Academic literature on the topic 'Crude oil emulsion'
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Journal articles on the topic "Crude oil emulsion"
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Zhang, Hong Jing. "The Influence Faction to the Crude Oil Emulsion Stability." Advanced Materials Research 502 (April 2012): 330–34. http://dx.doi.org/10.4028/www.scientific.net/amr.502.330.
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At present, the exploited crude oil is about 80% in the presence of crude oil emulsion in the world. More and more research to study stability of the crude oil is developed. Firstly, the basal knowledge of the crude oil emulsion and interfacial film are introduced in this paper. The main reason that crude oil can come into being stable emulsion is it has natural emulsifiers, which can form interfacial film, then the author emphasizes on four natural emulsifiers of the crude oil’s components: asphaltenes, gelatine, paraffine and solid particles, which play very important role in the crude oil emulsion’s stability. The natural emulsifiers, such as asphaltenes, gelatine, can be absorbed between water and oil to form interfacial film that has some visco-elasticity. The stronger is interfacial film, the more stable is the crude oil emulsion.
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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.
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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.
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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.
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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 %.
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Abdulla, Firdos M., and Nour Hamid Abdurahman. "DESTABILIZATION OF CRUDE OIL EMULSION VIA ELECTROCOAGULATION METHOD." Journal of Chemical Engineering and Industrial Biotechnology 4, no. 1 (March 1, 2018): 44–52. http://dx.doi.org/10.15282/jceib.v4i1.3882.
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Formation of emulsions during oil production and processing is a costly problem, both in terms of chemicals used and production losses. Conventional ways of breaking crude oil emulsion are disadvantageous from both economic and environmental perspectives. In this paper, the potentials of electrocoagulation technology in destabilization of crude oil emulsion were investigated. The crude oil was obtained from Petronas Refinery Melaka, Malaysia. For stability performance test, Span 80 was used as emulsifier, while for chemical destabilization performance test, Hexylamine was used. The electrocoagulation method was used for destabilization of W/O emulsion. For electrocoagulation destabilization, three factors namely; voltages 15-50 V, current density 1.04-3.94 mAcm- 2, and NaCl concentration 0.5-2.5 g/L. The electrocoagulation destabilization showed that the best water separation efficiency was achieved at voltage 50 V, current density 3.94 mAcm-2, and NaCl concentration 2.5 g/L, whereas the separation efficiency reached at 98%. In addition, electrocoagulation of W/O emulsion separation is advantageous as it was simple to be operated, low cost and more identical, and then successfully applied on destabilization of W/O crude oil emulsions on the industry.
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Canevari, Gerard P. "BASIC STUDY REVEALS HOW DIFFERENT CRUDE OILS INFLUENCE DISPERSANT PERFORMANCE." International Oil Spill Conference Proceedings 1987, no. 1 (April 1, 1987): 293–96. http://dx.doi.org/10.7901/2169-3358-1987-1-293.
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ABSTRACT Previous research has shown that crude oils contain various amounts of indigenous surface active agents that stabilize water-in-oil emulsions. It is also known that crude oils stabilize such emulsions to different extents. One aspect of the study was to investigate the relationship between the emulsion forming tendency of the various crude oils and the level of performance of a chemical dispersant on the particular crude oil. The results of the extensive laboratory test program indicated that dispersant effectiveness is a function of both dispersant type and the specific crude oil. However, there is no apparent correlation between the degree of emulsion-forming tendency of the crude oil, which is a function of the indigenous surfactant content, and effectiveness. A “clean” hydrocarbon, tetradecane (C14), was also tested in order to evaluate the absence of any indigenous surfactants on performance. It was found that tetradecane exhibited a higher level of effectiveness compared to the crude oils for each of the dispersants tested. In essence, the indigenous surfactants in the crude oil, in every instance, reduce dispersant effectiveness but to an unpredictable level. This is probably due to the fact that these agents present in crude oil promote a water-in-oil emulsion. Since the chemical dispersant is formulated to produce an oil-in-water dispersion, the interference of these crude oil surfactants is apparent. Hence, tetradecane would be an ideal test oil since the degree of dispersion of tetradecane by a particular dispersant represents the maximum dispersion effectiveness for that product. In order to establish more definitively the role of the indigenous surfactants, this surfactant phase was successfully separated from nine crude oils representative of different emulsion forming tendencies. It was found that the amount of surfactant residue extracted from the crude oil did correlate with the emulsion forming tendency of the crude oil. Finally, the above separated surfactant residue was added to tetradecane at the same concentrations as in the respective crude oil. As expected, in every instance, the surfactant residue decreased dispersant performance compared to “pure” tetradecane.
