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Journal articles on the topic 'Crude oil emulsion'
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1
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%.
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Arslan, Dr Mueyyed Akram, and Dr Ghassan Burhan Yaqoob. "Optimization of (RP6000 and MAKS-9150) demulsifiers for separation of water from (Kirkuk / baba, Khbbaz) crude oil emulsion." Journal of Petroleum Research and Studies 10, no. 4 (December 21, 2020): 69–84. http://dx.doi.org/10.52716/jprs.v10i4.368.
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In this study oil-soluble (RP6000 and MAKS-9150) emulsion breakers have been selected for separation of water from Kirkuk / baba (50oC), Khbbaz (40oC) crude oil emulsions and their activity measured using the Bottle test method at different concentration and found the activity of RP6000 demulsified best than MAKS-9150 emulsion breakers. RP6000 separated water (100%) in (15)min., (40)ppm and in (60)min., (20)ppm of demulsified for Kirkuk/ baba Crude oil and for khbbaz Crude oil the (100%) water separation was in (15)min., (80)ppm and in (30)min., (60)ppm and PH effect, salinity, temperature and density of emulsion stability depending on literature were explained for Optimization.
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Guo, Li Ping, Lei Wang, and Yi Min Zhang. "Applicability of Emulsion Viscosity Models to Crude Oil Emulsion." Advanced Materials Research 581-582 (October 2012): 50–53. http://dx.doi.org/10.4028/www.scientific.net/amr.581-582.50.
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The rheology behavior of waxy crude emulsion is an important basic information on safeguard research of crude oil-water flow. The non-newtonian characteristics of apparent viscosity of three kinds of waxy crude emulsions were studied experimentally around condensation point; three apparent viscosity forecasting models were evaluated by least-square regressions based on experimental data of shear balance and the average absolute deviation was taken as the measurement of fitness of a model to experimental data. It is concluded that the Pal-Rhodes model, whose relative deviation can be as high as 80%, is the worst forecasting model, but it need the least experiment data to obtain model parameters, only water cut was needed. Elgibaly model has the best forecasting results, the average absolute deviation of forecasting results of three waxy crude emulsions under the condition of different temperature, water cut and shear rate were all less than 15%, but compared with the other two models, Elgibaly model needs the most parameters.
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Kolotova, Daria S., Yuliya A. Kuchina, Lyudmila A. Petrova, Nicolay G. Voron’ko, and Svetlana R. Derkach. "Rheology of Water-in-Crude Oil Emulsions: Influence of Concentration and Temperature." Colloids and Interfaces 2, no. 4 (November 26, 2018): 64. http://dx.doi.org/10.3390/colloids2040064.
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The effect of aqueous phase content and temperature North Sea crude oil emulsion viscoelastic behavior has been studied. Heavy crude oil from the North Sea is of high viscosity and is capable of forming stable water-in-crude oil (w/o) emulsions without introducing any synthetic surfactants. The aqueous phase volume content was varied from 1 to 40%, and the temperature was varied from 0 to 30 °C. The w/o emulsion viscosity increased sharply when the aqueous phase content exceeds 20%, being more pronounced at the lower temperatures. The viscosity flow curves for emulsions containing more than 20% aqueous phase demonstrate non-Newtonian behavior, in contrast to crude oil, which is Newtonian. The coefficients in the master curve describing the viscosity-temperature dependence were determined. Oscillatory rheological tests showed that the loss modulus substantially exceeds the storage modulus which indicates the liquid-like state of the emulsions.
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Salam, K. K., A. O. Alade, A. O. Arinkoola, and A. Opawale. "Improving the Demulsification Process of Heavy Crude Oil Emulsion through Blending with Diluent." Journal of Petroleum Engineering 2013 (April 21, 2013): 1–6. http://dx.doi.org/10.1155/2013/793101.
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In crude oil production from brown fields or heavy oil, there is production of water in oil emulsions which can either be controlled or avoided. This emulsion resulted in an increase in viscosity which can seriously affect the production of oil from sand phase up to flow line. Failure to separate the oil and water mixture efficiently and effectively could result in problems such as overloading of surface separation equipments, increased cost of pumping wet crude, and corrosion problems. Light hydrocarbon diluent was added in varied proportions to three emulsion samples collected from three different oil fields in Niger delta, Nigeria, to enhance the demulsification of crude oil emulsion. The viscosity, total petroleum hydrocarbon, and quality of water were evaluated. The viscosity of the three emulsions considered reduced by 38, 31, and 18%. It is deduced that the increase in diluent blended with emulsion leads to a corresponding decrease in the value of viscosity. This in turn enhanced the rate of demulsification of the samples. The basic sediment and water (BS&W) of the top dry oil reduces the trace value the three samples evaluated, and with optimum value of diluent, TPH values show that the water droplets are safe for disposal and for other field uses.
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Beetge, Jan H., and Bruce Horne. "Chemical-Demulsifier Development Based on Critical-Electric-Field Measurements." SPE Journal 13, no. 03 (September 1, 2008): 346–53. http://dx.doi.org/10.2118/93325-pa.
