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1
Yarmola, Tetiana, Petro Topilnytskyy, and Victoria Romanchuk. "High-Viscosity Crude Oil. A Review." Chemistry & Chemical Technology 17, no. 1 (2023): 195–202. http://dx.doi.org/10.23939/chcht17.01.195.
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The current problem of the production and processing of heavy high-viscosity oils in Ukraine and the world has been considered. It has been established that the main reserves of heavy high-viscosity crude oils in the world are located in South and North America, in the Middle East, as well as in Ukraine in the eastern regions. An analysis of various classifications of heavy high-viscosity oils, which are used both in Ukraine and in the world, was carried out. The main extraction methods of heavy high-viscosity oils were considered, in particular, quarry, mine, and well extraction methods. An overview of the technological processes of heavy high-viscosity oil processing was carried out.
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Shemelina, O. N. "High Viscosity Oil Development Technology." International Journal of Petroleum Technology 6, no. 1 (2019): 35–40. http://dx.doi.org/10.15377/2409-787x.2019.06.4.
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Mullakaev, M. S., and R. M. Mullakaev. "Sonochemical transportation technology high viscous oil." SOCAR Proceedings, no. 1 (March 31, 2023): 135–42. http://dx.doi.org/10.5510/ogp20230100816.
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The work is devoted to one of the urgent problems of the oil and gas complex - the transportation of high-viscosity oils. The object of the study was the high-viscosity high-sulphur mixed oil of the Ashalchinskoye field. The sonochemical treatment of oil made it possible to reduce the effective viscosity by 35-40% and the pour point by 15-20 °C. Pilot tests of the developed unit and sonochemical technology have shown the possibility of reducing the load on pumping stations of main pipelines, reducing the number of hot oil pumping stations, and reducing the amount of emissions of organic sulfur compounds into the atmosphere. Keywords: high-viscosity oil; petroleum dispersed systems; ultrasound; pour point depres-sants; sonochemical effect; effective viscosity; pour point.
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Li, Yang, Pin Jia, Ming Li, Haoran Feng, Cong Peng, and Linsong Cheng. "Experimental Study on Microscopic Water Flooding Mechanism of High-Porosity, High-Permeability, Medium-High-Viscosity Oil Reservoir." Energies 16, no. 17 (2023): 6101. http://dx.doi.org/10.3390/en16176101.
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After the development of high-porosity, high-permeability, medium-high-viscosity oil reservoirs enters the high-water-cut stage, the remaining oil is highly dispersed on the microscopic scale, which leads to a change in the oil-water-flow law. If the enrichment and mobilization laws of the microscopic remaining oil cannot be truly and objectively described, it will ultimately affect the production of oil fields. At present, few studies have directly revealed the microscopic water flooding mechanism of high-porosity, high-permeability, medium-high-viscosity oil reservoirs and the main controlling factors affecting the formation of remaining oil. Starting with micro-physical simulation, this study explores the water flooding mechanism on the microscale, the type of remaining oil and its evolution law, and analyzes the main controlling factors of different types of remaining oil so as to propose effective adjustment and development plans for different types of remaining oil. It is found that this type of reservoir has a serious jet filtration phenomenon in the early stages of water flooding and is accompanied by the penetration of injected water, detouring flow, pore wall pressing flow, the stripping effect, and the blocking effect of the rock skeleton. The remaining oil is divided into five types: contiguous flake shape, porous shape, membrane shape, striped shape, and drip shape. Among them, the transformation of flake-shape and porous-shape remaining oil is greatly affected by the viscosity of crude oil. The decrease effect of crude oil viscosity on contiguous residual oil was as high as 33.7%, and the contiguous residual oil was mainly transformed into porous residual oil. The development of membrane-shape, striped-shape, and drip-shape remaining oil is more affected by water injection intensity. The decrease in water injection intensity on membrane residual oil was as high as 33.3%, and the membrane residual oil shifted to striped and drip residual oil. This paper classifies remaining oil on the microscopic scale and clarifies the microscopic water flooding mechanism, microscopic remaining oil evolution rules, and the main controlling factors of different types of remaining oil in high-porosity, high-permeability, medium-high-viscosity oil reservoirs.
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Makanov, Rinat, and Ilyas I. Turgazinov. "NUMERICAL STUDY OF THE POLYMER INJECTION ON DISPLACEMENT OF HIGH-VISCOUS OIL FROM CARBONATE FORMATION." Herald of Kazakh-British technical university 18, no. 3 (2021): 46–50. http://dx.doi.org/10.55452/1998-6688-2021-18-3-46-50.
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Residual recoverable reserves of high-viscosity and heavy oils in the Republic of Kazakhstan amount to about 340 million tons. The main oil fields containing high-viscosity and heavy oil are Karazhanbas, Kenkiyak, Zhetybai, North Buzachi, Kenbai, etc. Improving the system for the development of high-viscosity oil fields and the selection of rational EOR is relevant for Kazakhstan, as this will increase the efficiency of their development. Given the high resource potential of such fields, it is necessary to develop and introduce new technologies in the development of high-viscous oil fields using enhanced oil recovery methods. To ensure high oil recovery factors, it is necessary to carefully select the EOR applicable to high-viscosity oil fields at an early stage of their development. This work is devoted to the problem of EOR selection in the development of high-viscosity oil fields. For the research polymer injection was selected. Evaluation of the efficiency of the proposed EOR was carried out based on the results of numerical experiments to displace high-viscosity oil with the creation of reservoir conditions. As a result, the aqueous polymer solution with the concentration of 0.05 % yielded 51% of oil recovery, whereas water injection recovered only 10% of oil. However, the interaction of the polymer with high-viscosity oil has not been deeply studied, which is relevant to the fields of Kazakhstan.
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Nikolaev, A. I., B. V. Peshnev, and E. V. Egorova. "Coking of high-viscosity water-containing oil." Fine Chemical Technologies 17, no. 1 (2022): 30–38. http://dx.doi.org/10.32362/2410-6593-2022-17-1-30-38.
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Objectives. A characteristic feature of oil production is an increase in the volume of highviscosity bituminous oil. In Russia, technologies based on the use of water vapor are used for their extraction. The use of such technologies leads to a large amount of water in the product stream from the production well. Preparation of oil for processing involves its stabilization, desalination, and dewatering. Since the densities of the extracted oil and the water contained in it are comparable, traditional preparation schemes for processing of high-viscosity bituminous oil are ineffective. One of the possible solutions to the problem involving such oil in the fuel, energy, and petrochemical balance is to use a coking process at the first stage of its processing. This aim can be achieved by studying the influence of the process conditions of coking high-viscosity water-containing oil on the yield and characteristics of the resulting products.Methods. Coking of oil with a density of 1.0200 g/cm3 at 50 °C and with 18 wt % water content was carried out in a laboratory installation in a “cube.” A hollow cylindrical apparatus was used as a reactor and was placed in a furnace. The temperature and pressure in the reactor were maintained at 500–700 °C and 0.10–0.35 MPa, respectively.Results. An increase in the coking process temperature results in an increase in the amount of gaseous products, a decrease in the amount of the coke generated, and a higher dependence of the amount of liquid products on temperature with a maximum yield at 550–600 °C. The process temperature also affects the composition of liquid products. At a lower temperature, the amount of gasoline and kerosene fractions in liquid products is higher. With an increase in pressure, a higher amount of gaseous products, coke, and low-molecular-weight hydrocarbon fractions in liquid products could also be obtained. The characteristics of the coke produced in the coking process are similar to those of commercially produced grades. It is noted that when coking water-containing oil, up to 98% of the emulsion water goes with liquid products, and the remaining amount of water remains in the formed coke.Conclusions. Results showed the possible application of the coking process at the initial stage of processing high-viscosity bituminous oil. In this case, the dewatering stage is significantly simplified since the technological scheme of delayed coking allows the separation of the gasoline fraction from water.