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Abdulla, Firdos M., and N. H. Abdurahman. "Demulsification of crude oil emulsion via electrocoagulation method." Journal of Chemical Engineering and Industrial Biotechnology 3, no. 1 (March 1, 2018): 97–105. http://dx.doi.org/10.15282/jceib.v3i1.3878.
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During oil production and processing emulsions were formed and seriously cause problem, both in terms of chemicals used and production losses. The traditional methods of breaking crude oil emulsions are disadvantageous from both economic and environmental perspectives. In this paper, the potentials of electrocoagulation technology in demulsification of crude oil emulsion were investigated. The crude oil obtained from Petronas Ponapean Melaka, Malaysia. For stability performance test, Span 80 was used as emulsifier, while for chemical demulsification performance test,Hexylamine was used. The electrocoagulation method was used for demulsification of W/O emulsion. For electrocoagulation demulsification, three factors namely; voltages 15-50 V, current density 1.04-3.94 mAcm-2, and concentration of NaCl 0.5-2.5 g/L. The electrocoagulation demulsification showed that the best water separation efficiency was achieved at voltage 50 V, current density 3.94 mAcm-2, and NaCl concentration 2.5 g/L, whereas the separation efficiency reached at 98%. Results have shown the potential of electrocoagulation method in separation of water-in-crude oil emulsions, W/O.
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Li, Qiang, Yuhan Zhang, Qing Miao, Lei Chen, Ziyun Yuan, and Gang Liu. "Rheological properties of oil–water Pickering emulsion stabilized by Fe3O4 solid nanoparticles." Open Physics 18, no. 1 (December 31, 2020): 1188–200. http://dx.doi.org/10.1515/phys-2020-0223.
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Abstract Pickering emulsions have attracted extensive attention due to their good properties including easy to manufacture, high stability, and superparamagnetic response. To improve the emulsifying transportation of crude oil, a Pickering emulsion of crude oil and water stabilized by Fe3O4 nanoparticles was prepared and its rheological properties were tested in this research. It was found that the particle size of dispersion droplet polymerization group in stable crude oil Pickering emulsion is negatively correlated with solid content and water content, and the equilibrium apparent viscosity {\mu }_{\text{ap}} of emulsion follows the power law fluid equation. Besides, this kind of Pickering emulsion has higher elasticity of interface membrane, which means by adding functional particles, it obtains good dynamic stability, and thus, has a great application property in crude oil industry.
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Canevari, Gerard P., and Robert J. Fiocco. "CRUDE OIL VANADIUM AND NICKEL CONTENT CAN PREDICT EMULSIFICATION TENDENCY." International Oil Spill Conference Proceedings 1997, no. 1 (April 1, 1997): 309–14. http://dx.doi.org/10.7901/2169-3358-1997-1-309.
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ABSTRACT Most crude oils in contact with water form water-in-oil emulsions. The stability of these emulsions will vary. When spilled crude oil emulsifies, it becomes viscous and expands in volume, becoming more difficult to recover, chemically disperse, or ignite. The ability to better predict the emulsion-forming behavior of a specific crude oil would greatly aid oil spill response decisions. The problem is complex because of the various stabilizing mechanisms. This study identified surface active agents, that is, porphyrins, as key compounds that contribute to the emulsification of crude oil, particularly fresh crude oil. This research not only identified these metal-porphyrin agents but also determined the mechanism for their emulsion stabilization. These porphyrin complexes are known to be associated with the metals vanadium and nickel. Because the vanadium and nickel levels of a specific crude oil are available from its published assay, they can be used to predict the emulsification of oil early in the spill. The study has also established that a concentration level of over 15 ppm of vanadium and nickel is required to form a stable emulsion for fresh crude oil. It should be stressed that the vanadium-nickel index applies to fresh crude oil. A second emulsification mechanism was also observed during this research that was related to the weathering of the crude oil. Extensive data to support this mechanism are presented and may provide a valuable tool for oil spill response.
