Break Water-in-Crude Oil Emulsions." In 2022 AOCS Annual Meeting & Expo. American Oil Chemists' Society (AOCS), 2022. http://dx.doi.org/10.21748/qcje2805.
Full textAbstract:
Water-in-oil emulsions are commonly unavoidable and undesirable in the production, transportation, and refining of petroleum and related products. The emulsions are stabilized by a variety of surface-active compounds found in crude oil such as natural surfactants and fine mineral particles. A critical step in the processing of crude oil is to break the interfacial film formed at the oil/water interface to enable the coalescence and separation of water from oil. Demulsifiers are commonly used to promote the water removal process. However, the effectiveness of a demulsifier varies greatly due to the oil sources, water content, and processing. This presentation will describe our research efforts on breaking water-in-oil emulsions focusing on water-in-oil interfacial properties that govern emulsion stability and demulsification. Fundamental studies were done to understand the effect of selected additives on the interfacial behaviors using molecular and dissipative particle dynamics simulations, and microfluidics. The modeling and empirical results show that the effectiveness of an additive is correlated inversely to the coalescence time of two water droplets.
2
Zhang, Jingjun, Dabin Chen, Dafan Yan, Xiaoheng Yang, and Chen Shen. "Pipelining of Heavy Crude Oil as Oil-in-Water Emulsions." In SPE Production Operations Symposium. Society of Petroleum Engineers, 1991. http://dx.doi.org/10.2118/21733-ms.
Full text
3
Adewunmi, Ahmad A., Muhammad Shahzad Kamal, Afeez Gbadamosi, and Shirish Patil. "Natural Extracted Waste Materials for Breaking Crude Oil Emulsion." In SPE Western Regional Meeting. SPE, 2023. http://dx.doi.org/10.2118/213007-ms.
Full textAbstract:
Abstract This study was performed to examine the efficacy of corn husks (CH) fine particles as potential natural demulsifier for breaking crude oil emulsion. Stable emulsions were formed using distilled water/crude oil and oil-water ratio was 4:6. The concentrations of CH particles ranging from 0.25, 0.5, 0.75, and 1% were added into vials containing the prepared emulsions and demulsification test was conducted inside the oven at 75 °C. Rheology was used to illustrate the demulsification mechanism of CH as potential demulsifiers. According to the experimental outcomes, the demulsification activity from the bottle test showed that water removal increased with the increasing CH concentration. The demulsification efficiency (DE) of 0.25, 0.5, 0.75, and 1% CH was 8.33%, 50%, 73.33% and 81.67%, respectively; after 60 minutes of demulsification duration. Rheological characterization showed that the incorporation of CH particles caused the reduction of emulsion viscosity which indicated the breaking of emulsion and separation of oil and water. Optical microscopic analysis revealed the morphologies of emulsion immediately after preparation, as well as oil and water phases after separation.
4
Issa, Roy J., and Emily M. Hunt. "Rheology of water-in-oil emulsions for a medium crude oil." In 2015 International Mediterranean Gas and Oil Conference (MedGO). IEEE, 2015. http://dx.doi.org/10.1109/medgo.2015.7330336.
Full text
5
Altowilib, Ali, Rahul Gajbhiye, Mohamed Mahmoud, and Theis Solling. "Selection and Optimization of Demulsifier Based on Physio-Chemical Characteristics of Emulsion." In Middle East Oil, Gas and Geosciences Show. SPE, 2023. http://dx.doi.org/10.2118/213617-ms.