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AG, Ponomarenko. "Electrophysical Apparatus for Intensifying the Production of High-Viscosity Oils." Petroleum & Petrochemical Engineering Journal 4, no. 1 (2020): 1–3. http://dx.doi.org/10.23880/ppej-16000214.
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The production of heavy high-viscosity oils is associated with the formation of asphalt-resin-paraffin deposits in the pipelines of the wells, which leads to a rapid decrease in their flow rate. Currently, a variety of mechanical, chemical, thermal and combined sediment removal tools are used in oilfield practice. Nevertheless, there remains a request for the search for new technological solutions that would allow environmentally sound removal of deposits without interruptions in the process of oil production with minimal energy and labor. This article reports on the first results of developing a new technology for removing deposits from well pipes, which is based on their non-contact local induction heating. At the contact point of the deposits with the heated section of the pipe, their partial melting occurs, as a result of which the bulk of the deposits in the form of large fragments is removed together with the oil flow. The inductor moves slowly along the axis of the well, receiving a high-frequency current from a nearby immersed energy converter.
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Li, Xuening, Fusheng Zhang, and Guoliang Liu. "Review on new heavy oil viscosity reduction technologies." IOP Conference Series: Earth and Environmental Science 983, no. 1 (2022): 012059. http://dx.doi.org/10.1088/1755-1315/983/1/012059.
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Abstract Lots of gum and asphaltene in heavy oil caused high viscosity, high density and poor fluidity, which makes it very difficult to exploit and transport heavy oil. This paper introduces the mechanism and application of five new viscosity reduction technologies, including microbial viscosity reduction technology, biosurfactant viscosity reduction technology, ultrasonic viscosity reduction technology, magnetic treatment viscosity reduction technology and supercritical carbon dioxide viscosity reduction technology. At present, single viscosity reduction technology is difficult to solve the problem of heavy oil production and transportation. So the development direction of heavy oil viscosity reduction technology is the composite use of various technologies. In the future, it is necessary to develop new viscosity reduction technologies suitable for heavy oil production and transportation from the perspective of studying the structure and performance of heavy oil.
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Varisova, Raushanya R. "Technologies for the development of high-viscosity oil fields." Journal of Physics: Conference Series 2388, no. 1 (2022): 012071. http://dx.doi.org/10.1088/1742-6596/2388/1/012071.
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Abstract With the depletion of light oil reserves, the share of current reserves of viscous and high-viscosity oil will increase, therefore, the search for effective methods for the development of deposits of high-viscosity oil is a natural direction for the development of the oil industry. Currently, thermal methods of exposure are widely used in the development of deposits of high-viscosity oil. Despite the fairly good efficiency of this method, thermal exposure technologies are characterized by high energy intensity, which in some cases can significantly reduce the economic attractiveness of the method. This issue is particularly acute in the context of a decline in world oil prices.
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Du, Yong, Guicai Zhang, Jijiang Ge, Guanghui Li, and Anzhou Feng. "Influence of Oil Viscosity on Alkaline Flooding for Enhanced Heavy Oil Recovery." Journal of Chemistry 2013 (2013): 1–8. http://dx.doi.org/10.1155/2013/938237.
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Oil viscosity was studied as an important factor for alkaline flooding based on the mechanism of “water drops” flow. Alkaline flooding for two oil samples with different viscosities but similar acid numbers was compared. Besides, series flooding tests for the same oil sample were conducted at different temperatures and permeabilities. The results of flooding tests indicated that a high tertiary oil recovery could be achieved only in the low-permeability (approximately 500 mD) sandpacks for the low-viscosity heavy oil (Zhuangxi, 390 mPa·s); however, the high-viscosity heavy oil (Chenzhuang, 3450 mPa·s) performed well in both the low- and medium-permeability (approximately 1000 mD) sandpacks. In addition, the results of flooding tests for the same oil at different temperatures also indicated that the oil viscosity put a similar effect on alkaline flooding. Therefore, oil with a high-viscosity is favorable for alkaline flooding. The microscopic flooding test indicated that the water drops produced during alkaline flooding for oils with different viscosities differed significantly in their sizes, which might influence the flow behaviors and therefore the sweep efficiencies of alkaline fluids. This study provides an evidence for the feasibility of the development of high-viscosity heavy oil using alkaline flooding.
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Koishina, A., S. Nauryzkulova, A. Boranbayeva, and B. N. Koilybaev. "FACTORS AFFECTING OIL VISCOSITY AND THE STUDY OF METHODS FOR REDUCING IT." Yessenov Science Journal 49, no. 4 (2024): 169–76. https://doi.org/10.56525/cjau7934.
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In oil production, the high viscosity of crude oil negatively affects the production rate, causing serious problems. Numerous studies are aimed at assessing the properties of various grades of crude oil and their extraction technologies. The main reasons for high viscosity are the presence of solid particles, high concentrations of heavy fractions, and the formation of "water-in-oil" emulsions. This article discusses the mechanisms aimed at reducing the viscosity of oil with a high concentration of solid fractions, the mechanisms of formation and destabilization of emulsions, as well as methods for reducing viscosity.
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Mullakaev, M. S., D. G. Sarvarov, A. A. Rukhman, and R. M. Mullakaev. "THERMOACOUSTIC TECHNOLOGY FOR HIGH-VISCOSITY OIL PRODUCTION." Geology, Geophysics and Development of Oil and Gas Fields, no. 11 (2021): 39–46. http://dx.doi.org/10.33285/2413-5011-2021-11(359)-39-46.
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Kondrat, Oleksandr. "Improvement of high-viscosity oil production technology." AGH Drilling, Oil, Gas 31, no. 1 (2014): 73. http://dx.doi.org/10.7494/drill.2014.31.1.73.
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Chen, Chao, Hao Xu, Lidong Zhang, et al. "Foam Systems for Enhancing Heavy Oil Recovery by Double Improving Mobility Ratio." Processes 11, no. 10 (2023): 2961. http://dx.doi.org/10.3390/pr11102961.
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The recovery of heavy oil is challenging due to its high viscosity. Especially in water flooding, the high viscosity of heavy oil induces a high water/oil mobility ratio, resulting in frequent channeling and fingering. In the present work, the viscosity reduction in heavy oil caused by foaming agents is studied. Among the studied foam systems, the KX-048 foaming agent had the best oil viscosity reduction performance. It also shows excellent foaming performance, including large foam volume, long foam half-life, and high foam comprehensive index. With the reduction in oil viscosity, the KX-048 foaming agent decreases the foam/oil mobility to 0.28, which is beneficial for controlling gas channeling and fingering in foam flooding. Moreover, Foam flooding experiments in heterogeneous sand-pack models indicate that KX-048 has excellent efficiency in improving oil recovery, especially in the low-permeable tube. The chosen KX-048 foaming agent could provide a promising pathway for improving heavy oil recovery.
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Shipulin, A. V., I. Sh Mingulov, V. V. Mukhametshin, Sh G. Mingulov, and L. S. Kuleshova. "Wave-pulse simulation in high-viscosity oil wells." Journal of Physics: Conference Series 2176, no. 1 (2022): 012003. http://dx.doi.org/10.1088/1742-6596/2176/1/012003.