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Digno, Tagelsir Awad Ahmed. "Effect of Emulsion in Sudanese Crude Oil PalougeField ,Melute Basin." Journal of The Faculty of Science and Technology, no. 6 (January 13, 2021): 89–98. http://dx.doi.org/10.52981/jfst.vi6.607.
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The study was conducted in Palouge Field in Malute Basin Block 3&7 located in the Republic of South Sudan This paper discusses problems related to oil emulsions that have been encountered in Palouge Field. Oil samples collected from 17 Oil Gathering Manifold (OGM), viscosities range from 106cP to over 8159cP (@ 50ºCand API gravities ranged from 13 to 25. Emulsion from 2 up to 33and water cut form (7% water cut to over 77%), Pour Point 30 to 420 .These properties provide an interesting case of operational problems in oil water separation.The main causes of emulsion formation in the investigated fields were water cut, temperature, shear, Pour Point, demulsifier dosage and mixing different crudes. The results show a strong correlation ofPour Point (Paraffinic content which lead to stabilized emulsion)in the crude oil with the water-oil separation index or emulsion tightness. Recommendations are made for reducing and optimizing demulsifier dosage by adding chemical additives,and further comprehensive study should be done to determine the compounds which lead to stabilized emulsion for example Naphthenic compound and Asphaltenic.
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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.
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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%.
Dissertations / Theses on the topic "Crude oil emulsion"
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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.
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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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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.
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Al-Otaibi, Musleh B. "Modelling and optimising of crude oil desalting process." Thesis, Loughborough University, 2004. https://dspace.lboro.ac.uk/2134/8056.
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The history of crude oil desalting/dehydration plant (DDP) has been marked in progressive phases-the simple gravity settling phase, the chemical treatment phase, the electrical enhancement phase and the dilution water phase. In recent times, the proper cachet would be the control-optimisation phase marked by terms such as "DDP process control", "desalter optimisation control" or "DDP automating technology". Another less perceptible aspect, but nonetheless important, has been both a punch listing of traditional plant boundaries and a grouping of factors that play the essential roles in a desalting/dehydration plant (DDP). Nowadays, modelling and optimising of a DDP performance has become more apparent in petroleum and chemical engineering, which has been traditionally concerned with production and refinery processing industries. Today's desalting/dehydration technology finds itself as an important factor in such diverse areas as petroleum engineering, environmental concerns, and advanced technology materials. The movement into these areas has created a need not only for sources useful for professionals but also for gathering relevant information essential in improving product quality and its impact on health, safety and environmental (HSE) aspects. All of the foregoing, clearly establishes the need for a comprehensive knowledge of DDP and emulsion theories, process modelling and optimisation techniques. The main objective of this work is to model and qualitatively optimise a desalting/dehydration plant. In due course, the contents of this thesis will cover in depth both the basic areas of emulsion treatment fundamentals, modelling desalting/dehydration processes and optimising the performance of desalting plants. In addition, emphasis is also placed on more advanced topics such as optimisation technology and process modifications. At the results and recommendation stage, the theme of this work-optimising desalting/dehydration plant will practically be furnished in an applicable scheme. Finally, a significant compendium of figures and experimental data are presented. This thesis, therefore, essentially presents the research and important principles of desalting/dehydration systems. It also gives the oil industry a wide breadth of important information presented in a concise and focused manner. In search of data quality and product on-line-improvement, this combination will be a powerful tool for operators and professionals in a decision support environment.
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Luz, Maciel Santos. "Elementos traço em óleo cru: determinação total e estudo de especiação." Universidade de São Paulo, 2013. http://www.teses.usp.br/teses/disponiveis/46/46136/tde-21032014-120013/.