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Summary Resolution of water-and-oil emulsions is critical to the oilfield industry. A wide variety of undesirable emulsions are formed during the production, handling, and processing of crude oil. Although various methods are used, dehydration of crude oils is achieved mostly by gravitational sedimentation, normally at elevated temperatures and with the addition of chemical demulsifiers. The quantitative evaluation of emulsion stability by a critical-electric-field (CEF) technique was developed to play a significant role in chemical-demulsifier research. It was found that the CEF technique is useful not only in the evaluation of water-in-oil-emulsion stability, but also in studying the mechanisms of stabilization and demulsification. A method was developed to study the mechanism of emulsion stabilization in terms of flocculation and coalescence behavior of a crude-oil emulsion. The effect of chemical demulsifiers on emulsion stability was evaluated in terms of the method developed in this study. By following this approach, it is possible to determine the relative amount of energy required for both flocculation and coalescence in the presence of a chemical demulsifier. Introduction The inevitable creation and subsequent resolution of water-in-oil emulsions during the production and processing of crude oils are of significant importance in the oilfield industry. These emulsions, which typically could be any combination of water-in-oil, oil-in-water, or complex emulsions, are diverse in their nature and stability. The majority of oilfield emulsions are resolved by the application of chemical demulsifiers in special processes under specific conditions. The stability of crude-oil emulsions is influenced by many variables; therefore, and chemical demulsifiers are developed specifically for each application to achieve optimum economic efficiency. Emulsion stability of water-in-oil emulsions encountered in the oilfield industry can be evaluated with various methods (e.g., determining droplet size and distribution, determining the amount of water resolved as a second phase, analyzing moisture of the oil phase, and more-sophisticated methods such as interfacial rheology). Sullivan et al. (2004) suggested the use of CEF as a method to provide information for stability-correlation development. Commercial separation of a dispersed aqueous phase from typical crude oil by electrostatic methods is well-known and dates to the early 20th century (Cottrell 1911; Cottrell and Speed 1911). Electrostatic dehydration technology is still being developed and refined to play an important role in challenging oilfield applications (Warren 2002). The use of CEF, as a method to evaluate water-in-oil-emulsion stability, has been developed recently by Kilpatrick et al. (2001). In their CEF technique, a sample of water-in-oil emulsion is injected between two parallel electrode plates. A direct-current voltage is applied between the two electrodes and is increased in incremental steps, with continuous monitoring of the conductivity or the amount of electrical current through the oil sample. Fig. 1 shows a simple diagram of the CEF technique. In response to the increasing applied electric field, the water droplets tend to align themselves to form agglomerated columns of droplets, which form a conducting bridge once a critical voltage (or electric field) has been reached. The strength of the electric field at which the sample shows a sharp increase in conductivity (increase in current through sample, between the two electrode plates) is recorded as the CEF. By this method, relative emulsion stability is compared quantitatively in terms of the CEF value and expressed in units of kV cm-1. In contrast to the method of Sjöblom, we have used alternating current with parallel-plate electrodes at the tip of a probe, which was submerged in the hydrocarbon medium. Comparison of crude-oil emulsions by CEF techniques is well-documented (Sullivan et al. 2004; Aske et al. 2002), but no reference to the use of CEF in chemical-demulsifier development could be found. It is the purpose of this study to develop the CEF technique for application in chemical-demulsifier research.
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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.
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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.
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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.
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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.
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Pramudono, B., and H. B. Mat. "Malaysian Crude Oil Emulsions : Stability Study." REAKTOR 6, no. 1 (June 13, 2017): 29. http://dx.doi.org/10.14710/reaktor.6.1.29-34.
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The stability of water-in-oil emulsion of some Malaysian crude oils was studied with particular emphasis on effect of interfacial active components existed in the crude oil, i.e. asphaltene, resin and wax. The emulsion stability was studied by measuring the volume of water or oil phase separated in variation with time, water hold up, and the heights of the sedimenting/coalescing interfaces during the separation at various temperatures. The study investigated the influence of asphaltene, resin and wax on emultion stability if it`s present in the crude oil alone, together or combination one of the others. The result show that the interfacial active component that stabilize emulsion is asphaltene. The resin and wax do not form stale emulsion either aloneor together. There is a correlation between emulsion stability and physicochemical properties of crude oil which showed that higher asphaltene content in the crude oil would form more stable emultion. Increased temperature was found to cause instability of emultion. Keywords : emultion stability, crude oil, asphaltene, resin and wax
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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.
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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.
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Sulaiman, Shaharin A., Mohamad Nazmi Z. Moni, and Siti Norazilah Ahmad Tamili. "Flow of Water-Oil Emulsion through an Orifice." MATEC Web of Conferences 225 (2018): 03002. http://dx.doi.org/10.1051/matecconf/201822503002.
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The oil-in-water (O/W) and water-in-oil (W/O) emulsions are two common types of emulsions found in oil production industry. While stable O/W may be beneficial in transporting crude oil, stable W/O poses a flow assurance problem that leads to disruptions and losses in oil production line. This study examines the behaviour of both types of emulsion (40:60, 50:50 and 60:40 water-oil emulsion, vol. basis) subjected to 3/4D, 1/2D and 1/4D orifices within a pipeline. The study confirms that oil and water may form emulsion with only mechanical agitation and dynamic flow in the pipeline and without the presence of any emulsifying agent. The flow rate and the velocity of all emulsions were found to drop with the reduction of orifice diameter.
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Thayee Al-Janabi, Omer Yasin, Miran Sabah Ibrahim, Ibrahim F. Waheed, Amanj Wahab Sayda, and Peter Spearman. "Breaking water-in-oil emulsion of Northern Iraq’s crude oil using commercial polymers and surfactants." Polymers and Polymer Composites 28, no. 3 (August 13, 2019): 187–98. http://dx.doi.org/10.1177/0967391119868118.
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Water (W) and oil (O) normally mix during production and while passing through valves and pumps to form a persistent water-in-oil (W/O) emulsion, which is a serious restriction in oil production and transporting and refining processes. The objective of this work is to treat emulsions of two crude oil samples labeled KD1 and DGH2 using commercial polymers and surfactants which are also known as demulsifiers. Hydrophile–lipophile balance (HLB) in the demulsifier structure has demonstrated a great effect on breaking W/O emulsion. Emulsion breakers with low HLB value showed better reduction in the dynamic IFT, high diffusivity at the W/O interface, and accelerated coalescence of water droplets. Concomitantly, high emulsion temperatures were found to reduce the interfacial film viscosity and accelerate water droplets coalescence. A maximum water separation efficiency (WSE) of 97% was achieved in the case of KD1 and 88% for DGH2, and using a (1:1) polymer blend demulsifier further increased WSE to 99% after 100 min.
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Olarasu, Lacramioara, Maria Stoicescu, Ion Malureanu, and Ion Onutu. "Considerations for Using a Hydraulic Fracturing Fluid for Breaking Crude Oil Emulsion from Reservoir." Revista de Chimie 69, no. 6 (July 15, 2018): 1498–500. http://dx.doi.org/10.37358/rc.18.6.6354.