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Abstract The thixotropic properties of high-viscosity oils have been found to be highly dependent on temperature and pressure treatment. As the temperature increases, the efficiency of the wave-pulse method to reduce the thixotropic properties of high-viscosity oil increases. The effect of the wave interference on the productive formation decreases over time, and after 3-7 days of development, the well must be treated again to ensure its operation in an intensive mode. Wave-pulse treatment facilitates the separation of light fractions from high-viscosity oil and hydrophobization of the reservoir. Heat and wave-pulse treatments complement each other and contribute to a complex effect on high-viscosity oil, but they must be carried out simultaneously or alternated with minimal interruptions in order to avoid the space lattice restoration.
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Nikolaev, Alexander, and Kristina Plotnikova. "Study of the Rheological Properties and Flow Process of High-Viscosity Oil Using Depressant Additives." Energies 16, no. 17 (2023): 6296. http://dx.doi.org/10.3390/en16176296.
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This article analyzes the dependence of the choice of the method of transportation of high-viscosity oil on the rheological characteristics of the oil in question. An analysis of existing rheological models of high-viscosity oil was carried out, and it was found that a number of models have certain features (model coefficients, their purpose, quantity) that affect the choice of a rheological model of oil. The dependences for determining the coefficient of dynamic viscosity when pumping high-viscosity oil with the addition of pour-point depressants were studied, and the dependence of the hydraulic resistance coefficient when depressants are added to the oil was obtained. A method for choosing a rational oil heating temperature and diluent concentration to achieve the maximum pipeline performance is substantiated.
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Sayenko, Olga B., Bazargul S. Serkebayeva, and Yerbolat O. Ayapbergenov. "Study of the rheological characteristics of high-viscosity oil from Mangyshlak." Kazakhstan journal for oil & gas industry 6, no. 2 (2024): 88–98. http://dx.doi.org/10.54859/kjogi108716.
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Background: Due to the exhaustibility of active reserves of light oil, every year it becomes more and more important to improve the developmental efficiency of heavy high-viscosity oil fields. There is a need for a deeper study of the properties of high-viscosity oil in order to improve enhanced oil recovery technologies. Aim: The investigation of West Kazakhstan’s high-viscosity oils’ rheological properties by studying their physical and chemical characteristics and content of high-molecular compounds. Materials and methods: As objects of the study, oils from Western Kazakhstan's Karazhanbas, Northern Buzachi and Zhalgyztobe oil fields were selected. To accomplish the given tasks, laboratory studies were conducted using contemporary methods of chemical and physicochemical analysis. Results: This article presents the results of laboratory studies to determine the density, viscosity, and content of asphalt-resin-paraffin substances with a comparison of the results obtained. As well as the results of the study of the rheological characteristics of heavy high-viscosity oil with different water cut on the example of fields in Western Kazakhstan. The temperature limits and the influence of water cut on the manifestation of non-Newtonian properties were determined. Conclusion: It was found that the rheological behavior of high-viscosity heavy oil with different water cut exhibits pronounced properties of pseudoplastic liquid, where the most pronounced non-Newtonian properties are manifested at the content of bound water exceeding 50%. The expression of non-Newtonian properties of West Kazakhstan oil is due to the increased content of high-molecular components. The obtained results are of practical interest in creating a composite model of hydrodynamic and technological system of collection and transportation of heavy, high-viscosity oil.
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Hasanov, B. K., P. A. Guzhikov, K. M. Kunzharikova, N. K. Dukesov, and G. Zh Kokymbaeva. "High-viscosity oil properties of the East Moldabek field." Kazakhstan journal for oil & gas industry 3, no. 1 (2021): 56–66. http://dx.doi.org/10.54859/kjogi88892.
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Large reserves of hard-to-recover oil belong to the category of high-viscosity, heavy oils. Despite the shallow depth of occurrence, there are technological difficulties in extracting these fluids to the surface. The properties of reservoir oil, which directly affect the oil recovery factor, have a key role for the production technology. The article considers an example of analysis and substantiation of the properties of high-viscosity oil from the chalk reservoir of the East Moldabek field.
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Martín-Alfonso, María J., Francisco J. Martínez-Boza, Pedro Partal, and Montes Críspulo Gallego. "Influence of pressure and temperature on the flow behaviour of heavy fuel oils. Rheologica Acta, 45(4), 357-365." Rheologica Acta 45, no. 4 (2006): 357–65. https://doi.org/10.5281/zenodo.14725275.
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Transportation and consumption of petroleum products around the world have created a potential risk for oil spills in the environment. Knowledge of high pressure rheological behaviour of heavy crude oil fractions, which are usually transported in oil tankers, is very important to design deep recovering operations of the oil remaining in the tanks after an accident. The effect of pressure on the viscosity of these materials is not well understood, this is mainly due to experimental constraints involving high-pressure rheology measurements at low shear rates. Consequently, the overall objective of this work is to model the temperature–pressure–viscosity dependence of a selected heavy fuel oil in a wide range of pressure and temperature. With this aim, viscous flow tests at different temperatures and differential pressures and modulated differential scanning calorimetry tests were carried out on the heavy fuel oil selected. A temperature–pressure–viscosity model (FMT model) fits fairly well the experimental results obtained in the whole differential pressure range studied. However, viscosity values at temperatures lower than 10°C cannot be predicted due to microstructural changes associated with the solidification process of the heaviest components of the fuel oil tested.
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Ioana, Stanciu. "Some Methods for Determining the Viscosity Index of Hydraulic Oil." Indian Journal of Science and Technology 16, no. 4 (2023): 254–58. https://doi.org/10.17485/IJST/v16i4.1461.
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ABSTRACT <strong>Objectives:</strong> To determine the viscosity index of hydraulic oil by three methods. These methods are: the viscosity index determined by a mathematical relationship, using a calculation program and the graphic method. The study also intends to determine the viscosity-temperature coefficient for the hydraulic oil. <strong>Methods:</strong> To determine the kinematic viscosity of the hydraulic oil, we used a calculation formula that transforms the dynamic viscosity into kinetic viscosity knowing the density of the fluid. Thus, we determined the dynamic viscosity of the hydraulic oil with the Schott Ubbelohde viscometer at the temperatures of 40 and 100◦C. To determine the dynamic viscosity of hydraulic oil at 40◦C and 100◦C, we used a water bath. The dynamic viscosity thus obtained was transformed into the kinematic viscosity of the oil by dividing it by density. <strong>Findings:</strong> The lowest viscosity index of the hydraulic oil determined using the computer program is 101. The viscosity index of the hydraulic oil determined with relation (1) is 58% higher than using the computer program. The viscosity index determined by the graphic method is 50% higher than the one determined by the computer program. The viscositytemperature coefficient has a value of 0.8380. <strong>Novelty:</strong> Knowing the viscosity index of hydraulic oil is important for starting the engine at high temperatures and at low temperatures. At high temperatures, the oil chemically degrades and the molecules break down. The properties of hydraulic oils depend a lot on the way the hydraulic system works and the limits imposed on them in different conditions. <strong>Keywords:</strong> Viscosity Index; Viscosity-Temperature Coefficient
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Liu, Qing Wang, Xin Wang, Zhen Zhong Fan, Jiao Wang, Rui Gao, and Ling Da Kong. "Indoor Study of Viscosity Reducer for Thickened Oil of Huancai." Applied Mechanics and Materials 268-270 (December 2012): 547–50. http://dx.doi.org/10.4028/www.scientific.net/amm.268-270.547.