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O objetivo desta pesquisa foi o desenvolvimento de métodos para: determinação simultânea de Cr/Fe/Ni/V em óleo cru; determinação simultânea de Co/Cu/Pb/Se em óleo cru, gasolina e diesel; determinação monoelementar de Si em óleo cru, gasolina e diesel; e determinação de espécies porfirínicas de Fe/Ni/V em óleo cru, utilizando ultracentrifugação e extração em ponto nuvem, por espectrometria de absorção atômica com forno de grafite e detecção simultânea (SIMAAS). Foram estudadas as condições de preparo das amostras por emulsão, empregando Triton X-100® como surfactante e hexano ou clorofórmio como solventes diluentes do óleo cru. Nas melhores condições, as emulsões foram preparadas em 6% (m v-1) de Triton X-100® com o óleo cru previamente diluído com 125 µL de hexano (nos métodos para as determinações totais dos elementos) ou diluído com 400 µL de clorofórmio (no método para a determinação das espécies porfirínicas). No método envolvendo a determinação simultânea total de Cr/Fe/Ni/V não foi utilizada agitação ultrassônica devido à pequena massa de óleo necessária (50 mg) para análise. Por outro lado, a agitação ultrassônica foi essencial para possibilitar a estabilização de maiores massas de óleo cru (200 mg e 400 mg) na emulsão. A estabilidade da emulsão só foi melhorada com agitação ultrassônica, antes da etapa de diluição com água. Nessa condição, foi possível obter emulsões estáveis com 200 mg ou 400 mg de óleo cru, por 30 min ou mais de 8 h, respectivamente. O programa de aquecimento do forno de grafite foi avaliado em cada caso, com e sem uso de diferentes modificadores químicos (Pd e Mg), especialmente nos métodos de determinação simultânea, em que foi necessário adotar condições de compromisso. Para a determinação monoelementar de Si foi verificado melhora nos parâmetros analíticos (sensibilidade e repetibilidade) com o uso de NbC como modificador permanente combinado com 20 µg de Pd como modificador químico co-injetado. Os LODs estimados para Cr (0,07 µg g-1), Fe (2,15 µg g-1), Ni (1,25 µg g-1), V (1,25 µg g-1), Co (0,02 µg g-1), Cu (0,03 µg g-1), Pb (0,04 µg g-1), Se (0,11 µg g-1) e Si (0,16 µg g-1) foram suficientemente baixos para permitir as determinações dos elementos com boas precisão e exatidão. Análises de materiais de referência forneceram resultados a um nível de confiança de 95%, quando aplicado o teste t>/i> de Student. O fracionamento de porfirinas de Fe/Ni/V foi feito em emulsão de óleo cru combinando com a extração por ponto nuvem (CPE) e ultracentrifugação. Nesse estudo, foi verificado a necessidade do uso de 0,1 mol L-1 de HCl para extração dos elementos associados a espécies organometálicas não porfirínicas. Após a ultracentrifugação da emulsão de óleo cru, os alfaltenos e material particulado foram separados e no sobrenadante permaneceram espécies inorgânicas, compostos organometálicos leves e porfirinas de Fe, Ni e V. Após CPE de outra emulsão de óleo cru permaneceram na fase aquosa espécies inorgânicas e composto organometálicos leves. As concentrações das porfirinas de Fe, Ni e V foram determinadas após a subtração dos resultados obtidos no primeiro (ultracentrifugação) e segundo (CPE) procedimentos.The objective of this research was the methods development for: simultaneous determination of Cr/Fe/Ni/V in crude oil; simultaneous determination of Co/Cu/Pb/Se in crude oil, gasoline and diesel; determination of Si in crude oil, gasoline and diesel; and determination of porphyrin species of Fe/Ni/V in crude oil using graphite furnace atomic absorption spectrometry with simultaneous detection (SIMAAS). It was studied the conditions for the emulsion sample preparation, employing Triton X-100® as surfactant and hexane or chloroform as diluent of the crude oil. Under the best conditions, the emulsions were prepared in 6% (m v-1) of Triton X-100® with crude oil previously diluted with 125 µl of hexane (in methods for total determination of elements) or diluted with 400 µl of chloroform (in the method for determination of porfhyrin species). In the method for the simultaneous determination of Cr/Fe/Ni/V it was not necessary to use ultrasonic agitation due to the small mass of oil needed (50 mg) for analysis. On the other hand, ultrasonic agitation was essential to enable the stabilization of larger masses of crude oil (200 mg and 400 mg) in emulsion. The emulsion stability was improved with ultrasonic agitation, before dilution step with water. In this condition, it was possible to obtain stable emulsions with 200 mg or 400 m;g of crude oil, for 30 min or more than 8 h, respectively. The