Journal articles on the topic 'Oil-water emulsions- Crude'
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Nagy, Roland, Andrea Elekes, László Bartha, and Árpád Vágó. "Rheological characterization of crude oil-water emulsions." Epitoanyag - Journal of Silicate Based and Composite Materials 68, no. 4 (2016): 98–104. http://dx.doi.org/10.14382/epitoanyag-jsbcm.2016.17.
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Abouther Thalib Halboose, Mudhaffar Yacoub Hussein, and Raheem Jafar Aziz. "Study the effect of Water content and Temperature on the stability of Crude Oil/Water Emulsions." Journal of the College of Basic Education 20, no. 86 (February 2, 2023): 987–92. http://dx.doi.org/10.35950/cbej.v20i86.9912.
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During the crude oil production, water-in-oil stable emulsions may be created. Water which is naturally present in oil reservoirs mixes with crude oil to form very stable emulsions due to very high shear rates and zones of turbulence encountered at the wellhead and pipe of production. The formation of these emulsions is generally caused by the presence of resins, asphaltenes, wax and naphtenic acid which play the role of "natural emulsifiers. The aim of this study was to focus on some important factors in the formation and stabilize crude oil/water emulsions. These factors are the water content, which varies from oil field to another and to understand its role in the Stability of the emulsion, which vary depending on the oil fields. Another factor is the temperature at which the physicist has a role in a large non-oil emulsions Stability. The study deals with the effect of water content and temperature on the stability of crude oil emulsion. The emulsion was prepared by mixing the crude oil and desired content of water and shaking by hand. The volume percent of water were studied in this paper to the total volume of crude oil emulsion (10, 20, 30, 40, 50, 60) and temperature were (20, 30, 40, 50) OC. The results showed that, the emulsion stability decrease with increase water concentration. Change in temperature had a significant effect where the higher temperature became unstable emulsions
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N. H. Abdurahman and H. A. Magdib. "Surfactant (UMP) for emulsification and stabilization of water-in-crude oil emulsions (W/O)." Maejo International Journal of Energy and Environmental Communication 2, no. 2 (May 22, 2020): 18–21. http://dx.doi.org/10.54279/mijeec.v2i2.245027.
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The purpose of this research is to look into the formulation and evaluation of concentrated water-in-oil (W/O) emulsions stabilized by UMP NS-19-02 surfactant and their application for crude oil emulsion stabilization using gummy Malaysian crude oil. A two-petroleum oil from Malaysia oil refinery, i.e., Tapis petroleum oil and Tapis- Mesilla blend, were utilized to make water-in-oil emulsions. The various factors influencing emulsion characteristics and stability were evaluated. It was discovered that the stability of the water-in-oil emulsion improved by UMP NS-19-02 improved as the surfactant content rises, resulting in the decline of the crude oil-water interfacial tension (IFT). Nevertheless, the most optimum formulation of W/O emulsion was a 50:50 W/O ratio with 1.0% surfactant. Additionally, raising the oil content, salt concentration, duration and mixing speed, and pH of the emulsion resulted in higher emulsion stability. It also raised the temperature of the initial mixing, which significantly decreased the formulated emulsions' viscosity. The results showed that stable emulsions could be formed using the UMP NS-19-02 surfactant.
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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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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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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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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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Gentili Nunes, Denise, Jarlene Da Conceição Silva, Giovani Cavalcanti Nunes, Matheus Delduque Lopes da Silva, and Elizabete Fernandes Lucas. "Crude oils mixtures: compatibility and kinetics of water-in-oil emulsions separation." DYNA 89, no. 223 (September 9, 2022): 67–74. http://dx.doi.org/10.15446/dyna.v89n223.99911.