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Liaohe oil field block 58 for Huancai, the efficiency of production of thickened oil is low, and the efficiency of displacement is worse, likely to cause other issues. Researching and developing an type of Heavy Oil Viscosity Reducer for exploiting. The high viscosity of W/O emulsion changed into low viscosity O/W emulsion to facilitate recovery, enhanced oil recovery. Through the experiment determine the viscosity properties of Heavy Oil Viscosity Reducer. The oil/water interfacial tension is lower than 0.0031mN•m-1, salt-resisting is good. The efficiency of viscosity reduction is higher than 90%, and also good at 180°C.
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Fan, Zhen Zhong, Tong Wang, Peng Peng Li, Ji Gang Wang, and Qing Wang Liu. "The Evaluation of Factors Affecting the Performance of Heavy Oil Emulsion." Advanced Materials Research 690-693 (May 2013): 1508–11. http://dx.doi.org/10.4028/www.scientific.net/amr.690-693.1508.
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In this paper,we used the heavy oil of Du 84,53-55 well in Liaohe oil field,analyzed of the impact factors of the heavy oil emulsion viscosity.When the droplet size of the emulsion is reduced,the viscosity of the heavy oil emulsion increases,and the non-Newtonian obvious.Heavy oil emulsions exhibit Newtonian fluid properties at low shear rate,exhibits shear-thinning properties in the heavy oil emulsion under high shear rate.Heavy oil emulsion viscosity decreases with the increasing concentration of viscosity reducer,when the viscosity reducer concentration of more than 0.25%,heavy oil emulsion viscosity declines slowed.
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Rachmawati, Dewi Oktofa, and Iwan Suswandi. "THE VALUE OF VISCOSITY COEFFICIENT OF COOKING OIL RESULTED BY PURIFICATION BASED ON ACTIVE CHARCOAL TEMPERATURE WITH THE FALLING BALL METHOD." Indonesian Physical Review 5, no. 1 (2022): 57–63. http://dx.doi.org/10.29303/ipr.v5i1.140.
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A change in viscosity indicates the damage to cooking oil. The value of the viscosity coefficient indicates the level of viscosity. This value describes the drag caused by friction between the cooking oil molecules to block the flow. The adhesive property of used cooking oil with a high viscosity value is that it is easy to stick to foodstuffs processed with this oil. Used cooking oil is cooking oil with a high viscosity coefficient value. This oil contains free fatty acids that are harmful to the body. Reuse of used cooking oil for frying foodstuffs is not recommended. Purifying used cooking oil is one way to make cooking oil safe to consume again. The surface adsorption capacity of activated charcoal is increased by heating. Activated charcoal activation temperatures are 27oC, 40oC, 50oC, 70oC, and 90oC.The value of the viscosity coefficient of the purified cooking oil is interesting to study for the activation temperature of the activated charcoal used. The falling ball method was chosen to determine the value of the viscosity coefficient. This method measured the time the ball fell in the oil. Data were analyzed quantitatively descriptively and presented in graphical form. The results show that the value of the viscosity coefficient of the purified cooking oil decreases with the increase in the activated charcoal temperature. The value of the viscosity coefficient of cooking oil as a result of purification using activated charcoal at 90oC is (0.854 ±0.004) Pa. s
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Zou, Jungang, Yaermaimaiti Patiguli, Jun Chen, Awan Alimila, Bin Zhao, and Junwei Hou. "Study on Demulsification Technology of Heavy Oil Blended in Xinjiang Oilfield." Processes 11, no. 2 (2023): 409. http://dx.doi.org/10.3390/pr11020409.
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HYW (Hong Yi Wu line) heavy oil emulsion in Xinjiang Oilfield (Karamay, China) is a kind of heavy oil with high viscosity and high emulsification. Its viscosity reaches 120,000 mPa·s at 40 °C. The emulsion has no demulsification. Even if the demulsification temperature reaches 90 degrees, the concentration of demulsifier reaches 260 mg/L. In this paper, a new process of thermochemical demulsification of heavy oil after blending is studied. First, SE low-viscosity oil with viscosity of 640 mPa·s and water cut of 90% was selected as blended oil. Study the viscosity of SE line and HYW line at different temperatures after fully blended. The results show that the heavy oil blended model conforms to Bingham model. When the temperature is 40 °C and the content of SE line is 30%, the viscosity is less than 10,000 mPa·s. With the increase of temperature, the viscosity continues to decline. When the temperature exceeds 80 °C, the viscosity is less than 1000 mPa·s. The final design SE line content is 30%, the demulsification temperature is 70 °C, and the demulsifier concentration is 160 mg/L as the best demulsification parameter. The field results show that the demulsification rate of heavy oil in this process reaches more than 90%. This experiment lays a foundation for demulsification of high emulsified crude oil developed by heavy oil in Xinjiang oilfield.
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Cao, Yang, Yanlin Guo, Tao Wu, and Dejun Sun. "Synergistic emulsification of polyetheramine/nanofluid system as a novel viscosity reducer of acidic crude oil." Materials Science-Poland 41, no. 4 (2023): 107–19. http://dx.doi.org/10.2478/msp-2023-0049.
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Abstract Oil is a critical raw material for energy and industry, the depletion of conventional oil reserves necessitates efficient extraction and production of unconventional resources like acidic crude oil. However, its high viscosity poses significant challenges for transportation and processing. To address these challenges, this study developed a novel emulsion viscosity reducer. We designed a nanofluid based on a synergistic polyetheramine/nanofluid system consisting of alkyl ethoxy polyglycosides (AEG) as a green surfactant, SiO2 nanoparticles, and an organic alkali polyetheramine. The mixture was evaluated for its viscosity reduction and emulsification performance with acidic crude oi obtained from Qinghe oil production plant in Shengli Oilfield. The results showed that the optimized viscosity reducer achieved a remarkable reduction rate of 98.1% at 50◦C in crude oil viscosity from 6862 mPa·s to 129 mPa·s. This demonstrated the reducer effectively transformed acidic crude oil into a low viscosity oil-in-water (O/W) emulsion with high stability. Furthermore, the core imbibition simulation tests demonstrated that the viscosity reducer could improve the recovery of acidic crude oil from 29.6% to 49.4%, indicating the potential application of the optimized viscosity reducer in the exploitation of acidic crude oil. In conclusion, this study developed a novel emulsion viscosity reducer, which can reduce the viscosity and improve recovery of acidic crude oil by emulsifying into O/W emulsion. The optimized formula has potential for practical application in the exploitation of acidic crude oil.
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Wang, Jincai, Zifei Fan, Lun Zhao, et al. "Effects of oil viscosity on waterflooding: A case study of high water-cut sandstone oilfield in Kazakhstan." Open Geosciences 12, no. 1 (2020): 1736–49. http://dx.doi.org/10.1515/geo-2020-0218.