heating program of graphite furnace was evaluated in each case, with and without use of different chemical modifiers (Pd and Mg), especially in the methods for simultaneous determination, in which was necessary to adopt compromise conditions. For Si determination, was verified significant improvement in analytical parameters (sensitivity and repeatability) with the use of NbC as permanent modifier, combined with co-injected 20 µg of Pd as chemical modifier. The LODs estimated for Cr (0.07 µg g-1), Fe (2.15 µg g-1), Ni (1.25 µg g-1), V (1.25 µg g-1), Co (0.03 µg g-1), Cu (0.03 µg g-1), Pb (0.04 µg g-1), Se (0.11 µg g-1) and Si (0.16 µg g-1) were low enough to allow measurements of the elements with great precision and accuracy. Analysis of reference materials provided results at confidence level of 95%, when applied to the Student\'s t-test. The Porphyrin fractionation of Fe/Ni/V was done on crude oil emulsion by combining cloud point extraction (CPE) and ultracentrifugation. In this method, 0.1 mol L-1 of HCl must be used for extraction of elements associated with the organometallic species different of porfhyrins. After the ultracentrifugation of crude oil emulsion, asfalthene and particulate matter were separated and in the supernatant remained inorganic species, organometallic compounds and porphyrins of Fe, Ni and V. After CPE of another emulsion of crude oil, remained in the aqueous phase only the inorganic and organometallic compound species. The porphyrin concentrations of Fe, Ni and V were determined after the subtraction of the results obtained in the supernatant from the first (centrifugation) and second (CPE) procedures.
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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.
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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
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Flesinski, Lionel. "Étude de la stabilité des émulsions et de la rhéologie interfaciale des systèmes pétrole brut/eau : influence des asphaltènes et des acides naphténiques." Thesis, Pau, 2011. http://www.theses.fr/2011PAUU3022/document.
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La formation d'émulsions eau-dans-huile stables est un problème majeur rencontré par les pétroliers au niveau de la production mais aussi du raffinage. Afin d'essayer de prévoir ce phénomène, Total a développé une méthode de classement des huiles qui permet, à partir de leurs propriétés physico-chimiques, de déterminer a priori leur capacité à former ou non des émulsions stables. Cependant, les mécanismes interfaciaux sous-jacents ainsi que l’influence des molécules tensioactives du brut sur la stabilité des émulsions n’est pas très clair. Notre travail a consisté à étudier la contribution des acides naphténiques et des asphaltènes dans les phénomènes observés. L’étude d’huiles réelles a permis d’établir un lien entre la stabilité des émulsions et la formation à l'interface d'un gel 2D. Les études menées sur les huiles réelles dont les acides naphténiques ont été extraits ont permis de montrer que ces derniers, en compagnie de leurs formes ionisées, les naphténates, ont la capacité de réduire la stabilité des émulsions en diminuant la résistance du gel interfacial, ou même en empêchant sa formation. Les expériences réalisées sur les huiles réelles dépourvues d’asphaltènes ont permis de confirmer le rôle stabilisant des asphaltènes. Les résultats obtenus suggèrent que les asphaltènes s’adsorbent sur le gel 2D déjà formé par des tensioactifs passés de l’huile vers l’eau et le rapprochent ainsi de sa transition vitreuse. La résistance du gel interfacial s'en trouve alors augmentée, ce qui conduit à la formation d'émulsions plus stables. En croisant le classement industriel des bruts opéré par Total et les résultats de l’étude, un mécanisme global, régi par la compétition entre les acides naphténiques, les naphténates et les asphaltènes à l’interface E/H est proposé pour expliquer les différences de stabilité observées avec les différentes huiles. Lorsque les acides et les naphténates sont suffisamment concentrés, ils empêchent la formation du gel interfacial et les émulsions sont peu stables. Lorsqu’ils sont moins concentrés le rôle des asphaltènes peut alors devenir prépondérant en donnant une cohésion plus importante au gel qui se rapproche de sa transition vitreuse, ce qui conduit en général au renforcement de la stabilité des émulsions forméesWater-in-crude oil emulsions are a major issue for oil companies in both production and refining facilities. Thanks to physical and