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In the oil industry, crude oil emulsions appear very frequently in almost all activities, starting with drilling and continuing with completion, production, transportation and processing. They are usually formed naturally or during oil production and their presence can have a strong impact on oil production and facilities. In this paper we addressed the problem of oil emulsions present in a reservoir with unfavorable flow properties. It is known that the presence of emulsions in a reservoir can influence both flow capacity and the quality of its crude oil, especially when they are associated with porous medium�s low values of permeability. Considering this, we have introduced a new procedure for selecting a special fluid of fracture. This fluid has two main roles: to create new flow paths from the reservoir rock to wells; to produce emulsion breaking of emulsified oil from pore of rocks. Best fracturing fluid performance was determined by laboratory tests. Selected fluid was then used to stimulate an oil well located on an oil field from Romania. In the final section of this paper,we are presenting a short analysis of the efficiency of the operation of hydraulic fracturing stimulation probe associated with the crude oil emulsion breaking process.
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Strøm-Kristiansen, Tove, Alun Lewis, Per S. Daling, Jorunn Nerbø Hokstad, and Ivar Singsaas. "WEATHERING AND DISPERSION OF NAPHTHENIC, ASPHALTENIC, AND WAXY CRUDE OILS." International Oil Spill Conference Proceedings 1997, no. 1 (April 1, 1997): 631–36. http://dx.doi.org/10.7901/2169-3358-1997-1-631.
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ABSTRACT The chemical composition and physical properties of a crude oil determine the behavior of the oil and the way its properties will change when the oil is spilled at sea. Reliable knowledge of the oil's behavior will enable the most effective countermeasure techniques to be used in a spill situation. A diverse range of crude oils is coming into production in the North Sea. The weathering behavior and chemical dispersibility of three very different crude oils—Troll (naphthenic), Balder (asphaltenic), and Nome (waxy)—have recently been thoroughly investigated through bench- and meso-scale experiments. The naphthenic crude oil was also exposed to full-scale studies in the North Sea. This study shows that emulsion formation, the viscosity of emulsion, and the potential for dispersing emulsions by dispersant treatment may vary greatly for the different crude oils. It would be impossible to predict these differences with existing oil-weathering models based on fresh oil properties alone. Especially for abnormal (e.g., highly asphaltenic, waxy) crude oils, the weathering and dispersibility behavior can be revealed only by experimental work. The findings have important implications for effective oil spill response planning, particularly for estimating the most appropriate “window of opportunity” and for optimizing a dispersant application strategy for crude oils.
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Jing, Jiaqiang, Jiatong Tan, Haili Hu, Jie Sun, and Peiyu Jing. "Rheological and Emulsification Behavior of Xinjiang Heavy Oil and Model Oils." Open Fuels & Energy Science Journal 9, no. 1 (August 9, 2016): 1–10. http://dx.doi.org/10.2174/1876973x01609010001.
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Transparent model oils are commonly used to study the flow patterns and pressure gradient of crude oil-water flow in gathering pipes. However, there are many differences between the model oil and crude oils. The existing literatures focus on the flow pattern transition and pressure gradient calculation of model oils. This paper compares two most commonly used model oils (white mineral oil and silicon oil) with Xinjiang crude oil from the perspectives of rheological properties, oil-water interfacial tensions, emulsion photomicrographs and demulsification process. It indicates that both the white mineral oil and the crude oils are pseudo plastic fluids, while silicon oil is Newtonian fluid. The viscosity-temperature relationship of white mineral oil is similar to that of the diluted crude oil, while the silicon oil presents a less viscosity gradient with the increasing temperature. The oil-water interfacial tension can be used to evaluate the oil dispersing ability in the water phase, but not to evaluate the emulsion stability. According to the Turbiscan lab and the stability test, the model oil emulsion is less stable than that of crude oil, and easier to present water separation.
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Kaur, Harvin, and Azuraien Jaafar. "Interfacial Tension Prediction of Readily-Mixed Waxy Crude Oil Emulsion at Pour Point Temperature." Key Engineering Materials 818 (August 2019): 62–71. http://dx.doi.org/10.4028/www.scientific.net/kem.818.62.
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In the industry, stubborn emulsion still constitutes up to 20% of the total emulsion volume. The existing remediation strategies for emulsion treatment rely heavily on the study of heavy crude oil emulsion. However, minimal information is available on integrating interfacial rheology with emulsion stability on waxy crude oil emulsion. The proposed research provides a study to the development of integration between interfacial rheology and emulsion stability so that it can be a quick assessment but an accurate method to measure emulsion stability. The primary objectives of the research are to provide an extensional study to the design development of a comprehensive interfacial rheology protocol for the assessment of emulsion stability by developing a method of testing and monitoring the interfacial rheology and to investigate the demulsification ability of the waxy crude oil emulsion subjected to microbial treatment. The novelty of this study is to use the newly developed measurement protocol via interfacial rheology to predict emulsion stability. Application of the microbes on waxy crude oil to breakdown the water-in-oil emulsion using a rheometer will also be explored. The treatment is targeted to disintegrate the interfacial layer within the emulsion leading to better oil recovery. Rheological properties of the emulsion will be monitored upon the microbial injection to analyze the effects of the treatment on the rheology of emulsion. The outcomes from this research is that the newly developed protocol will predict emulsion stability that could resolve the stubborn emulsion issues via the developed interfacial rheology protocol, which could be time-saving and increases the production efficiency. This research paper is a study to develop a correlation on surface tension and interfacial tension between crude oil, water and a readily-mixed emulsion.
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Hussain, Fatima A., Julio Zamora, Ivonne M. Ferrer, Maureen Kinyua, and Jesús M. Velázquez. "Adsorption of crude oil from crude oil–water emulsion by mesoporous hafnium oxide ceramics." Environmental Science: Water Research & Technology 6, no. 8 (2020): 2035–42. http://dx.doi.org/10.1039/d0ew00451k.