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Abstract After a sandstone oilfield enters the high water-cut period, the viscosity of crude oil has an important influence on remaining oil distribution and waterflooding characteristics under the same factors of, e.g., reservoir quality and development methods. Based on a comprehensive interpretation of the waterflooded layers in new oil wells, physical simulation experiments, and reservoir numerical simulations, we analyzed the waterflooding laws of a high water-cut sandstone reservoir with different oil viscosities in Kazakhstan under the same oil production speed, and we clarified the remaining oil potential of reservoirs with different viscosities and proposed corresponding development measures. The results show that low-viscosity oil reservoirs (1 mPa s) have uniform waterflooding, thick streamlines, small waterflooding areas, and low overall waterflooding degrees because of their homogeneous oil–water viscosities. However, within waterflooded areas, the reservoirs have high oil displacement efficiencies and high waterflooding degrees, and the remaining oil is mainly concentrated in the unwaterflooded areas; therefore, the initial production and water cut in new oil wells vary significantly. High-viscosity oil reservoirs (200 mPa s) have severe waterflooding fingering, large waterflooding areas, and high overall waterflooded degrees because of their high oil–water mobility ratios. However, within waterflooded areas, the reservoirs have low oil displacement efficiencies and low waterflooding degrees, and the remaining oil is mainly concentrated in both the waterflooded areas and the unwaterflooded areas; therefore, the differences in the initial production and water cut of new oil wells are small. Moderate-viscosity oil reservoirs (20 mPa s) are characterized by remaining oil distributions that are somewhere in between those of the former two reservoirs. Therefore, in the high water-cut period, as the viscosity of crude oil increases, the efficiency of waterflooding gradually deteriorates and the remaining oil potential increases. In the later development, it is suggested to implement the local well pattern thickening in the remaining oil enrichment area for reservoirs with low viscosity, whereas a gradual overall well pattern thickening strategy is recommended for whole reservoirs with moderate and high viscosity. The findings of this study can aid better understanding of waterflooding law and the remaining oil potential of reservoirs with different viscosities and proposed corresponding development measures. The research results have important guidance and reference significance for the secondary development of high water-cut sandstone oilfields.
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Bocharov, O. B., and I. G. Telegin. "Analysis of solutions of the Muskat — Leverett non-isothermal model for different types of oils." Oil and Gas Studies, no. 2 (June 2, 2020): 26–37. http://dx.doi.org/10.31660/0445-0108-2020-2-26-37.
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In this article, numerical methods are used to analyze the features of solutions to the non-isothermal Muskat — Leverett two-phase filtration model. The structure of solutions to thermal waterflooding problems for low-viscosity and high viscosity types of oil is considered. Typical solutions for different types of functional parameters of the model are shown. The simulations show that hot water displacement of high-viscosity oil is an effective method of increasing oil recovery. In particular, if in the case of thermal flooding the reservoir with low-viscosity oil, recovery increases by only a few percent, then for a field with high viscosity oil, thermal flooding increases oil recovery by tens of percent. It is shown that in order to increase the efficiency of the thermal flooding it is necessary to pump hot water with the minimum possible capillary parameter. High total filtration rate reduces total heat loss through the roof and sole of the formation. Numerical experiments have shown that for an adequate simulation of thermal flooding, in addition to taking into account changes in oil viscosity, it is necessary to take into account the action of capillary forces and the variation of relative phase permeability during the operation of the oil field.
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Tao, Jianqiang, Chunyu Hu, Wenfeng Wang, et al. "Characteristics and Genesis of Heavy Oil in Shallow and Thin Layers in Chepaizi Area, Xinjiang, China." Energies 17, no. 23 (2024): 5988. http://dx.doi.org/10.3390/en17235988.
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The Neoproterozoic Shawan Formation in the Chepaizi area is recognized for its significant heavy oil resources. Investigating the underlying causes and mechanisms of heavy oil changes in accordance with the specific characteristics of the reservoir is crucial for future exploration and development. The distribution of heavy oil in the Pai 612 block was identified to present a combination of shallow and thin deposits, high porosity, high permeability, and elevated water content. The physicochemical properties of the crude oil included a complex composition, high density, high viscosity, substantial gel content, and notable oxidation-biodegradation potential. The oxidation and biodegradation of crude oil during transportation played the critical roles in the formation of heavy oil. As cru3de oil was transported upward, the formation temperature decreased, resulting in increased viscosity. An excess of water could initially increase and subsequently decrease heavy oil viscosity, while groundwater in the reservoir contained various chemicals that interacted with colloids and asphaltenes, further increasing the viscosity. During the formation of the early heavy oil reservoir, the light oil was unable to dissolve and transport the high-molecular-weight asphaltene component, leading to the high resin content in the heavy oil of the Pai 612 block.
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Wang, Feng, Chi Ai, Dan Dan Yuan, Shuang Liang, and Guang Miao Qu. "Experimental Investigation of Emulsifying Viscosity Reduction of a New Viscosity Breaker." Advanced Materials Research 981 (July 2014): 946–50. http://dx.doi.org/10.4028/www.scientific.net/amr.981.946.
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In this paper, alkyl polyglucoside (APG) and fatty alcohol polyoxyethylene ether (AEO3) were prepared to obtain a new type of soluble viscosity reducer which can change the rheological behavior of the crude oil and reduce its viscosity using method of emulsification viscosity reduction. The typical sample of heavy oil produced in Jilin oilfield was analyzed to figure out the key factors of influencing the viscosity of this heavy oil and the static evaluation experiments were carried out to investigate the reducing performance of the viscosity breaker. The viscosity breaker can lower the interfacial tension between oil and water to some extent, and the stability of emulsion between the oil and water is relatively good, in addition, it can provide high viscosity reduction rate and detergent factor of oil to produce a good viscosity reduction performance.
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Liu, Kechen, Michal Slaný, Alena Golian-Struhárová, et al. "Surface-Functionalized Nano-Montmorillonite and Its Application as Crude Oil Flow Improver." Minerals 14, no. 7 (2024): 696. http://dx.doi.org/10.3390/min14070696.
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In view of the problem of poor flowability in the production and transportation of high-wax crude oil and high-viscosity crude oil, crude oil flow improvers are commonly used to reduce their viscosity and pour point. Although polymer-based crude oil flow improvers are highly effective in improving crude oil flowability, there are still problems such as high cost and the need for a large amount of solvent dilution when used. In this work, highly dispersed organic modified nano-montmorillonite was prepared by using Na-based montmorillonite and quaternary ammonium salts, and the influencing factors on the viscosity of the crude oil were investigated. The most effective modified nano-montmorillonite (B@MMT) can reduce the viscosity by 96.7% (21 °C) and depress the pour point by 15 °C. Furthermore, it has shown a high improvement in flowability in the other four different sources of crude oil, with viscosity reduction rates of 52.2, 93.4, 79.1 and 67.4%, respectively. B@MMT was characterized by FTIR, SEM, zeta potential and contact angle. Based on DSC and wax crystal structure analysis, the mechanism of the influence of B@MMT on crude oil viscosity and pour point was explored. Finally, the cost of B@MMT was estimated, and the result shows that, compared with the crude oil flow improver in use, B@MMT has considerable commercial competitive advantages.
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Konoval, Alexander. "THE TEMPERATURE DEPENDENCE OF DYNAMIC VISCOSITY AND TYXOTROPY OF HIGH-VISCOUS OIL IN THE HIGH ALCOHOLS PRESENCE AT DIFFERENT CONCENTRATION." Ukrainian Chemistry Journal 86, no. 6 (2020): 99–107. http://dx.doi.org/10.33609/2708-129x.86.6.2020.99-107.