chemical characterizations, Total set a classification which allows the decision of a crude oil ability to create stable emulsions. However the interfacial mechanisms implied and the influence of the indigenous surfactants of crude oil remain unclear. Our work consists in studying the naphthenic acids and asphaltenes contribution to the w/o emulsion stability. The study of realistic crude oils enabled the discovery of a link between the emulsion stability with the formation of a very particular interfacial behavior: a two-imensional gel. Experiments with desacidified oils have proven the destabilizing ability of naphthenic acids and their ionized form, naphthenates. They actually decrease the interfacial gel strength and can even prevent the gel formation. Asphaltenes-free crude oils have permitted to confirm the stabilizing role of asphaltenes. Rather than adsorbing directly on the interface, asphaltenes seem to adsorb on the interfacial gel already formed. The gel strength is thus increased and lead to higher emulsion stability. Thanks to these results and the industrial classification of crude oil developed by Total, a global mechanism explaining the emulsion stability process has been proposed. This mechanism is governed by the competition between asphaltenes, naphthenates and naphthenic acids at the water/oil interface. If the concentration of naphthenic acids and naphthenates is high enough, the interfacial gel cannot be formed and the emulsions are unstable. If the crude oil is not acidic enough, the asphaltenes influence increases dramatically and implies the strengthening of the gel which becomes closer to his glass transition. This generally leads to the formation of more stable emulsions
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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.
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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.
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Koski, A. (Anna). "Applicability of crude tall oil for wood protection." Doctoral thesis, University of Oulu, 2008. http://urn.fi/urn:isbn:9789514287237.
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Abstract
Moisture content control is a very effective way of protecting timber. Treatments with environment-friendly, biodegradable tall oil are known to reduce the capillary water uptake of pine sapwood greatly, but despite the good results achieved there have been two problems that limit the use of tall oil for wood protection, the large amount of oil needed and the tendency for the oil to exude from the wood. This work was undertaken in order to obtain an understanding of the mechanism of wood protection by means of crude tall oil (CTO) and to find technical solutions to the main problems limiting its use for industrial wood protection.
It is shown that the emulsion technique is one way of solving the first problem, as it provides high water-repellent efficiency at considerably lower oil retention levels. The fact that water is used as a thinner in this technique instead of the commonly used organic solvents is beneficial from environmental, economic and safety points of view.
It is also shown that although the drying properties of CTO are inadequate for use as such in wood preservation, its oxidation and polymerization can be accelerated considerably by means of iron catalysts, which prevent the oil from exuding out of the wood. This also increases the water repellent efficiency of CTO treatment.
Most impregnation oils do not dry when applied in large quantities, because they hinder the diffusion of air through the wood, which supplies the necessary oxygen. Limiting of the oil uptake by the means of the emulsion technique disturbs the airflow to a lesser extent, and thus enhances the drying process. Hence, both the emulsion technique and the use of an iron catalyst improve both the water-repellent efficiency of tall oil treatment and the rate of drying of the oil, thus solving the two main problems related to wood impregnation with tall oil in one single-stage treatment which can be used in existing wood preservation plants. This is advantageous from both an industrial and an economic point of view.
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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.
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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.
Books on the topic "Crude oil emulsion"
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Becker, J. R. Crude oil waxes, emulsions, and asphaltenes. Tulsa, Okla: Pennwell Books, 1997.