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Some oil fields produce from different reservoirs, which may be incompatible generating precipitates. These precipitates are often asphaltenes, which can be an emulsion stabilizing agent negatively affecting the oil treatment processes. In this work, the influence of oil incompatibility on the stabilization of water-in-oil emulsions was studied. Emulsions were evaluated from three different oils (A, B and C) and their mixtures (AB, AC, BC and ABC). The results showed that there is a relationship between separation kinetics of emulsions and asphaltene precipitation. The separation kinetics of the emulsions was faster for more compatible oils. We observed that oil A, which was the less stable regarding asphaltenes, and the ABC mixture, which was the most incompatible mixture, both presented the slowest kinetics of emulsion separation. On the other hand, mixture BC which had the highest compatibility among the other mixtures presented a faster kinetic of emulsion separation.
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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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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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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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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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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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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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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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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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Aysel Gasimzadeh, Aysel Gasimzadeh. "INVESTIGATION OF EFFECT OF NEW REAGENT COMPOSITIONS ON VARIOUS CRUDE OIL EMULSIONS OF AZERBAIJAN." PAHTEI-Procedings of Azerbaijan High Technical Educational Institutions 10, no. 06 (October 10, 2021): 04–13. http://dx.doi.org/10.36962/pahtei1006202104.
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The article is devoted to the decomposition of strong water-crude oil emulsions formed during the preparation of crude oil for transportation. In the petroleum industry, there is a great need to develop new chemicals to improve the degradation efficiency of stable water- crude oil emulsions. Decomposition of strong water-oil emulsions is considered a key part of crude oil preparation for transportation. Therefore, the development of new demulsifying compositions to improve the degradation efficiency of stable crue oil emulsions remains relevant. This paper presents the results of studies of dehydration processes of Azerbaijani oils and emulsions depending on the degree of watering. The composition is based on Disulfan 4411, Disulfan 13280, Sarola 412, Difron 9426, ND-12 and Gossipol, they were also used to prepare Azerbaijani oil for transportation during laboratory tests of demulsification efficiency (except Difron 9426). During laboratory tests, it was determined that the best results on the degree of residual dehydration of petroleum phases were achieved using a composition called KAV-22. Keywords: Muradhanly, Bulla, Balakhany, Neft dashlari, Dehydration, Surahany, KAV-22.
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Algburi, Dr Abbas K. "Continuous Separation Process of Water-in-Crude Oil Emulsion by Simultaneous Application of an Electrical Field Combined with a Novel Absorbent Based on Functionalised PolyHIPE Polymer." Journal of Petroleum Research and Studies 11, no. 4 (December 20, 2021): 91–113. http://dx.doi.org/10.52716/jprs.v11i4.565.
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During the extraction process of crude oil, the removal of water from a high stability water-in-crude oil emulsions is life-threatening for the production of a profitable product. However, several technologies of separation exist today, e.g. stripping columns, centrifugal separators, coalescence separators, vacuum distillation systems and gravity separators, almost all of these approaches are not able to completely remove water from water-in-crude oil emulsions besides their high cost.
In this study, the preparation of a high internal phase emulsion (HIPE) was achieved on a laboratory scale. Subsequently, it was polymerized and sulphonated to produce a hydrophilic macroporous polyHIPE polymer (PHP) called silane (vinyl trimethoxy silane) PHP with a relatively high surface area of 104 m 2/g. It demonstrates high water absorption capability in addition to its ability to remove surface active substances such as Mg, Ca, Na and Cl, from crude oil which cause crude oil emulsification.
The rates of demulsification of water-in-crude oil emulsions were examined in high AC field under various emulsion inlet flow rates from 100 ml/min to 1500 ml/min and different applied voltages from 1-5 kV (equivalent to 14-69 kV/m) by using a model of an electrostatic separator combined with silane PHP as absorber. It was found that the best separation efficiency was 91% with applied voltage of 5 kV and emulsion inlet flow rate of 100 ml/min. When the spent silane PHP was reused in the demulsification process under similar conditions, a separation efficiency of up to 73% was achieved. Also, it was noticed that the separation efficiency was increased with the increase in applied voltage and reduction in the inlet flow rate of emulsion. Moreover, the original or spent silane PHP were able to remove the undesired metals present in the crude oil.