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An environmentally benign, mechanically stable, and renewable mesoporous hafnium oxide ceramic synthesized via a sol–gel process has exhibited 99.9% removal capacity of crude oil from an oil-in-water emulsion.
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Ganeeva, Yulia M., Tatiana N. Yusupova, Ekaterina E. Barskaya, Alina Kh Valiullova, Ekaterina S. Okhotnikova, Vladimir I. Morozov, and Lucia F. Davletshina. "The composition of acid/oil interface in acid oil emulsions." Petroleum Science 17, no. 5 (April 23, 2020): 1345–55. http://dx.doi.org/10.1007/s12182-020-00447-9.
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Abstract In well stimulation treatments using hydrochloric acid, undesirable water-in-oil emulsion and acid sludge may produce and then cause operational problems in oil field development. The processes intensify in the presence of Fe(III), which are from the corroded surfaces of field equipment and/or iron-bearing minerals of the oil reservoir. In order to understand the reasons of the stability of acid emulsions, acid emulsions were prepared by mixing crude oil emulsion with 15% hydrochloric acid solutions with and without Fe(III) and then separated into free and upper (water free) and intermediate (with water) layers. It is assumed that the oil phase of the free and upper layers contains the compounds which do not participate in the formation of acid emulsions, and the oil phase of the intermediate layers contains components involved in the formation of oil/acid interface. The composition of the oil phase of each layer of the emulsions was studied. It is found that the asphaltenes with a high content of sulfur, oxygen and metals as well the flocculated material of protonated non-polar oil components are concentrated at the oil/acid interface. In addition to the above, in the presence of Fe(III) the Fe(III)-based complexes with polar groups of asphaltenes are formed at the acid/oil interface, contributing to the formation of armor films which enhance the emulsion stability.
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Riaza, Stephanie, Farid B. Cortés, and Julián Otalvaro. "Emulsions with heavy crude oil in presence of nanoparticles." Boletín de Ciencias de la Tierra, no. 36 (July 1, 2014): 55–68. http://dx.doi.org/10.15446/rbct.n36.46282.
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A study about the use of silica nanoparticles in crude oils from the Castilla field and the effects on stability, drop size and emulsion viscosity was carried out. The interest in the use of this type of nanoparticles is created by the inversion effect that these produce in the W/O emulsion at high water cuts upper than 48%. The emulsion is transformed in W/O/W being the latter the least viscous due to the water is the external phase and it allows to the crude oil slides easily on any surface. In this study, two types of naturally emulsified crude oil with different water cuts and a synthetic emulsion were used. This kind of behavior created by nanoparticles over the emulsion could be an alternative solution to the viscosity, fluidity and mobility problems that affect the extraction and transportation in heavy crude oil.
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Ekott, Emmanuel. "CORRELATION OF ASPHALTENE SOLVATION WITH STABILITY OF CRUDE OIL EMULSION USING SCALING EQUATIONS." International Journal of Engineering Science Technologies 4, no. 3 (May 29, 2020): 19–29. http://dx.doi.org/10.29121/ijoest.v4.i3.2020.87.
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Due to the simplicity of scaling equations and its applicability to colloid chemistry, the scaling theory is widely used in studying emulsion properties such as force profiles. Scaling equations were developed for the studied samples for correlation of asphaltene solvation with stability of crude oil emulsions. Correlations were made for viscosity and percentage water resolved by varying the volume concentration of toluene in heptol mixture that was used as solvent for the asphaltene re-dissolution. The study shows that tuning the composition of heptol allows fine control of colloidal forces between asphaltene surfaces in an organic solvent and therefore determines the stability state of the emulsion. Statistically derived correlation equations provide for a range in the aromaticity of the crude medium for which an optimum stability is observed and therefore gives good understanding on the control of emulsion stability. The study further shows that emulsion inversion can be achieved by adjusting the concentration of surfactant.
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Saad, M. A., Mohammed Kamil, N. H. Abdurahman, Rosli Mohd Yunus, and Omar I. Awad. "An Overview of Recent Advances in State-of-the-Art Techniques in the Demulsification of Crude Oil Emulsions." Processes 7, no. 7 (July 21, 2019): 470. http://dx.doi.org/10.3390/pr7070470.
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The processing of crude oil often requires the extraction of a large amount of water. Frequently, crude oil is mixed with water to form water-in-crude oil emulsions as the result of factors such as high shear at the production wellhead and surface-active substances that are naturally present in crude oil. These emulsions are undesirable and require demulsification to remove the dispersed water and associated inorganic salts in order to meet production and transportation specifications. Additionally, the demulsification of these crude oil emulsions mitigates corrosion and catalyst poisoning and invariably maximizes the overall profitability of crude oil production. Recently, there has been growing research interest in developing workable solutions to the difficulties associated with transporting and refining crude oil emulsions and the restrictions on produced water discharge. Therefore, this paper reviews the recent research efforts on state-of-the-art demulsification techniques. First, an overview of crude oil emulsion types, formation, and stability is presented. Then, the parameters and mechanisms of emulsification formation and different demulsification techniques are extensively examined. It is worth noting that the efficiency of each of these techniques is dependent on the operating parameters and their interplay. Moreover, a more effective demulsification process could be attained by leveraging synergistic effects by combining one or more of these techniques. Finally, this literature review then culminates with propositions for future research. Therefore, the findings of this study can help for a better understanding of the formation and mechanisms of the various demulsification methods of crude oil to work on the development of green demulsifiers by different sources.
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Jiang, Jian Fang, Mei Qin Lin, Xue Qin Xu, Ming Yuan Li, and Zhao Xia Dong. "Effect of Reaction of NaOH and Daqing Crude Oil on Oil/Water Interfacial Properties and Emulsion Stability." Advanced Materials Research 781-784 (September 2013): 2389–95. http://dx.doi.org/10.4028/www.scientific.net/amr.781-784.2389.