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The delivery of high-viscosity petroleum, which demonstrates significant resistance to pressure, from wells to refineries has long been the cause of energy costs during transportation through pipelines. In order to reduce costs, various methods are used: heating, dilution, ultrasonic effect, emulsification in water. We have investigated the effect of fusel oil on the rheological and physical characteristics of high-viscosity petroleum in order to reduce its viscosity, and as a result, reduce the resistance of the system during transportation through the pipeline. It has been established that the addition of 5-10% fusel oil under certain conditions can increase the petroleum dynamic viscosity. This fact should be taken into account when using the fusel oil fraction alcohols in tracer studies. The petroleum has a lower viscosity in the presence of fusel oil at a temperature of 30 ° C and 40 ° C. Moreover, with an increase in shear stress of more than 10 Pa, an almost linear dependence is observed in the decrease in viscosity for both petroleum and petroleum systems with fusel oil in the range from 5% to 20%. At the same time, the nature of the flow of petroleum systems with fusel oil with a change in shear stress and temperature almost completely corresponds to the behavior of petroleum. In general, given the lower viscosity of fusel oil, the behavior of the systems is logical except for the petroleum system with the addition of 5% fusel oil at a temperature of 30 ° C where the dynamic viscosity was higher than the viscosity of the petroleum in the range of shear stresses up to 10 Pa. Moreover, according to the results of the study, it is unlikely that the systems form eutectics since the pour point of the test petroleum has 29.8 ° C, the pour point of the alcohol fraction of fusel oil is lower than -50 ° C, and the petroleum: fusel oil 80:20 system has 28.8 ° C. The resulting systems remain thixotropic and have a non-Newtonian flow character, that is, paraffins and resinous substances do not form true solutions and eutectics with fusel oil.
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Mukhamatdinov, I. I., E. E. Giniyatullina, R. E. Mukhamatdinova, O. V. Slavkina, K. A. Shchekoldin, and A. V. Vakhin. "Evaluation of the aquathermolysis catalyst effect on the composition and properties of high-viscosity oil from the Strelovskoe field." SOCAR Proceedings, SI2 (December 30, 2021): 90–96. http://dx.doi.org/10.5510/ogp2021si200570.
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The article examines the aquathermolysis process of high viscosity oil from Strelovskoe field developed by RITEK LLC using steam injection. Laboratory modeling of non-catalytic and catalytic aquathermolysis in a high-pressure reactor was performed. Laboratory tests have demonstrated the high efficiency of the iron-based oil-soluble catalyst developed at Kazan Federal University in the destruction reactions of resinous asphaltenes. Samples of the initial oil as well as products of non-catalytic and catalytic aquathermolysis in the presence of iron tallate and the solvent Asphalt-Resin-Paraffin Deposits were studied at temperatures of 200, 250 and 300°C for 24 hours. In addition, the gas composition of the oil aquathermolysis products and the viscosity-temperature characteristics of the oil samples were determined. The studies have shown that catalytic aquathermolysis has a significant effect on the changes in the composition and properties of oil from the Strelovskoe field. It was found that the presence of a catalyst contributes to decarboxylation reactions, increases the degree of desulfurization and decreases the viscosity of oil samples. Keywords: high-viscosity oil; aquathermolysis; catalyst precursor; steam thermal treatment; viscosity.
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Lu, Teng, Faqiang Dang, Haitao Wang, Qingmin Zhao, and Zhengxiao Xu. "Experimental Study on Fe3O4 Nanoparticle-Assisted Microwave Enhancing Heavy Oil." Geofluids 2022 (January 12, 2022): 1–14. http://dx.doi.org/10.1155/2022/6457186.
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Nanoparticle-assisted microwave heating of heavy oil has the advantages of fast temperature rise and high thermal efficiency. Compared with traditional heating methods, it can reduce viscosity in a shorter time. In addition, the heavy components in the heavy oil are cracked into light components at high temperatures (this high temperature cannot be reached by conventional heating methods). This process is irreversible and avoids the problem of viscosity recovery of heavy oil after the temperature is reduced. Through absorbing microwave heating experiments, study the effect of nanoparticles on the improvement of the ability of heavy oil to absorb waves and raise temperature; through the heavy oil upgrading experiment and the four-component analysis experiment, the effect of adding hydrogen donor to assist microwave on the viscosity reduction of heavy oil upgrading by nanoparticles was studied, and the problem of viscosity recovery was determined; Through the gravity drainage experiment, the mechanism of nanoparticle-assisted microwave to improve the recovery of heavy oil is studied, and the influence of water content, nanocatalyst, and microwave power on the production of drainage is analyzed. The results show that nanoparticles can improve the wave absorption and heating capacity of heavy oil, and adding 0.6 wt% of nanomagnetic iron oxide catalyst can increase the heating rate of heavy oil in microwave by 60.6%; nanoparticle-assisted microwave heating method can effectively upgrade heavy oil and reduce viscosity. The experimental conditions are 2 wt% tetralin mass concentration, 0.5 wt% nano-Fe3O4 particle mass concentration, microwave heating time 50-60 min, and microwave power 539 W. Under this experimental condition, the viscosity is reduced by 40%. This method has viscosity recovery problems, but final viscosity reduction effect is still very significant. Obtaining the mechanism of nanoparticle-assisted microwave to enhance oil recovery, one of which is that nanoparticles improve the wave absorption and heating capacity of heavy oil and increase the heating speed of heavy oil; the second is that the nanoparticles form local high temperature under the action of microwave, which catalyzes the hydrocracking reaction between the heavy components in the heavy oil and the hydrogen donor, upgrading and reducing the viscosity of the heavy oil, and accelerating the production of heavy oil.
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Song, Bao Yu, Qing Xiang Yang, Yu Lin Qi, and Dai Zhong Su. "The Mechanochemistry of Synthetic Phosphate Oil under High Pressure." Key Engineering Materials 450 (November 2010): 185–88. http://dx.doi.org/10.4028/www.scientific.net/kem.450.185.
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The pressure-viscosity relationships of phosphate synthetic oil and other two kinds of similar atmospheric viscosity synthetic oils were studied using ultra-high pressure capillary viscometer. The pressure-viscosity relationship of phosphate synthetic oil is much better than the other two kinds of synthetic oils. The impact of pressure on viscosity is not limited to purely physical factors. The pressure can cause a variety of chemical reactions in some cases. The investigation results of mechanochemistry of phosphate synthetic oil at high pressure reveal that the physical state of phosphate synthetic oil changed from liquid into glassy amorphous state under high pressure, and the color varied from transparent into milky white. The mechanochemistry of phosphate synthetic oil was analyzed using the infrared spectroscopy and gel permeation chromatography, and the results indicate that under high pressure, the oxidation reaction of phosphate synthetic oil occurred, and the molecular weight distribution changed with the increase of the low molecular weight region. The reason of the mechanochemistry phenomena was that phosphate synthetic oil molecular chain disconnects to inform great radical. The great radical has strong activity, and reacts with other free radicals acceptor (oxygen, etc).
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Derendyaev, R. A., A. Yu Slushkina, and K. A. Derendyaev. "Experience in the Application of Technologies for Intensifying the Production of High-Viscosity Oil in Fields of Perm Region." Oil and Gas Technologies 131, no. 6 (2020): 28–33. http://dx.doi.org/10.32935/1815-2600-2020-131-6-28-33.
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This paper presents an overview of technologies for intensifying oil production in the Perm Region fields with high-viscosity oil. The analysis and evaluation of the effectiveness of all geological and technical measures in a separate field. The result of the work is the justification for the application of the most rational measures for the development of deposits with high viscosity oil in the territory of the Perm Territory, followed by the formation of geological and physical criteria for the application of technologies for fields with high viscosity oil.