Keywords: Demulsification; Emulsion flow rate; Separation efficiency; Electrostatic Separator; Electric field strength.
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Mohammed, Sawsan A. M., and Sally D. Maan. "The Effect of Asphaltene on the Stability of Iraqi Water in Crude Oil Emulsions." Iraqi Journal of Chemical and Petroleum Engineering 17, no. 2 (June 30, 2016): 37–45. http://dx.doi.org/10.31699/ijcpe.2016.2.5.
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In the present work, asphaltenes and resins separated from emulsion samples collected from two Iraqi oil wells, Nafut Kana (Nk) and Basrah were used to study the emulsion stability. The effect of oil resins to asphaltene (R/A) ratio, pH of the aqueous phase, addition of paraffinic solvent (n-heptane), aromatic solvent (toluene), and blend of both (heptol) in various proportions on the stability of emulsions had been investigated. The conditions of experiments were specified as an agitation speed of 1000 rpm for 30 minutes, heating at 50 °C, and water content of 30%. The results showed that as the R/A ratio increases, the emulsion will be unstable and the amount of water separated from emulsion increases. It was noticed that the emulsion of Nk crude oil became more stable at basic pH range, and reached to completely stabilized emulsion at pH=12. Whereas Basrah emulsion was stable in both acidic and basic pH ranges. Results indicated that toluene gave a good solubility for asphaltene, and a higher water separation for both crude oil emulsions.
A mathematical model to determine the kinetic constants that characterize the coalescence in the emulsions was also developed.
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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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Asaadian, Hamidreza, and Milan Stanko. "Experimental Characterization and Evaluation of Crude Spiking Influence on Oil/Water Dispersed Flow in Pipe." Molecules 28, no. 17 (August 31, 2023): 6363. http://dx.doi.org/10.3390/molecules28176363.
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This study centers around examining the impact of introducing varying (small) quantities of crude oil into mineral oil (Exxsol D60) on the resultant properties of dispersions and emulsions in oil–salty-water mixture properties such as rheology, droplet size distribution, separation duration, and interfacial tension. The experimentation encompassed bottle tests and a compact flow loop configuration featuring a 2 m horizontal pipe segment. The findings indicate that blends of oil infused with crude oil, combined with salty water at water ratios of 25% and 50%, necessitate an extended duration for separation and for the establishment and stabilization of interfaces, in contrast to mixtures of unaltered oil and saline water. To illustrate, in samples with spiking concentrations ranging from 200 to 800 ppm within a 25% water fraction, the separation period escalates from 51 s to 2 min and 21 s. Interestingly, when the water fraction increased to 75 percent, the impact of crude oil spiking on separation time was minimal. The analysis revealed that the Pal and Rhodes emulsion viscosity model yielded the most accurate predictions for the viscosity of resulting emulsions. The introduction of crude oil spiking elevated emulsion viscosity while diminishing interfacial tension from 30.8 to 27.6 mN/m (800 ppm spiking). Lastly, a comparative assessment was performed between droplet size distributions in the devised dispersed pipe flow and observed in an actual emulsion system comprising crude and salty water.
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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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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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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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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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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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Sun, Qi, Zhao-Hui Zhou, Lu Han, Xin-Yuan Zou, Guo-Qiao Li, Qun Zhang, Fan Zhang, Lei Zhang, and Lu Zhang. "How to Regulate the Migration Ability of Emulsions in Micro-Scale Pores: Droplet Size or Membrane Strength?" Molecules 28, no. 4 (February 9, 2023): 1672. http://dx.doi.org/10.3390/molecules28041672.