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The oil/water interfacial properties and the stability of the emulsion of ASP flooding in Daqing Oilfield were investigated with the measurement of interfacial tension, interfacial shear viscosity,Zeta potential and turbidity of the oil/water system. The results show that, after NaOH has reacted with Daqing crude oil for a long time, the interfacial tension between the aqueous phase and Daqing model oil decreases. The absolute value of the Zeta potential of the surface of oil droplets increases. The changes of the interfacial shear viscosity between the aqueous phase and the oil phase do not appear to be obvious. The stability of O/W emulsion formed by Daqing model oil and the aqueous phase is enhanced. After NaOH has reacted with crude oil for 1d, the interfacial tension between oil phase and simulated water, Zeta potential and the stability of the oil/water emulsion become higher than that of the emulsion without NaOH. However, after NaOH has reacted with crude oil for 10 d and 30 d, respectively, the interfacial tension between oil phase and simulated water, Zeta potential and the stability of the O/W emulsion are lower than that of the emulsion with the same reaction for 1d.
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Nadirova, Zhanna, Oleksandr Ivakhnenko, Manap Zhantasov, Gulmira Bimbetova, and Kazim Nadirov. "Ultrasound-assisted dewatering of crude oil from Kumkol oilfield." Chemical Bulletin of Kazakh National University, no. 2 (June 30, 2021): 4–10. http://dx.doi.org/10.15328/cb1217.
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Reducing the water content of crude oil is a necessary step in preparing oil for transportation and processing. This task is complicated by the presence of stable water-in-oil emulsions. The most widely used approach to oil demulsification is exploring chemical demulsifiers. However, the high cost and impossibility of regenerating the latter require the search for new ways to destroy water-oil emulsions. One of the promising areas is the use of ultrasound. This paper presents the results of studies on the ultrasonic treatment of four samples of emulsions with different water content (8.74; 15; 25 and 30 vol.%) based on oil from the Kumkol oilfield (Kazakhstan). Samples of emulsions were subjected to ultrasonic action at a frequency of 40 kHz for 5-60 min at a temperature of 70±1°C, followed by settling for 40 min at the indicated temperature. The influence of the initial water content in the emulsion, the acoustic intensity, as well as the duration of ultrasonic treatment on the dewatering ratio was investigated. It was found that the residual water content in the oil was 5.04- 7.82 vol.%. Ultrasonic treatment of crude oil from the Kumkol oilfield can be used for preliminary dewatering, to subsequently reduce the consumption of chemical demulsifiers.
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Visintin, Ruben F. G., Thomas P. Lockhart, Romano Lapasin, and Paolo D’Antona. "Structure of waxy crude oil emulsion gels." Journal of Non-Newtonian Fluid Mechanics 149, no. 1-3 (February 2008): 34–39. http://dx.doi.org/10.1016/j.jnnfm.2007.07.008.
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Ghannam, Mamdouh T. "Water-in-Crude Oil Emulsion Stability Investigation." Petroleum Science and Technology 23, no. 5-6 (May 2005): 649–67. http://dx.doi.org/10.1081/lft-200033001.
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Fingas, Merv. "OIL SPILL DISPERSION STABILITY AND OIL RE-SURFACING." International Oil Spill Conference Proceedings 2008, no. 1 (May 1, 2008): 661–65. http://dx.doi.org/10.7901/2169-3358-2008-1-661.
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ABSTRACT This paper summarizes the data and the theory of oil-in-water emulsion stability resulting in oil spill dispersion re-surfacing. There is an extensive body of literature on surfactants and interfacial chemistry, including experimental data on emulsion stability. The phenomenon of resurfacing oil is the result of two separate processes: de stabilization of an oil-in-water emulsion and desorption of surfactant from the oil-water interface which leads to further de stabilization. The de stabilization of oil-in-water emulsions such as chemical oil dispersions is a consequence of the fact that no emulsions are thermodynamically stable. Ultimately, natural forces move the emulsions to a stable state, which consists of separated oil and water. What is important is the rate at which this occurs. An emulsion is said to be kinetically stable when significant separation (usually considered to be half or 50% of the dispersed phase) occurs outside of the usable time. There are several forces and processes that result in the destabilization and resurfacing of oil-in-water emulsions such as chemically dispersed oils. These include gravitational forces, surfactant interchange with water and subsequent loss of surfactant to the water column, creaming, coalescence, flocculation, Ostwald ripening, and sedimentation. Gravitational separation is the most important force in the resurfacing of oil droplets from crude oil-in-water emulsions such as dispersions. Droplets in an emulsion tend to move upwards when their density is lower than that of water. Creaming is the de stabilization process that is simply described by the appearance of the starting dispersed phase at the surface. Coalescence is another important de stabilization process. Two droplets that interact as a result of close proximity or collision can form a new larger droplet. The result is to increase the droplet size and the rise rate, resulting in accelerated de stabilization of the emulsion. Studies show that coalescence increases with increasing turbidity as collisions between particles become more frequent. Another important phenomenon when considering the stability of dispersed oil, is the absorption/desorption of surfactant from the oil/water interface. In dilute solutions, much of the surfactant in the dispersed droplets ultimately partitions to the water column and thus is lost to the dispersion process. This paper provides a summary of the processes and data from some experiments relevant to oil spill dispersions.
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Rondon, B. "Experimental Characterization of Admittance Meter With Crude Oil Emulsions." International Journal of Electronics, Communications, and Measurement Engineering 10, no. 2 (July 2021): 51–59. http://dx.doi.org/10.4018/ijecme.2021070104.
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Measuring water content is useful in the oil industry to quantify the actual amount of oil being produced. This extent is used in the processes of control and transfer of custody in tank farms, flow stations, and others. In this study, to determine the water content with an admittance measuring device, a characterization was performed with emulsions to identify the behavior of the sensor against this type of fluid. The device has facing electrodes parallel flat. Emulsions O/W and W/O were prepared in the laboratory with heavy oil at laboratory temperature conditions. The capacitance measurement is used to calculate the value of relative permittivity of the fluid (εm) and conductance is used to calculate the conductivity of the mixture (σm). The results of water content measurements showed the sensor response is related to the continuous phases of the emulsions. In addition, these measurements indicated that a characterization of the electrical behavior of the emulsions, as well as the effect of the formulation of the emulsion, can be made using this equipment.
