Academic literature on the topic 'High-viscosity oil'
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Journal articles on the topic "High-viscosity oil"
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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.
Dissertations / Theses on the topic "High-viscosity oil"
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Al-Awadi, Hameed. "Multiphase characteristics of high viscosity oil." Thesis, Cranfield University, 2011. http://dspace.lib.cranfield.ac.uk/handle/1826/13902.
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Heavy oil production has drawn more and more attention in petroleum industry. The amount of heavy oil in the world is twice more than the conventional oil (low viscosity), which has been consumed rapidly from the past. The understanding of flow patterns and pressure losses in multiphase flow with high viscosity oil are vital to assist the design of transportation pipeline. This thesis involves experimental investigation of two phase and three phase flows under high oil viscosity conditions (up to 17000cP) in horizontal pipelines. The multiphase (oil/water/solid/gas) facility was designed and constructed at Cranfield University and consists of 6m long horizontal pipeline of 0.026m diameter along with instrumentations. The principal objectives of the work were to study the effect of viscosity, water cut, temperature variance, and flow conditions on flow patterns and pressure drops for (oil/gas and oil/water) two phase flows; to compare the measured flow parameters and phase distribution with those predicted from models found in the literature for two phase flows; and to conduct an experimental study of gas injection effect on pressure gradient in (oil/water/gas) three phase flow. Due to the nature of heavy oil reservoirs, sand is associated with oil/water mixture when extracted; therefore sand concentration effect on pressure drop in (oil/water/sand) three phase flow is also examined. For oil-air flow, a smooth oil coating was observed in the film region of slug flow, while a ripple structure of oil coating film was found at higher superficial air velocity for slug flow regime and annular flow regime. The ripple structure was believed to increase the effective roughness of the pipe wall, which resulted in higher pressure gradients. The pressure drop correlations from Beggs and Brill (1973) and Dukler et al. (1964) were used to compare with experimental pressure gradients for oil/air flow. It was found that these correlations failed to predict the pressure gradients for heavy oil/air flows in this work. Several new heavy oil/water flow patterns were named and categorized based on observations. Though the heavy oil viscosity is an essential parameter for oil continuous phase flow on pressure drop, it had no significant effect beyond Water Assist Flow (WAF) condition, as a threshold was found for water cut with fixed superficial oil velocity. The transition criterion by McKibben et al. (2000b) for WAF was found to be able to predict this threshold reasonably well. Core Annular Flow (CAF) models were found to greatly under predict the pressure gradients mainly due to the coating (oil fouling) effect associated with this study. A new coating coefficient was introduced to models presented by Bannwart (2001) and Rodriguez et al (2009). The addition of solid in the mixed flow led to minor increase in the pressure gradient when the particles were moving with the flow. However, higher sand concentration in the system led to higher pressure gradient values. The addition of gaseous phase to the oil/water flow was more complex. The gaseous injection was beneficial toward reducing the pressure gradient when introduced in oil continuous phase only at very low water cuts.
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Mohammed, Shara Kamal. "Gas-high viscosity oil flow in vertical large diameter pipes." Thesis, University of Nottingham, 2017. http://eprints.nottingham.ac.uk/43311/.
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Gas flow in columns of high viscosity liquids is found in heavy oil and bitumen production, polymer manufacturing and in Volcanology as silicate magmas in the volcanic conduit. Predicting the characteristics of the hydrodynamics of gas flow, under such conditions is essential in both design and safety assessments. In oil and gas industry, it is very important in the design of the equipment and the very long pipelines. Further, it is important in the design and safety of the industrial equipment and the pipelines in the polymer manufacturing. Finally, the ability to predict natural phenomenon and develop the knowledge about volcanoes activity and the nature of eruptions in volcanoes is important for the assessment of environmental risks. The majority of the works, which have studied gas-liquid flow in pipes, have been carried out mainly by using water or liquids of low viscosities (< 1 Pa.s). Knowledge, regarding the hydrodynamics of gas flow in high viscosity liquids and large diameter columns, is still limited though despite the importance of this subject. In this work, the characteristics of gas-high viscosity oils in large diameter columns were studied over a wide range of gas flow rates. Two column geometries were used: one of 240 mm and the other of 290 mm internal diameter. The columns were initially filled with stagnant Silicone oil of viscosities 360 and 330 Pa.s respectively. Electrical Capacitance Tomography (ECT) technique was employed for the data measurements besides a high-resolution camera. In general, 4 flow patterns are found over the selected range of gas flow rates. These are seen to differ from the ones in lower viscosity liquids. First, bubbly flow consists of single spherical bubbles that rise at a constant velocity in the centre of the column at low gas flow rates. Second, slug flow which consists of long bubbles (Taylor bubble) with rounded top and end, with a diameter almost equal to the column diameter and separated by liquid slugs. The third flow pattern is the transition to churn flow which occurs due to further increase of gas flow rate. The falling film, around the very long bubbles, accumulates to create regions of high frequency activity that consists of liquid bridges. These regions are named “churn” regions. The length of this region increases gradually with increasing the gas flow rate. At very high gas flow rates, the gas flows through an open wavy non-symmetrical core in the column of the viscous oil (churn regions). The length of the churn regions increases significantly at this flow regime which can be named churn flow regime. Small bubbles of millimetres to centimetres diameter are seen to accumulate in the column due to the high viscosity and low velocity of the liquid motion. These bubbles generate due to the bubble eruption at the top section, bubble coalescence along the column and at the gas injection points at the bottom of the column.