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Micro visualization has become an important means of solving colloid and interface scientific problems in enhanced oil recovery. It can establish a relationship between a series of performance evaluations of an oil-water interface under macroscopic dimensions and the actual application effect in confined space, and more truly and reliably reflect the starting and migration behavior of crude oil or emulsion in rock pores. In this article, zwitterionic surfactant alkyl sulfobetaine (ASB) and anionic extended surfactant alkyl polyoxypropylene sulfate (A145) were employed as flooding surfactants. The macroscopic properties of the surfactant solutions, such as the oil-water interfacial tension (IFT), the interfacial dilational rheology and the viscosity of crude oil emulsions, have been measured. At the same time, we link these parameters with the oil displacement effect in several visual glass models and confirm the main factors affecting the migration ability of emulsions in micro-scale pores. The experimental results show that ASB reduces the IFT through mixed adsorption with crude oil fractions. The flat arrangement of the large hydrophilic group of ASB molecules enhances the interactions between the surfactant molecules on the oil-water interface. Compared with sulfate, betaine has higher interfacial membrane strength and emulsion viscosity. A145 has a strong ability to reduce the IFT against crude oil because of the larger size effect of the PO chains at the oil side of the interface. However, the membrane strength of A145 is moderate and the emulsion does not show a viscosity-increasing effect. During the displacement process, the deformation ability of the front emulsions or oil banks is the main controlling factor of the displacement efficiency, which is determined by the membrane strength and emulsion viscosity. The strong interfacial membrane strength and the high emulsion viscosity are not conducive to the migration of droplets in pore throats and may result in low displacement efficiency.
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Adilbekova, Akbota, Saidulla Faizullayev, and Wojciech Kujawski. "Evaluation of the effectiveness of commercial demulsifiers based on polyoxyalkylated compounds in relation to oil and water emulsions of the Sarybulak oilfield." Chemical Bulletin of Kazakh National University, no. 3 (September 20, 2022): 4–11. http://dx.doi.org/10.15328/cb1282.
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Water and oil emulsion formation is a natural process that takes place during oil recovery and processing. Heavy oils of Kazakhstan form highly stable oil emulsions mostly stabilized by a high content of asphaltenes, resins, and other surface-active components. Oil-in-water emulsions initiate the corrosion of equipment and cause transportation issues. Dewatering of oil emulsions is economically reasonable and requires universal techniques which could be applied to any sort of oil. In this study, the chemical composition of crude oil from the Sarybulak oilfield was determined, and commercial demulsifiers of Basorol brand were applied to these water-in-oil emulsions. The natural stabilizers content (asphaltenes and resins) was determined and correlated with IR-spectrum data. Finally, the effectiveness of demulsifiers is compared and explained according to their structures. It has been found that the higher the relative solubility number of the demulsifier, the better water-in-oil emulsion separation efficiency and dewatering mechanism was assumed. Results of water separation showed that Basorol PE-10400 and PE-10500 are the most effective, with DE of 96% and 91%, respectively, for 30% (vol.) water-in-oil emulsion at 60°C during 1-hour treatment.
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Durán, Alberto L., Ediguer E. Franco, Carlos A. B. Reyna, Nicolás Pérez, Marcos S. G. Tsuzuki, and Flávio Buiochi. "Water Content Monitoring in Water-in-Crude-Oil Emulsions Using an Ultrasonic Multiple-Backscattering Sensor." Sensors 21, no. 15 (July 27, 2021): 5088. http://dx.doi.org/10.3390/s21155088.
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This work shows the application of an ultrasonic multiple-scattering sensor for monitoring water-in-petroleum emulsions. The sensor consists of a commercial ultrasonic transducer with an array of cylindrical scatterers placed in the near field. The scatterers are thin metal bars arranged in rows in front of the transducer. The backscattering signals were analyzed by calculating the wave energy and by a cross-correlation between signal segments; they were also used to determine the propagation velocity in the emulsions. The tests performed used emulsions with water volume concentrations from 0 to 50%. The results showed that both the signal energy and propagation velocity strongly depended on the concentration of water in the emulsion. Therefore, the ultrasonic multiple-scattering sensor can be used for on-line and real-time monitoring of the water content in water-in-crude-oil emulsions.