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Bęben, Dariusz. "The effectiveness of chemicals used in the process of transmitting crude oil from the well to the processing plant." Nafta-Gaz 76, no. 11 (November 2020): 774–83. http://dx.doi.org/10.18668/ng.2020.11.02.
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Chemicals are added to crude oil to ensure that it flows from the well to the processing plant. Depending on the composition of the reservoir fluids being extracted (crude oil, reservoir water, natural gas), paraffin may be separated from the crude oil, hydrates may be formed from reservoir water and natural gas, and the combination of reservoir water and crude oil may form an emulsion. Those situations should be avoided to ensure continuous flow from the wellbore to the processing plant. To this end, chemicals, paraffin inhibitors, hydrate inhibitors, and demulsifiers are used. Based on the literature on the subject and on the author’s own experience from observing technological processes, research methods were proposed to assess the effectiveness of chemicals used to ensure the continuity of crude oil flow. The crude oil selected for the tests was characterised by a high content of paraffins, asphaltenes, chloride ions, and water. To determine the onset of paraffin precipitation, tests were conducted based on a change in viscosity and a coupon method – determining the weight gain on a coupon to check the effectiveness of a paraffin inhibitor. The rate of emulsion separation was evaluated in separating funnels. The water released from crude oil often leaches the salt contained within it. Various demulsifiers were used to investigate the separation of emulsions and the purification of oil from salts; silicone demulsifiers in particular were considered. To determine the change in the amount of salt in crude oil, a conductometric measurement was performed. The amount of demulsifier used for phase separation was determined by changing the surface tension. The proposed solution for the use of chemicals to transport and purify crude oil yields tangible economic benefits. The article summarises the research procedures and presents the results for selected crude oil and chemicals.
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Mohammed, R. A., A. I. Bailey, P. F. Luckham, and S. E. Taylor. "Dewatering of crude oil emulsions 3. Emulsion resolution by chemical means." Colloids and Surfaces A: Physicochemical and Engineering Aspects 83, no. 3 (March 1994): 261–71. http://dx.doi.org/10.1016/0927-7757(93)02706-k.
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Lewis, Alun, Per S. Daling, Tove Strøm-Kristiansen, Atle B. Nordvik, and Robert J. Fiocco. "WEATHERING AND CHEMICAL DISPERSION OF OIL AT SEA." International Oil Spill Conference Proceedings 1995, no. 1 (February 1, 1995): 157–64. http://dx.doi.org/10.7901/2169-3358-1995-1-157.
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ABSTRACT Small-scale laboratory methods were used to simulate the weathering processes that occur when crude oil is spilled at sea. Changes caused by evaporation and water-in-oil (w/o) emulsification were studied separately. W/o emulsions were assessed for chemical dispersibility using the Institut Français du Petrole (IFP) and Mackay-Nadeau-Steel-man (MNS) methods. Larger scale experiments were performed in a meso-scale flume. Crude oil was weathered for three days and then sprayed with dispersant. The results show that emulsion breaking is an important part of the mechanism of chemical dispersion. IFP, MNS, and Warren Spring Laboratory (WSL) tests, conducted on w/o emulsions recovered from the flume, produced much lower levels of dispersion than did treatment in the flume. The standard test procedures do not permit emulsion breaking to proceed to the extent observed in the flume. A sea trial also was conducted. Preliminary evaluation of the results shows that dispersant application partially broke the w/o emulsion that had rapidly formed. Dispersion proceeded at a slow rate but the treated slick was removed from the surface more rapidly than the control slick. The degree of dispersion was difficult to quantify by visual observation due to the weather conditions. A combination of remote sensing, surface sampling, and subsurface fluorometry provided a more reliable estimate.
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Fingas, Merv, and Ben Fieldhouse. "HOW TO MODEL WATER-IN-OIL EMULSION FORMATION." International Oil Spill Conference Proceedings 2005, no. 1 (May 1, 2005): 647–54. http://dx.doi.org/10.7901/2169-3358-2005-1-647.
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ABSTRACT Water-in-oil mixtures were grouped into four states or classes: stable, mesostable, unstable, and entrained water. Only stable and mesostable states can be characterized as emulsions. These states were established according to lifetime, visual appearance, complex modulus, and differences in viscosity. Water-in-oil emulsions made from crude oils have different classes of stability as a result of the asp haltene and resin contents, as well as differences in the viscosity of the starting oil. In this paper a new numerical modelling scheme is proposed and is based on empirical data and the corresponding physical knowledge of emulsion formation. The density, viscosity, saturate, asphaltene and resin contents are used to compute a class index which yields either an unstable or entrained water-in-oil state or a meso-stable or stable emulsion. A prediction scheme is given to estimate the water content and viscosity of the resulting water-in-oil state and the time to formation with input of wave-height.
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Zhang, Fu Sheng, Jian Ouyang, Feng Wang, Xin Fang Feng, Chun Bao Ma, and De Wei Wang. "Some Key Problems Encountered for Demulsifier Research." Advanced Materials Research 1033-1034 (October 2014): 22–25. http://dx.doi.org/10.4028/www.scientific.net/amr.1033-1034.22.
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Main reasons, of which viscous crude emulsion and chemical flooding emulsion are difficult to demulsify, is that their compositions and structures have tremendous differences to water flooding emulsion. To resolve main difficulties encountered in demulsifier research today, such as demulsification of viscous crude oil emulsion, demulsification of chemical flooding emulsion, some research value routes, such as increasing aromaticity, molecular weight and branch degree of demulsifier molecule, and leading double-function groups meeting W/O type and O/W type emulsion and groups with alkyl carbon number matching equivalent alkyl carbon number of the crude oil into demulsifier molecule, were suggested according to demulsification mechanisms and their emulsion characteristics, and action mechanisms of the above-mentioned research routes were elaborated at the same time.