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Shi, Jing. "A study on high-viscosity oil-water two-phase flow in horizontal pipes." Thesis, Cranfield University, 2015. http://dspace.lib.cranfield.ac.uk/handle/1826/9654.
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A study on high-viscosity oil-water flow in horizontal pipes has been conducted applying experimental, mechanism analysis and empirical modelling, and CFD simulation approaches. A horizontal 1 inch flow loop was modified by adding a designed sampling section to achieve water holdup measurement. Experiments on high-viscosity oil-water flow were conducted. Apart from the data obtained in the present experiments, raw data from previous experiments conducted in the same research group was collated. From the experimental investigation, it is found that that the relationship between the water holdup of water-lubricated flow and input water volume fraction is closely related to the oil core concentricity and oil fouling on the pipe wall. The water holdup is higher than the input water volume fraction only when the oil core is about concentric. The pressure gradient of water-lubricated flow can be one to two orders of magnitude higher than that of single water flow. This increased frictional loss is closely related to oil fouling on the pipe wall. Mechanism analysis and empirical modelling of oil-water flow were conducted. The ratio of the gravitational force to viscous force was proposed to characterise liquid-liquid flows in horizontal pipes into gravitational force dominant, viscous force dominant and gravitational force and viscous force comparable flow featured with different basic flow regimes. For viscous force dominant flow, an empirical criterion on the formation of stable water-lubricated flow was proposed. Existing empirical and mechanistic models for the prediction of water holdup and/or pressure gradient were evaluated with the experimental data; the applicability of different models is demonstrated. Three-dimensional CFD modelling of oil-water flow was performed using the commercial CFD code Fluent. The phase configurations calculated from the CFD model show a fair agreement with those from experiments and mechanism analysis. The velocity distribution of core annular flow is characterised with nearly constant velocity across the oil core when the oil viscosity is significantly higher than the water viscosity, indicating that the high-viscosity oil core flows inside the water as a solid body. The velocity profile becomes similar to that of single phase flow as the oil viscosity becomes close to the water viscosity.
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Alagbe, Solomon Oluyemi. "Experimental and numerical investigation of high viscosity oil-based multiphase flows." Thesis, Cranfield University, 2013. http://dspace.lib.cranfield.ac.uk/handle/1826/10495.
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Multiphase flows are of great interest to a large variety of industries because flows of two
or more immiscible liquids are encountered in a diverse range of processes and
equipment. However, the advent of high viscosity oil requires more investigations to
enhance good design of transportation system and forestall its inherent production
difficulties.
Experimental and numerical studies were conducted on water-sand, oil-water and oilwater-
sand respectively in 1-in ID 5m long horizontal pipe. The densities of CYL680 and
CYL1000 oils employed are 917 and 916.2kg/m3 while their viscosities are 1.830 and
3.149Pa.s @ 25oC respectively. The solid-phase concentration ranged from 2.15e-04 to
10%v/v with mean diameter of 150micron and material density of 2650kg/m3.
Experimentally, the observed flow patterns are Water Assist Annular (WA-ANN),
Dispersed Oil in Water (DOW/OF), Oil Plug in Water (OPW/OF) with oil film on the
wall and Water Plug in Oil (WPO). These configurations were obtained through
visualisation, trend and the probability density function (PDF) of pressure signals along
with the statistical moments. Injection of water to assist high viscosity oil transport
reduced the pressure gradient by an order of magnitude. No significant differences were
found between the gradients of oil-water and oil-water-sand, however, increase in sand
concentration led to increase in the pressure losses in oil-water-sand flow.
Numerically, Water Assist Annular (WA-ANN), Dispersed Oil in Water (DOW/OF), Oil
Plug in Water (OPW/OF) with oil film on the wall, and Water Plug in Oil (WPO) flow
pattern were successfully obtained by imposing a concentric inlet condition at the inlet of
the horizontal pipe coupled with a newly developed turbulent kinetic energy budget
equation coded as user defined function which was hooked up to the turbulence models.
These modifications aided satisfactory predictions.
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Sancet, Aitor. "Study of heat transfer and flow pattern in a multiphase fuel oil circular tank." Thesis, University of Gävle, University of Gävle, Department of Technology and Built Environment, 2009. http://urn.kb.se/resolve?urn=urn:nbn:se:hig:diva-4926.