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Miadonye, Adango, and Mumuni Amadu. "Theoretical Interpretation of pH and Salinity Effect on Oil-in-Water Emulsion Stability Based on Interfacial Chemistry and Implications for Produced Water Demulsification." Processes 11, no. 8 (August 17, 2023): 2470. http://dx.doi.org/10.3390/pr11082470.
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The petroleum industry produces thousands of barrels of oilfield waters from the initial stage driven by primary production mechanisms to the tertiary stage. These produced waters contain measurable amounts of oil-in-water emulsions, the exact amounts being determined by the chemistry of the crude oil. To meet strict environmental regulations governing the disposal of such produced waters, demulsification to regulatory permissible levels is required. Within the electric double layer theory, coupled with the analytical solutions to the Poisson–Boltzmann Equation, continuum electrostatics approaches can be used to describe the stability and electrokinetic properties of emulsions. In the literature, much of the surface charge density and zeta potential relationship to emulsion stability has been confined to systems with less salinity. In this paper, we have exploited the theoretical foundations of the electric double layer theory to carry out theoretical evaluations of emulsion salinity based on zeta potential and surface charge density calculations. Most importantly, our approaches have enabled us to extend such theoretical calculations to systems of the higher salinity characteristic of oil-in-water emulsions found in oilfield-produced waters, based on crude oil samples from the literature with varying surface chemistry. Moreover, based on the definition of acid crude oils, our choice of samples represents two distinct classes of crude oils. This approach enabled us to evaluate the stability of emulsions associated with these produced oilfield waters in addition to predicting the potential of demulsification using demulsifiers. Given that the salinity range of this study is that encountered with the vast majority of produced oilfield waters, the findings from our theoretical predictions are perfect guides as far as emulsion stability is concerned.
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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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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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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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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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Aomari, N., R. Gaudu, F. Cabioc'h, and A. Omari. "Rheology of water in crude oil emulsions." Colloids and Surfaces A: Physicochemical and Engineering Aspects 139, no. 1 (July 1998): 13–20. http://dx.doi.org/10.1016/s0927-7757(97)00194-5.
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Clark, Peter E., and Ali Pilehvari. "Characterization of crude oil-in-water emulsions." Journal of Petroleum Science and Engineering 9, no. 3 (June 1993): 165–81. http://dx.doi.org/10.1016/0920-4105(93)90013-5.
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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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Ismail, Ali I., Ayman M. Atta, Mohamed El-Newehy, and Mohamed E. El-Hefnawy. "Synthesis and Application of New Amphiphilic Asphaltene Ionic Liquid Polymers to Demulsify Arabic Heavy Petroleum Crude Oil Emulsions." Polymers 12, no. 6 (June 2, 2020): 1273. http://dx.doi.org/10.3390/polym12061273.
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Asphaltenes are heavy petroleum crude oil components which limit the production of petroleum crude oil due to their aggregation and their stabilization for all petroleum crude oil water emulsions. The present study aimed to modify the chemical structures of isolated asphaltenes by converting them into amphiphilic polymers containing ionic liquid moieties (PILs) to demulsify the emulsion and replace the asphaltene layers surrounding the oil or water droplets in petroleum crude oil emulsions. The literature survey indicated that no modification occurred to produce the PILs from the asphaltenes. In this respect, the asphaltenes were modified via oxidation of the lower aliphatic chain through carboxylation followed by conversion to asphaltene acid chloride that reacted with ethoxylated N-alkyl pyridinium derivatives. Moreover, the carboxylation of asphaltenes was carried out through the Diels–Alder reaction with maleic anhydride that was linked with ethoxylated N-alkyl pyridinium derivatives to produce amphiphilic asphaltene PILs. The produced PILs from asphaltenes acid chloride and maleic anhydride were designated as AIL and AIL-2. The chemical structure and thermal stability of the polymeric asphaltene ionic liquids were evaluated. The modified structure of asphaltenes AIL and AIL-2 exhibited different thermal characteristics involving glass transition temperatures (Tg) at −68 °C and −45 °C, respectively. The new asphaltenes ionic liquids were adsorbed at the asphaltenes surfaces to demulsify the heavy petroleum crude emulsions. The demulsification data indicated that the mixing of AIL and AIL-2 100 at different ratios with ethoxylated N-alkyl pyridinium were demulsified with 100% of the water from different compositions of O:W emulsions 50:50, 90:10, and 10:90. The demulsification times for the 50:50, 90:10, and 10:90 O:W emulsions were 120, 120, and 60 min, respectively. The interaction of the PILs with asphaltene and mechanism of demulsification was also investigated.