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Juwarkar, Asha, P. Sudhakar Babu, Kirti Mishra, and Megha Deshpande. "APPLICATION OF BIOSURFACTANT IN OIL SPILL MANAGEMENT." International Oil Spill Conference Proceedings 1993, no. 1 (March 1, 1993): 503–4. http://dx.doi.org/10.7901/2169-3358-1993-1-503.
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ABSTRACT Surfactants are surface active agents which reduce surface tension and interfacial tension between two immiscible phases and help in emulsification. Toxicity, nonbiodegradability, and limited structural types of chemical surfactants have initiated the need for effective substitutes. Biosurfactants, which are synthesized by specific microbial cultures, have surface active properties comparable to chemical surfactants. They are compounds that can help in oil spill cleanup operations without presenting the problems posed by chemical surfactants. Two bacterial cultures were isolated from oil-contaminated soil and were used for biosurfactant production. The biosurfactants produced by the Bacillus licheniformis, BS1, and Pseudomonas aeruginosa, BS2, in mineral media containing glucose as the carbon source belong to the class of lipoprotein and glycolipid, respectively. They were found to reduce the surface and interfacial tension of water and water-hexadecane systems from 72 dynes/cm and 40 dynes/cm to 28 to 30 dynes/cm and 1 to 3 dynes/cm, respectively. These results were comparable with chemical surfactants with respect to surface tension reduction (Slic Gone 34 dynes/cm and Castrol 30 dynes/cm). The low interfacial tension allows the formation of stable emulsion. The two cultures were grown on different substrates, namely, glucose, mannitol, glycerol, hexadecane, oily sludge, and crude oil. Emulsion formation of hexadecane in water was tested with the cell-free broth containing biosurfactant from the respective substrate broths. Emulsions of 56 percent stability to 100 percent stability were obtained from these biosurfactant-containing broths. Both biosurfactants were able to emulsify crude oil. A surfactant's ability to form a stable emulsion is the first step in oil spill cleanup. The emulsified oil can then be acted upon very easily by the microorganisms under study. Therefore, the biosurfactants produced by the microorganisms under study offer a good potential for use in oil spill cleanup.
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Hai, Duong Ngoc, Nguyen Van Diep, Ha Ngoc Hien, Nguyen The Duc, Phung Dinh Thuc, Nguyen Thuc Khang, Ha Van Bich, and Tong Canh Son. "Rheological properties of emulsion of crude oil and water." Vietnam Journal of Mechanics 21, no. 4 (December 30, 1999): 213–30. http://dx.doi.org/10.15625/0866-7136/10003.
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In the paper the rheological properties of crude oil of White Tiger oil-field (Vietnam) and its emulsion with sea-water, including measurement results and analytical approximation formulae for wide range of pressure, temperature and water concentration, are presented. As it is known, the crude oil of White Tiger oil-field is a high-paraffin and high-viscous oil. At the low temperature (T ≤ 40°C) it behaves as non-Newtonian fluid of Bingham-Shvedov group. Therefore, beside the effective viscosity, the effective dynamic shear stress is also measured and approximated. The rheological properties of crude oil and emulsion of crude oil and water are also measured and approximated for the case when the mixture contains 0.1% chemical reagent ES-3363.
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Fang, Hongbo, Mingxia Wang, Xiaoyun Liu, Weinan Jin, Xiangyang Ma, Xiangyu Meng, and Feng Yan. "Study of Influences of Fracture Additives on Stability of Crude Oil Emulsion." Open Petroleum Engineering Journal 11, no. 1 (November 30, 2018): 118–28. http://dx.doi.org/10.2174/1874834101811010118.
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Background: A hydraulic fracture is a key technology to increase production of the low permeability oil fields. Fracture additives such as gels, friction reducers, pH adjusters and clay stabilizers were injected into the underground. While more than 50% of the fracture fluid remains underground. The residue of fracture fluid comes out with the produced liquid (a mixture of crude oil and water) in the subsequent oil recovery process, which results in a highly stable crude oil-water emulsion. Objective: The stability and stable mechanism of the emulsion with fracture fluid have been experimentally investigated. Materials and Methods: The influences of fracture additives and components of crude oil on the stability of emulsion were investigated by bottle test and microscopic examination. The interfacial tension and modulus of dilation were explored by a spinning drop interfacial tension meter and an interface expansion rheometer, respectively. Results: The fracture additives played the key role on the emulsion stability. On one hand, the interface energy of oil-water was reduced by friction reducer (IFT was decreased from 24.0 mN/m to 1.9 mN/m), which was a favor for the formation of an emulsion. On the other hand, the dilational modulus of crude oil-water film was increased by hydroxypropyl guar and pH adjuster (Na2CO3) to form a viscoelastic film, which resulted in a highly stable emulsion. Conclusion: The residual fracture fluid accompanied by produced liquid resulted in a highly stable emulsion. The emulsion with fracture additives was difficult to be broken, which may affect the normal production of the oil field. A positive strategy such as developing demulsifier with high efficient should be put onto the schedule.
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Cao, Renyi, Linsong Cheng, and Y. Zee Ma. "Model for Rheological Behavior of Crude Oil and Alkali-Surfactant- Polymer Emulsion." Open Fuels & Energy Science Journal 7, no. 1 (October 3, 2014): 55–61. http://dx.doi.org/10.2174/1876973x01407010055.
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Characterization of rheological behavior of alkali-surfactant-polymer (ASP) solution and oil emulsion is difficult, due to the complex chemical components and various physiochemical reactions with oil during chemical flooding. Through rheological experiments of ASP and crude oil emulsion, this paper presents the studies on influencing factors of rheological behavior, including interfacial tension, polymer and water cut, and discusses the stability mechanism of ASP and crude oil emulsion. The relationships among viscosity, interfacial tension, water cut and sheer rate were built through fitting the experimental data. The model and calculation can be used to more accurately simulate the ASP flooding in oil reservoirs.
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Buist, Ian, James McCourt, Joseph V. Mullin, Nick W. Glover, Charlene Hutton, and Jim McHale. "In Situ Burning Wave Tank Tests at Prudhoe Bay, Alaska1." International Oil Spill Conference Proceedings 1999, no. 1 (March 1, 1999): 1269–72. http://dx.doi.org/10.7901/2169-3358-1999-1-1269.