Full textAbstract:
Abstract The presence of crude oil/water emulsions is a burden in the petroleum industry. It leads to several operational and economic issues related to crude production, transportation, and refining processes. The stability of the emulsified oil is affected by water content, presence of organic/inorganic materials, formation brine salinity, and temperature. In reservoir fluid studies, applying chemical demulsifiers on emulsion samples is common to break the emulsion and reduce the water content to an acceptable level (less than 1 wt. %) to generate representative fluid composition results. However, this process depends heavily on the crude and the water compositions and the type of demulsifier used. An incompatible choice of demulsifier could strengthen the emulsion's stability or alter the fluid composition. This introduces the need to understand specific physiochemical properties to identify the root causes of demulsifier ineffectiveness. In this study, two demulsifiers containing different functional groups (Type 1 and Type 2) were evaluated for their emulsion breakage ability. Nine oil samples from various fields were mixed with formation water in the first round and seawater in the second. The water-oil ratio of 80:20 was achieved using a blender for 1.5 minutes at 300 RPM. Saturates, Aromatics, Resins, and Asphaltene (SARA), viscosity, density, and sulfur content were determined for all oil samples. Furthermore, chemical analysis was conducted on all water samples to determine Total Dissolved Solids (TDS). After applying both demulsifiers at the same concentration (1% of total volume), separated water volumes were measured at 5, 10, 15, and 20 minutes and used to calculate the emulsion separation index (ESI). Results of this work showed that Type 1 demulsifier performed better than Type 2 in the formation water and seawater and while using different oils due to the resistance of the non-ionic surfactant to salinity, polarity, and water hardness. This study shows a methodology for effectively determining the optimum chemical demulsifier type to break emulsions by adequately understanding the chemistry of the oil, brine, resulting emulsions, and demulsifiers used.
6
Hattori, Tokima, Xingjuan Hao, Mai Shimokawara, Yoshitake Kato, Ryuta Kitamura, and Yogarajah Elakneswaran. "Influence of Inorganic Solid Particles in the Formation and Stability of Crude Oil Emulsion." In International Petroleum Technology Conference. IPTC, 2023. http://dx.doi.org/10.2523/iptc-22863-ea.
Full textAbstract:
Abstract Water-in-oil (W/O) emulsion could be formed during the transportation, refining, and storage of crude oils. In the stockpiling tanks, the emulsion and sludge formation were observed by storing of crude oils for a long period of time and cleaning of tanks. It has been reported that the presence of solids affects the emulsion types as well as the stability of emulsions produced. In addition, the surface properties of inorganic particles could influence the crude oil/water interface and thus affect the crude oil-water emulsion stability. Therefore, in this study, the presence of inorganic solid particles on the formation and stability of emulsion was quantitatively evaluated. A crude oil and synthetic brine were used for emulsion evaluation. In addition, calcite and kaolinite were selected as inorganic solid particles. Emulsions were prepared by mixing crude oil and synthetic brine at a ratio in volume of 1:9. The prepared emulsion was allowed to rest for 24 h and then centrifuged to separate crude oil and water. The volume and pH of resolved water were measured to assess emulsion stability in the presence of inorganic solids. It is found that the addition of inorganic solid particles increased the volume of resolved water and destabilize the emulsion compared to that of without inorganic solid particles. The concentration of solids influences the formation of stable emulsion: high concentration decreases the stable emulsion formation. The dissolution of inorganic solids increases the pH of the water and promotes the demulsification due to high surface potential of crude oil. Moreover, the solid particles enhance the formation of oil-in-water-in-oil (O/W/O) emulsion and thus generates unstable emulsion. Increase of temperature and addition of inorganic solids decrease the emulsion height, which was predicted by emulsion layer growth model where coagulation rate constant was a tuning parameter. High value of the coagulation rate constant implies strong coagulation between water droplets and facilitate emulsion instability.
7
Umar, Abubakar A., Ismail B. M. Saaid, and Aliyu A. Sulaimon. "Rheological and stability study of water-in-crude oil emulsions." In INTERNATIONAL CONFERENCE ON ADVANCED SCIENCE, ENGINEERING AND TECHNOLOGY (ICASET) 2015: Proceedings of the 1st International Conference on Advanced Science, Engineering and Technology. Author(s), 2016. http://dx.doi.org/10.1063/1.4965086.