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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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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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Abdullah, Mahmood M. S., Mohd Sajid Ali, and Hamad A. Al-Lohedan. "Application of New Ammonium-Based Ionic Liquids for Dehydration of Crude Oil Emulsions." Journal of Chemistry 2023 (July 7, 2023): 1–12. http://dx.doi.org/10.1155/2023/8711570.
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Crude oil emulsions are prevalent in the petroleum industries due to different natural emulsifiers in crude oil. In addition, adding amphiphilic compounds for enhanced oil recovery at high temperatures and pressure under extreme shear stress conditions improved the stability of these emulsions. However, these emulsions are not desirable because they cause different operational problems. Herein, this work aims to synthesize and characterize two novel ionic liquids (ILs) and apply them to the dehydration of water-in-crude oil (W/O) emulsions. For that, tetraethylene glycol (TEG) was reacted with thionyl chloride (TC), yielding dialkyl halide (TEC). After that, TEC was reacted with 4-hexylaniline (HA) or 4-tetradecylaniline (TA) in the presence of sodium carbonate, obtaining the amines TC-HA and TC-TA, respectively. Finally, TC-HA and TC-TA were reacted with acetic acid, yielding the corresponding ionic liquids, THA-IL and TTA-IL. Chemical structure, surface tension (ST), interfacial tension (IFT), thermal stability, and micelle size were investigated using various techniques. The conventional bottle test was used to evaluate the performance of these ILs for dehydration W/O emulsion at different crude oil/brine ratios (ranging from 90/10 to 50/50). The results indicated that the dehydration performance (DP) increased with an increase in IL concentration. In addition, DP improved with increased water contents, reaching 100% for THA-IL and 80% for TTA-IL, respectively, at a crude oil/brine ratio of 50/50. Furthermore, TTA-IL showed higher DP and separated more clear water than THA-IL, which could be linked to its higher ability to reduce IFT due to a longer alkyl chain than THA-IL. The results showed that the synthesized ILs could serve as demulsifiers in the petroleum industry.
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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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Belore, Randy, Alun Lewis, Alan Guarino, and Joe Mullin. "DISPERSANT EFFECTIVENESS TESTING ON VISCOUS, U.S. OUTER CONTINENTAL SHELF CRUDE OILS AND WATER-IN-OIL EMULSIONS AT OHMSETT." International Oil Spill Conference Proceedings 2008, no. 1 (May 1, 2008): 823–28. http://dx.doi.org/10.7901/2169-3358-2008-1-823.
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ABSTRACT Two separate projects were funded by the US Minerals Management Service to study the dispersibility of viscous crude oils and water-in-oil emulsions. The objective of the first study was to determine the viscosity limit for the effectiveness of chemical dispersants applied to viscous US Outer Continental Shelf crude oils of varied origin. The objective of the second study was to determine the effectiveness of chemical dispersants when applied to water-in-oil emulsions and to determine if similar viscosity limits exist for successful dispersion of emulsions as for non-emulsified crude oils. In both programs, preliminary tests were completed in the small-scale wave tank at SL Ross. Full-scale tests were completed at The National Oil Spill Response Test Facility (Ohmsett) in Leonardo, New Jersey in April 2005 (viscous oils) and December 2005 (emulsions). In the emulsion dispersion program, tests were conducted with both Corexit 9500 and Corexit 9527 dispersants. Only Corexit 9500 was used in the viscous oil dispersion testing. In the viscous oil test program, the effectiveness of the dispersant was influenced by both oil type (viscosity) and to a lesser extent by DOR. In general, the oils with viscosities lower than 6,500 cP were dispersible to a significant degree, whereas the oils with viscosities of 33,000 cP and greater were not. Oils between 6,500 and 33,000 cP were not available for testing to identify dispersant effectiveness between these two viscosities.