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Abdel-Raouf, Manar El-Sayed. Crude oil emulsions: Composition stability and characterization. Rijeka, Croatia: InTech, 2011.
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Abdul-Raouf, Manar El-Sayed, ed. Crude Oil Emulsions- Composition Stability and Characterization. InTech, 2012. http://dx.doi.org/10.5772/2677.
Full textBook chapters on the topic "Crude oil emulsion"
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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.
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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.
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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.
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Sjöblom, Johan, Øystein Sæther, Øivind Midttun, Marit-Helen Ese, Olav Urdahl, and Harald Førdedal. "Asphaltene and Resin Stabilized Crude Oil Emulsions." In Structures and Dynamics of Asphaltenes, 337–76. Boston, MA: Springer US, 1998. http://dx.doi.org/10.1007/978-1-4899-1615-0_11.
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French, T. R. "Use of Crude Oil Emulsions To Improve Profiles." In ACS Symposium Series, 405–28. Washington, DC: American Chemical Society, 1988. http://dx.doi.org/10.1021/bk-1988-0373.ch021.
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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.
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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.
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Christenson, H. K. "Studies of Interactions between Surfaces Immersed in Crude Oils." In Emulsions — A Fundamental and Practical Approach, 123–34. Dordrecht: Springer Netherlands, 1992. http://dx.doi.org/10.1007/978-94-011-2460-7_9.
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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.
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Aveyard, R., B. P. Binks, P. D. I. Fletcher, X. Ye, and J. R. Lu. "The Resolution of Emulsions, Including Crude Oil Emulsions, in Relation to HLB Behaviour." In Emulsions — A Fundamental and Practical Approach, 97–110. Dordrecht: Springer Netherlands, 1992. http://dx.doi.org/10.1007/978-94-011-2460-7_7.
Full textConference papers on the topic "Crude oil emulsion"
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M. Moradi, M., M. K. Kazempour, and V. A. Alvarado. "Crude Oil-in-water Emulsion Flooding for EOR." In 74th EAGE Conference and Exhibition incorporating EUROPEC 2012. Netherlands: EAGE Publications BV, 2012. http://dx.doi.org/10.3997/2214-4609.20148427.
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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.
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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.
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Augustina, Ovuema, and Okotie Sylvester. "Emulsion Treatment in the Oil Industry: A Case Study of Oredo Field Crude Oil Emulsion." In SPE Nigeria Annual International Conference and Exhibition. Society of Petroleum Engineers, 2015. http://dx.doi.org/10.2118/178381-ms.
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Thatte, Azam M., and Anil K. Kulkarni. "Mathematical Modeling and Numerical Simulation of Flame Spread Over Water-in-Oil Emulsions." In ASME 2005 International Mechanical Engineering Congress and Exposition. ASMEDC, 2005. http://dx.doi.org/10.1115/imece2005-82788.
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Flame spread characteristics are studied for water-in-oil emulsion layers floating on top of a water body — similar to a scenario in which an accidental oil spill occurs in open, rough sea. A comprehensive mathematical model is developed and numerical solution is obtained for the ignition and flame spread process which takes into account the emulsion break up into oil and water due to heating, oil vaporization, combustion of oil vapor mixed with air in open atmosphere, radiative and convective heat feed back from flames to the condensed phase (consisting of emulsion, oil, and water), and continuation of the emulsion breaking resulting in flame spread till the oil is consumed. Numerical results are compared with experiments conducted on Arabian Medium Crude oil emulsions made with up to 20% weathered oil (light fraction evaporated, by volume), having up to 50% water content in the emulsions. The flame spread rate decreased as the water content and the weathering level increased, with a reasonable agreement between experiments and model. The long term objective of this work is to assist the application of in situ burning as a measure for the cleanup of weathered and emulsified oils.
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Joseph, A., B. Obong, and J. A. Ajienka. "The Impact of Crude Oil Emulsion on Horizontal Separator Efficiency." In SPE Nigeria Annual International Conference and Exhibition. Society of Petroleum Engineers, 2017. http://dx.doi.org/10.2118/189081-ms.