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Gusev, V. V., L. E. Zemlerub, and A. M. Peshkov. "Deasphaltizing of High-Viscosity Oil at the Field." IOP Conference Series: Earth and Environmental Science 272 (June 21, 2019): 032001. http://dx.doi.org/10.1088/1755-1315/272/3/032001.
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Zhang, Hong-Quan, Cem Sarica, and Eduardo Pereyra. "Review of High-Viscosity Oil Multiphase Pipe Flow." Energy & Fuels 26, no. 7 (2012): 3979–85. http://dx.doi.org/10.1021/ef300179s.
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Schaschke, C. J., S. Allio, and E. Holmberg. "Viscosity Measurement of Vegetable Oil at High Pressure." Food and Bioproducts Processing 84, no. 3 (2006): 173–78. http://dx.doi.org/10.1205/fpb.05122.
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Bair, Scott, Mark Baker, and David M. Pallister. "The high-pressure viscosity of refrigerant/oil systems." Lubrication Science 29, no. 6 (2017): 377–94. http://dx.doi.org/10.1002/ls.1374.
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Kumbár, Vojtěch, and Jiří Votava. "Excessive Additive Effect On Engine Oil Viscosity." Acta Universitatis Agriculturae et Silviculturae Mendelianae Brunensis 62, no. 5 (2014): 1015–20. http://dx.doi.org/10.11118/actaun201462051015.
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The main goal of this paper is excessive additive (for oil filling) effect on engine oil dynamic viscosity. Research is focused to commercially distribute automotive engine oil with viscosity class 15W–40 designed for vans. There were prepared blends of new and used engine oil without and with oil additive in specific ratio according manufacturer’s recommendations. Dynamic viscosity of blends with additive was compared with pure new and pure used engine oil. The temperature dependence dynamic viscosity of samples was evaluated by using rotary viscometer with standard spindle. Concern was that the oil additive can moves engine oil of several viscosity grades up. It is able to lead to failure in the engine. Mathematical models were used for fitting experimental values of dynamic viscosity. Exponential fit function was selected, which was very accurate because the coefficient of determination R2 achieved high values (0.98–0.99). These models are able to predict viscosity behaviour blends of engine oil and additive.
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Cely, Alexandra, Ingvar Skaar, and Tao Yang. "Holistic Evaluation of Reservoir Oil Viscosity in Breidablikk Field – Including Mud Gas Logging Approach." Petrophysics – The SPWLA Journal of Formation Evaluation and Reservoir Description 64, no. 6 (2023): 919–30. http://dx.doi.org/10.30632/pjv64n6-2023a8.
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Breidablikk is a green field on the Norwegian Continental Shelf that just started the preproduction drilling of 23 wells in two structures. We have two reservoir fluid samples from exploration wells in each structure with relatively high viscosity of 4 and 8 cP, respectively. Our dynamic reservoir simulations on the Breidablikk Field indicate that any change in the viscosity in each direction can lead to a 20 to 30% difference in oil recovery. Therefore, updating our reservoir models with the viscosity distribution in the field along with the drilling activities is important. Currently, our models assume homogeneous reservoir oil viscosities across each structure. In this study, our primary aim is to conduct a holistic evaluation of the reservoir oil viscosity, using multiple methods to determine the most effective approach for qualitatively mapping the oil viscosity across the field, distinguishing between the low- and high-viscosity regions. The technologies chosen for this assessment are standard mud gas data, advanced mud gas data, and analysis of oil extracts from cuttings, given they have previously demonstrated their capability to estimate fluid properties while drilling or within a limited time frame, as evidenced by the work of Cutler et al. (2022). The methods were compared using pressure/volume/temperature (PVT) measurements as a benchmark. As of today, this method is considered the most reliable to obtain reservoir fluid properties, and in consequence, these measurements serve as the reference viscosity values in the study. The results of our analysis in Breidablikk show that an approach based on advanced mud gas data provide an oil quality classification that distinguishes between high- and low-viscosity reservoir oils, using the ethane/n-pentane ratio as the best parameter correlated to reservoir oil viscosity in Breidablikk. The threshold for the two viscosity regions is identified from a reservoir fluid database from the Breidablikk-Grane area, and the oil viscosity region estimated from advanced mud gas data agrees well with the PVT measurements. The viscosity estimation using a standard mud gas approach based on methane to propane compositions indicates that this technology cannot correctly differentiate between low- and high-viscosity region wells in the Breidablikk Field. Hence, it is not recommended. Further findings from our analysis indicate that the utilization of oil-based mud, combined with a high drilling speed, significantly affects the quality of the cuttings in Breidablikk. Consequently, the application of traditional geochemical analysis methods on cutting extracts is challenging. Therefore, this method is not recommended for the qualitative identification of the viscosity region of a given well. Benchmarking all available technologies allows us to select a real-time, reliable, and cost-efficient method to qualitatively estimate reservoir oil viscosity in Breidablikk. The selected method is field-specific and not general for other heavy oil fields. In summary, providing an accurate reservoir oil viscosity mapping at an early stage in field development plays a crucial role in the further optimization of drilling targets and ultimately leads to improved oil recovery (Halvorsen et al., 2016; Maraj et al., 2021).
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Ma, Zhenfu, Kai Zhang, Mengjie Zhao, Lu Liu, Chao Zhong, and Jian Wang. "Development and Application of Efficient Oil Displacement System for Middle-Low Permeability and High Pour-Point Heavy Oil Reservoirs." Complexity 2021 (October 31, 2021): 1–10. http://dx.doi.org/10.1155/2021/3046584.
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In view of the problems of low permeability, high oil viscosity and freezing point, and low productivity of single well in Luo 321 and Luo 36 blocks of Luojia Oilfield, the chemical viscosity-reducing cold production technology was studied. By analyzing the properties of crude oil, it is concluded that the reason for high viscosity and high freezing point is the high content of asphaltene, pectin, and wax. The viscosity is mainly affected by asphaltene; the wax precipitation point and pour point are mainly affected by the wax; and the solidification point is affected by the wax and asphaltene. The treatment idea of reducing viscosity and inhibiting wax is determined. By compounding the synthetic pour point depressant POA-VA and the viscosity reducer DBD-DOPAMA, the effect of reducing the viscosity and freezing point of crude oil was evaluated. PD-7 (POA-VA 40%, DBD-DOPAMA 50%, and P-10C 10%) system was selected as the optimal formula. When the concentration of the system is 10%, the viscosity reduction rate reaches 95.2%; the freezing point can reduce by 10.2°C; it has good oil sample adaptability, salinity resistance, and temperature resistance; and the oil washing rate can reach more than 60%. The oil displacement system was injected into the formation by means of multiconcentration and multislug and was applied in the field of Luo 321-2 Well. A total of 500 t of the oil displacement system was injected, and the effect of measures lasted for 400 days, with a cumulative oil increase of 883 t. It has been applied in different blocks 30 times and achieved a good field application effect.
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Urinov, Sobir Nasilloyevich, Parizoda Muzaffar kizi Sabirova, and Svetlana Olegovna Dobychina. "REDUCING THE VISCOSITY OF OIL CONTAINING COLLOIDAL PARTICLES ON THE BASIS OF THE FRACTAL THEORY ON THE EXAMPLE OF PRESSURE OSCILLATIONS BY ULTRASONIC IMPACT." INNOVATION IN THE OIL AND GAS INDUSTRY 2, no. 1 (2021): 61–66. http://dx.doi.org/10.26739/2181-1482-2021-1-10.