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Otremba, Zbigniew, and Jacek Piskozub. "Modelling the Spectral Index to Detect a Baltic-Type Crude Oil Emulsion Dispersed in the Southern Baltic Sea." Remote Sensing 13, no. 19 (September 30, 2021): 3927. http://dx.doi.org/10.3390/rs13193927.
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Information was obtained on the possibility of detecting oil-in-water emulsions located under the sea based on the modelling of the directional distribution of the radiance field above the water surface. The optical sea model used applies to the southern Baltic Sea, while the oil emulsion model is based on the optical properties of crude oil extracted in this region of the sea. The analyses were carried out while taking into account eight wavelengths in the range 412–676 nm, assuming different thicknesses of the layer contaminated with oil. The most favourable combination of two wavelengths (555/412 nm) for the determination of an index related to the polluted sea area compared to the same index for oil-free water (difference index) was identified, the value of which is indicative of the presence of the oil emulsion in water. Changes in the difference index depending on the viewing direction are shown for almost the entire upper hemisphere (zenith angles from 0° to 80°). The observation directions for which the detection of emulsions should be the most effective are shown.
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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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Sousa, Ana M., Henrique A. Matos, and Maria J. Pereira. "Properties of Crude Oil-in-Water and Water-in-Crude Oil Emulsions: A Critical Review." Industrial & Engineering Chemistry Research 61, no. 1 (December 23, 2021): 1–20. http://dx.doi.org/10.1021/acs.iecr.1c02744.
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H. Nour, Abdurahman,, Rosli Mohd Yunus, and Zulkifly Jemaat. "Chemical Demulsification of Water-in-Crude Oil Emulsions." Journal of Applied Sciences 7, no. 2 (January 1, 2007): 196–201. http://dx.doi.org/10.3923/jas.2007.196.201.
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H. Nour, Abdurahman, A. Suliman, and Mahmmoud M. Hadow. "Stabilization Mechanisms of Water-in-Crude Oil Emulsions." Journal of Applied Sciences 8, no. 8 (April 1, 2008): 1571–75. http://dx.doi.org/10.3923/jas.2008.1571.1575.
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Zaki, N., and A. Al-Sabagh. "De-emulsifiers for water-in-crude oil-emulsions." Tenside Surfactants Detergents 34, no. 1 (January 1, 1997): 12–17. http://dx.doi.org/10.1515/tsd-1997-340104.
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Cloud, Richard W., Rebecca L. Ramsey, Robert A. Pultz, and Michael K. Poindexter. "Characterization of Solids from Oilfield Emulsions." Microscopy Today 13, no. 6 (November 2005): 28–31. http://dx.doi.org/10.1017/s1551929500053955.
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Production of crude oil is generally accompanied by several other product phases, namely water, gas and solids. Pressure drops across chokes, concomitant gas evolution (due to pressure drops) and turbulence caused by various pipeline configurations can create difficult-to-resolve emulsions. Natural crude oil surfactants and solids exacerbate the problem further by migrating to the newly created oil-water interface and stabilizing the unwanted emulsions. Once the fluids arrive at the production facilities, a variety of vessels are employed to separate the oil, gas and water. Depending on the wettability of the solids, they will exit via one or both of the liquid phases. In a worse case scenario, the solids will accumulate at the oil-water interface.