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Khan, J. A., H. H. Al-Kayiem, and M. S. Aris. "Stabilization of Produced Crude Oil Emulsion in the Presence of ASP." In SPE Asia Pacific Enhanced Oil Recovery Conference. Society of Petroleum Engineers, 2015. http://dx.doi.org/10.2118/174671-ms.
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Makeyev, Y. V., A. P. Lifanov, and A. S. Sovlukov. "Microwave measurement of crude oil water content under inversion of water-oil emulsion." In 2010 20th International Crimean Conference "Microwave & Telecommunication Technology" (CriMiCo 2010). IEEE, 2010. http://dx.doi.org/10.1109/crmico.2010.5632827.
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Almohsin, Ayman M., Zainab Alabdulmohsen, Baojun Bai, and Parthasakha Neogi. "Experimental Study of Crude Oil Emulsion Stability by Surfactant and Nanoparticles." In SPE EOR Conference at Oil and Gas West Asia. Society of Petroleum Engineers, 2018. http://dx.doi.org/10.2118/190440-ms.
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Opawale, Adekunle. "Oilfield Emulsion Control: A Major Issue During Heavy Crude Oil Production." In Nigeria Annual International Conference and Exhibition. Society of Petroleum Engineers, 2009. http://dx.doi.org/10.2118/128352-ms.
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Guo, Kai, Yuling Lv, Limin He, Xiaoming Luo, and Donghai Yang. "Investigation on Corrosion Base Characteristics and Deep Dehydration Technology of Micro-Droplets in Oil Pipelines." In ASME 2019 Asia Pacific Pipeline Conference. American Society of Mechanical Engineers, 2019. http://dx.doi.org/10.1115/appc2019-7617.
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Abstract Corrosion is an important cause of steel pipeline failure and oil leakage, especially local pitting corrosion in long distance crude oil pipelines. Deep dehydration is of great significance to pipeline anticorrosion, however, further experimental results show that it is very difficult to achieve deep dehydration by a single electric field. Recent studies have shown that the particle size change of dispersed phase for the emulsion with large droplets after electromagnetic synergistic treatment is more obvious than that of a single electric field. In this study, the effect of micro-droplets on corrosion of oil pipelines are revealed. The role of micro-droplets in the process of microbial corrosion and electrochemical corrosion in a strong or weak acid solution for oil pipelines was summarized. A structural model of on-line tubular electromagnetic synergistic intensification coalescing device was established. The size change of particle of the dispersed phase in emulsions was studied. Crude oil and water were used as experimental materials, and the particle size distribution of dispersed phase in emulsions was tested by the evaluation system. The results showed that mean radius, d10 and d50 of water droplets in emulsion treated by electromagnetic synergism are larger than those treated by a single electric field. Strengthening droplets coalescence by electromagnetic synergism is also effective on emulsions whose particle size of the dispersed phase is less than 100μm. The role of micro-droplets in pitting corrosion is summarized based on corrosion channels. In the process of microbial corrosion and electrochemical corrosion in strong or weak acid solution, the role of water is presented in two aspects like participating in the reaction and providing ion electron transmission media. Analogous to culture medium, micro water droplets can be called corrosion medium for pitting corrosion in long-distance crude oil pipelines. A structural model of on-line tubular electromagnetic synergistic intensification coalescing device was established, including an electric field generation device and a magnetic field excitation component with orthogonal distribution and synchronous synergy. And emulsions are treated by electric and magnetic fields while flowing through the medium channel. The particle size change of dispersed phase in emulsions with average particle size of dispersed phase less than 100μm was experimental studied. It is found that mean radius, d10 and d50 of water droplets in emulsion treated by electromagnetic synergism are larger than that by a single electric field. Therefore, electromagnetic synergism can further enhance the dehydration depth compared with a single electric field.
Reports on the topic "Crude oil emulsion"
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Nemer, Martin B., David L. Lord, and Terry L. MacDonald. Brine-in-crude-oil emulsions at the Strategic Petroleum Reserve. Office of Scientific and Technical Information (OSTI), October 2013. http://dx.doi.org/10.2172/1121934.
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