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The content of the work consists in obtaining from high-viscosity oil, oil with a lower viscosity, in order to increase oil recovery. Proceeding from the fact that today the most pressing issue is the growth of oil production, amethod for increasing oil recovery was recommended basedon the fractal theory, pressure fluctuations of the studied fluid. This analysis shows that a decrease in oil viscosity can be obtained only at small values of the amplitude of oscillations for a definite long time.Key words:High-viscosity oil, colloidal particles, fractal aggregate (FA), ultrasonic action, fractal theory, shear rate, pressure fluctuation
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Garifzyanova, G. G., and G. G. Garifzyanov. "Mild catalytic hydropyrolysis of high-viscosity, high-sulfur crude oil." Chemistry and Technology of Fuels and Oils 42, no. 1 (2006): 10–12. http://dx.doi.org/10.1007/s10553-006-0019-x.
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Фомин, А. И. "ОСОБЕННОСТИ РАЗРАБОТКИ ЯРЕГСКОГО МЕСТОРОЖДЕНИЯ ТЯЖЕЛОЙ НЕФТИ". Вестник Научного центра ВостНИИ по промышленной и экологической безопасности, № 1(9) (1 квітня 2019): 75–81. http://dx.doi.org/10.25558/vostnii.2019.30.36.007.
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В статье раскрыты особенности добычи высоковязкой нефти Ярегского месторождения, представлены различные способы извлечения нефти из недр земли. Приведены геолого-физические характеристики продуктивного пласта, показана нефтеотдача пласта при термошахтном способе извлечения высоковязкой нефти. Рассмотрена двухгоризонтная система термошахтной разработки месторождения высоковязкой нефти Ярегского месторождения, которая может послужить положительным примером разработки других месторождений высоковязкой нефти России. Отмечено воздействие вредных производственных факторов, способных вызывать профессиональные заболевания у работников подземной группы. The article presents the characteristics of high-viscosity oil recovery at the Yaregskaya field and describes various oil recovery methods. Geological-and-physical characteristics of the producing reservoir are considered. The reservoir recovery rate during the thermal mining of high-viscosity oil recovery is given. Two-level mining system for thermal mining of high-viscosity oil recovery in oil mines of the Yaregskaya field, which can be a good example for the development of other high-viscosity oil fields in Russia. The impact of harmful occupational factors that can cause occupational diseases among underground workers is noted.
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KONESEV, S. G., P. A. KHLYUPIN, A. V. GREB, and E. Y. KONDRATIEV. "INDUCTION TECHNOLOGY IN HIGH-VISCOSITY OIL PRODUCTION AT TAZOVSKOYE FIELD." Periódico Tchê Química 15, no. 30 (2018): 520–26. http://dx.doi.org/10.52571/ptq.v15.n30.2018.524_periodico30_pgs_520_526.pdf.
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The article addresses viscous and high-viscosity oil production methods that are also relevant to Tazovskoye oil-gas condensate field. Heat-affected zones have been identified to assure the most effective development of the viscous and high-viscosity oil field. Study and patent research results have been used to determine four most effective thermal methods of high-viscosity oil rheological properties con-trol: local heating, co-current heating, local stage heating, and local co-current heating. Existing thermal systems for the implementation of these thermal methods have been analyzed and electrothermal systems based on induction technology have been chosen. The efficiency of induction technology is due to a high range of the thermal flow formed and implementation of two modes: temperature maintenance and emergency heating. Local heating may be ensured by an induction downhole heater of the face area or an induction electric steam generator for the thermal action not only on the face area, but the entire producing formation. A heating device has been proposed based on results of the patent research of induction heating systems for high-viscosity oil. A versatile magnet-operated component has been proposed as a heating body of the induction heating system.
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Gizzatullina, A. A. "Investigation of the two-dimensional problem of filtration of high-viscosity oil in a formation under thermal action." Proceedings of the Mavlyutov Institute of Mechanics 12, no. 2 (2017): 232–37. http://dx.doi.org/10.21662/uim2017.2.035.
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A theoretical and numerical study of developing a reservoir with high-viscosity oil using the technology of pair horizontal wells is presented. In a two-dimensional formulation, numerical solutions to the problem of the possibility of extracting high-viscosity oil from a formation with the use of thermal action were obtained. The proposed method is aimed at increasing the efficiency of developing an oil reservoir with high viscosity oil by ensuring a uniform warming up of the developing zone of the field. The adopted model allows to trace a detailed two-dimensional picture of oil filtration in the reservoir and to investigate the main regularities of this process.
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Prater, Walter, John Burns, Garvin Stone, and Tom Ting. "Evaluation of Perfluorinated Polyalkylether Grease Rheology on Disk Drive Bearing Performance." Journal of Tribology 120, no. 1 (1998): 21–27. http://dx.doi.org/10.1115/1.2834182.
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A matrix of specially formulated greases composed of perfluorinated polyalkylether (PFPE) oil and telomers of polytetrafluoroethylene (PTFE) particulate thickener were tested. The PFPE greases were chosen for this evaluation because their oils have a very low vapor pressure and they will not volatilize in the disk drive. Base oil viscosity, PTFE particle size and percentage of oil content were varied. The rheological properties of complex viscosity, storage and loss moduli, and loss factor were measured. Percent oil was determined using thermal gravimetric analysis. The thickener’s PTFE particle sizes were measured and their shapes were imaged using scanning electron microscopy. Bearing low speed torque and bearing noise tests were performed to evaluate the effect of the grease on bearing performance. The head settle track misregistration (TMR) was measured on disk drives to measure the effect of bearing lubrication on the servo performance. Generally, greases with high base oil viscosity had the lowest complex viscosity. Greases with highest viscosity PFPE oils had the highest torque and lowest noise. Greases with large PTFE particles had high loss factors and exhibited high torque and noise levels. High PTFE thickener to PFPE oil ratio (thicker grease) causes the bearings to have fluctuations in torque and noise levels. Actuator bearings lubricated with greases having higher viscosity oil had lower head settle TMR.
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Pham Trong, Hoa. "Analysis effects of oil viscosity and temperature on orbit of ring gear in internal gear motor and pump." Transport and Communication Science Journal 70, no. 3 (2019): 153–61. http://dx.doi.org/10.25073/tcsj.70.3.1.
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Effect of oil temperature and viscosity on the ring gear orbit in the internal gear motor and pump is analyzed in this study. The mobility method is used to calculate the ring gear orbit. The mathematical model of oil viscosity and temperature is then integrated into the mobility method. The simulation results point out that the oil temperature and viscosity have great effect on the eccentricity, position angle and minimum oil film thickness. The metal - to - metal contact phenomenon occurs if internal gear motor and pump operates under high values of oil temperature or low values of oil viscosity conditions.
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Pham Trong, Hoa. "Analysis effects of oil viscosity and temperature on orbit of ring gear in internal gear motor and pump." Transport and Communications Science Journal 70, no. 3 (2019): 153–61. http://dx.doi.org/10.25073/tcsj.70.3.23.
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Effect of oil temperature and viscosity on the ring gear orbit in the internal gear motor and pump is analyzed in this study. The mobility method is used to calculate the ring gear orbit. The mathematical model of oil viscosity and temperature is then integrated into the mobility method. The simulation results point out that the oil temperature and viscosity have great effect on the eccentricity, position angle and minimum oil film thickness. The metal - to - metal contact phenomenon occurs if internal gear motor and pump operates under high values of oil temperature or low values of oil viscosity conditions.