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ABSTRACT A series of research burns was carried out in the fall of 1997 in Prudhoe Bay, Alaska, in a new wave tank purpose-built for oil spill research and training. These tests were the culmination of a 3-year research project by Alaska Clean Seas (ACS) and S.L. Ross into the effects of oil type, emulsification, temperature and waves on in situ burning in Arctic open water conditions. The 1997 experimental program involved conducting mid-scale burns with fresh and weathered Alaska North Slope (ANS) and Milne Pt. crude oils and emulsion slicks in waves, including tests involving the addition of emulsion breakers. Emulsion breakers are surface active chemicals which are added at very low dosages (1:500 to 1:5000) to petroleum emulsions to promote separation of the emulsion into discrete oil and water phases.
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Nora Mamulaishvili, Gaioz Partskhaladze, Gocha Chavleshvili, Otar Janelidze, and Nigar Salimova. "Research results on the effects of magnetic fields on crude oil." Global Journal of Engineering and Technology Advances 5, no. 3 (December 30, 2020): 050–58. http://dx.doi.org/10.30574/gjeta.2020.5.3.0108.
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The paper presents the results of the process of demulsification of crude oil, well No. 15 of the Supsa field. The reasons for the formation of persistent petroleum emulsion are considered, the component composition of crude oil is determined, including the content of the amount of formation water. The experiments were carried out at low (20-30)Hz and high (50-80) Hz frequencies of the magnetic field. The destruction of the oil-water emulsion was carried out without heat treatment under conditions of stabilization of the magnetic field and demulsifier Alkan 202. The technological scheme and parameters of crude oil dehydration are given. The influence of the magnetic field on the rate of destruction of the water-oil emulsion and the amount of released water is shown.
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Sokolovic, Dunja, Radmila Secerov-Sokolovic, and Slobodan Sokolovic. "Rheology of unstable mineral emulsions." Chemical Industry 67, no. 2 (2013): 293–301. http://dx.doi.org/10.2298/hemind120216070s.
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In this paper, the rheology of mineral oils and their unstable water emulsion were investigated. The oil samples were domestic crude oil UA, its fractions UA1, UA4 and blend semi-product UP1, while the concentration of oil in water emulsions was in the range from 1 up to 30%. The results were analyzed based on shear stress. The oil samples UA, UA1 and UP1 are Newtonian fluids, while UA4 is pseudoplastic fluid. The samples UA and UA4 show higher value of shear stress (83.75 Pa, 297 Pa), then other two samples UA1 and UP1 (18.41 Pa, 17.52 Pa). Rheology of investigated oils due to its complex chemical composition should be analyzed as a simultaneous effect of all their components. Therefore, structural composition of the oils was determined, namely content of paraffins, naphthenes, aromatics and asphaltenes. All samples contain paraffins, naphthenes and aromatics but only oils UA and UA4 contain asphaltenes as well. All investigated emulsions except 30% EUA4 are Newtonian fluids. The EUA4 30% emulsion shows pseudoplastic behaviour, and it is the only 30% emulsion among investigated ones that achieves lower shear stress then its oil. The characteristics of oil samples that could have an influence on their properties and their emulsion rheology, were determined. These characteristics are: neutralization number, interfacial tension, dielectric constant, and emulsivity. Oil samples UA and UA4 have significantly higher values of neutralization number, dielectric constants, and emulsivity. The sample UA has the lowest value of interface tension and the greatest emulsivity, indicating that this oil, among all investigated, has the highest preference for building emulsion. This could be the reason why 20% and 30% emulsions of the oil UA achieve the highest shear stress among all investigated emulsions.
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Umar, Abubakar A., Ismail M. Saaid, Aliyu A. Sulaimon, and Rashidah M. Pilus. "Predicting the Viscosity of Petroleum Emulsions Using Gene Expression Programming (GEP) and Response Surface Methodology (RSM)." Journal of Applied Mathematics 2020 (January 6, 2020): 1–9. http://dx.doi.org/10.1155/2020/6215352.
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This paper summarizes an investigation of certain operating parameters on the viscosity of petroleum emulsions. The production of crude oil is accompanied by emulsified water production, which comes along with various challenges like corroding the transport systems and catalysts poisoning during petroleum refining in the downstream. Several process variables are believed to affect the ease with which emulsified water can be separated from emulsions. Some of the issues have not been extensively examined in the literature. The simplicity with which water is separated from petroleum changes with age (after formation) of the emulsion; notwithstanding, this subject has not been investigated broadly in literature. This study tries to assess the correlation between aging time, water cut, crude oil viscosity, water viscosity and amount of solids and viscosity of petroleum emulsions. To achieve that, a response surface methodology (RSM) based on Box-Behnken design (BBD) was used to design the experiment. Synthetic emulsions were prepared from an Offshore Malaysian Crude oil based on the DoE design and were aged for 7 days. The emulsions viscosities were measured at 60-degree Celsius using an electromagnetic viscometer (EV100). The broad pressure and temperature range of the HPHT viscometer permit the imitation of acute conditions under which such emulsions may form. The data obtained from the RSM analysis was used to develop a prediction model using gene expression programming (GEP). It was discovered that the viscosity of water has no effect on the viscosities of the studied emulsions, as does the water cut and amount of solids. The most significant factor that affects emulsion viscosity is the aging time, with the emulsion becoming more viscous over time. This is believed to be imminent because of variations in the interfacial film structure. This is followed by the amount of solids, also believed to be as a result of increasing coverage at the interface of the water droplets, limiting the movements of the dispersed droplets (reduced coalescence), thereby increasing the viscosity of the emulsions.
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Stelmaszewski, Adam, Tadeusz Król, and Henryk Toczek. "Light scattering in Baltic crude oil - seawater emulsion." OCEANOLOGIA 51, no. 3 (September 30, 2009): 405–14. http://dx.doi.org/10.5697/oc.51-3.405.
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