Full text
8
Pilehvari, A., B. Saadevandi, M. Halvaci, and P. E. Clark. "Oil/Water Emulsions for Pipeline Transport of Viscous Crude Oils." In SPE Annual Technical Conference and Exhibition. Society of Petroleum Engineers, 1988. http://dx.doi.org/10.2118/18218-ms.
Full text
9
Rodriguez, Fernancelys, Hadi Belhaj, David Rousseau, and Mohammed AlDhuhoori. "Generation of Complex Emulsions During the Application of Improved Recovery Methods in Venezuelan Heavy and Extra-Heavy Oil Reservoirs: A Critical Review." In ADIPEC. SPE, 2022. http://dx.doi.org/10.2118/211106-ms.
Full textAbstract:
Abstract The formation of emulsions during the production of highly viscous crude oils is one of the biggest issues observed both in cold production and after the application of IOR methods in Venezuelan heavy and extraheavy oil reservoirs, with impact on the lifting of crude oils, separation of phases, fouling, production costs, etc. For the cold production case, the presence of water with strong compositional and salinity variation, coupled with the presence of gas in the case of foamy oil, could generate very stable oil-water and gas-oil emulsions; hence complicating the phenomena after the application of thermal or chemical IOR methods. This article presents a review of: 1) different types of emulsions found in cold production as well as thermal and chemical IOR methods, 2) factors that affect the stability of the emulsions (compositions of crude oil and formation and injection waters, type of injection fluid, temperature, etc.), 3) fluid characterization methods (gravimetric method, droplet size distribution, centrifugation, rheology, etc.), 4) recommended demulsifiers based on laboratory, and field experiences in Venezuela and internationally. These criteria will be reviewed in detail, establishing the main insights associated with the emulsion formation, providing related conclusions and perspectives for treatment and prevention measures. Based on the results of this review, it can be highlighted that the presence of resins and asphaltenes in the crude oil has a fundamental role in the stability of the emulsions found during cold production in the Orinoco Oil Belt and that the composition of the formation water might increase the stability of the emulsions (Mg2+ and Ca2+). The application of thermal as well as diluent injection methods generates emulsions that involve precipitation of asphaltenes, which together with sand production in the process, leads to making phase separation processes more complex. Furthermore, the application of chemical methods could cause phase trapping (for the surfactant case) with impact on chemical losses, and water- in-oil emulsion with high viscosity after the addition of alkali in lab experiments. A worldwide review of field and laboratory remediation methods indicates that possible emulsion treatments include the use of silica nanoparticles, polyglycerol fumarate ester, heavy aromatic naphtha, electrical heaters, among others. This article presents the main insights related to the generation of emulsions in Venezuela and for developing strategies for emulsions breakers adapted to each IOR process. It also covers the effect of water chemistry, oil composition and type of IOR/EOR process on the characteristics of emulsion and emulsion stability, and consequently the impact on the technical and economic criteria of the process.
10
Guo, Liping, Tao Feng, Yang Liu, Xu Chen, Wenbo Li, and Jyh-Ping Hsu. "Characterization of a Water-in-Waxy Crude Oil Emulsion by its Steady Apparent Viscosity." In ASME 2019 Asia Pacific Pipeline Conference. American Society of Mechanical Engineers, 2019. http://dx.doi.org/10.1115/appc2019-7629.
Full textAbstract:
Abstract The rheological properties of water-in-waxy crude oil emulsion depend highly on its forming conditions. Among these, the steady apparent viscosity is capable of characterizing its degree of emulsification. Adopting waxy crude oil in the field, we examine the influence of the water cut, the stirring speed, and the stirring time on the steady apparent viscosity of the emulsions formed under various conditions in this study. A model based on the viscous flow entropy generated in emulsion preparation is applied to correlate the steady apparent viscosity with the key parameters. A regression model is constructed for the dependence of the steady apparent viscosity on the viscous flow entropy, the shear rate, the rheological parameters of blank crude oil, and the wax deposition volume.