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<p>This is a thesis work proposed by Sweco System in order to carry out a study related to the heating system of a circular fuel oil storage tank or cistern. The study tank is a 23m diameter and 18m height with a storage capacity of around 7500m3 of Eo5 heavy fuel oil. The content ought to be at a minimum storage temperature of 50ºC so that the fuel oil is fluid enough and operation labors can be adequately performed. In fact, these types of heavy fuel oils have fairly high viscosities at lower temperatures and the heating and pumping system can be compromised at temperatures below the pour point. For this purpose a heating system is installed to maintain the fluid warm. So far the system was operated by an oil burner but there are plans to its replacement by a District Heating-heat exchanger combo. Thereby, tank heating needs, flow and thermal patterns and heat transfer within it are principally studied.</p><p> </p><p>Tank boundaries are studied and their thermal resistances are calculated in order to dimension heat supply capacity. The study implies Finite Elements (Comsol Multiphysics) and Finite Volume (Fluent) analysis to work out some stationary heat transfer by conduction cases on some parts and thermal bridges present on these boundaries. Afterwards both cooling and heating processes of the fuel oil are studied using several strategies: basic models and Computational Fluid Dynamics (CFD). CFD work with Fluent is focused on optimizing inlet and outlet topologies. Understanding the cooling process is sought as well; Fluent CFD transient models are simulated in this way as well. Additionally the effect of filling levels is taken into account leading to a multiphase (fuel oil and air) flow cases where especially heating coupling of both phases is analyzed.</p><p> </p><p>Results show that maximum heat supply needs are around 80kW when the tank temperature is around 60ºC and 70kW when it is around 50ºC. Expectedly the main characteristic of the flow turns out to be the buoyancy driven convective pattern. K-ε turbulence viscous models are applied to both heating and cooling processes showing thermal stratification, especially at the bottom of the tank. Hotter fluid above follows very complex flow patterns. During the heating processes models used predict fairly well mixed and homogenous temperature distribution regardless small stratification at the bottom of the tank. In this way no concrete inlet-outlet configuration shows clear advantages over the rest. Due to the insulation of the tank, low thermal conductivity of the fluid and vast amount of mass present in the tank, the cooling process is slow (fluid average temperature drops around 5.7 ºC from 60ºC in 15 days when the tank is full and ambient temperature is considered to be at -20ºC) and lies somewhere in the middle between the solid rigid and perfect mixture cooling processes. However, due to stratification some parts of the fluid reach minimum admissible temperatures much faster than average temperature does. On the other hand, as expected, air phase acts as an additional thermal resistance; anyhow the cooling process is still faster for lower filling levels than the full one.</p><br><p>El presente proyecto fue propuesto por Sweco Systems para llevar a cabo un estudio relacionado con el sistema de calefacción de una cisterna o tanque de almacenamiento de fuel oil circular. Dicho tanque tiene 23 m de diámetro y 18 m de altura con una capacidad de almacenamiento de alrededor de 7500 m<sup>3</sup> de Eo5 fuel oil pesado. El contenido mantenerse a una temperatura mínima de 50 ºC de manera que el fuel oil es suficientemente fluido para que las labores de operación puedan ser ejecutadas adecuadamente. De hecho, estos tipos de fuel oil pesado tienen altas viscosidades a bajas temperaturas y, por tanto, tanto los sistemas de calefacción y como el de bombeo pueden verse comprometidosr a temperaturas por debajo del pour point. Con este fin un sistema de calefacción es instalado para mantener el fluido suficientemente caliente. Hasta el momento, el sistema era operado por un quemador de fuel, sin embargo, hay planes que éste sea sustituido por un combo intercambiador de calor-District Heating. Por lo tanto, principalmente son estudiadas las necesidades de calefacción así como los flujos térmicos y fluidos.</p><p>Se estudian las fronteras del tanque, y sus respectivas resistencias térmicas son calculadas con el fin de dimensionar la capacidad necesaria de suministro de calor. El estudio implica Elementos Finitos (Comsol Multiphysics) y Volúmenes Finitos (Fluent) para elaborar análisis estacionarios de transferencia de calor por conducción en algunos casos. Existen puentes térmicos en las paredes y su importancia es también anallizada. Posteriormente se estudian tanto los procesos de calentamiento y enfriamiento del fuel oil utilizando diversas estrategias: modelos básicos y Dinámica de Fluidos Computacional (CFD). El trabajo con CFD se centra en la optimización de topologías de entradas y salidas del sistema. También es solicitado entender el proceso de enfriamiento; En este sentido, se simulan modelos CFD transitorios de Fluent. Además, el efecto de los niveles de llenado se tiene en cuenta dando lugar a estudios de flujo multifase (fuel oil y aire), haciendo hincapié en el análisis de acoplamiento de transferencia de calor entre las dos fases.</p><p>Los resultados muestran que las necesidades de calefacción máximas son de alrededor de 80kW cuando la temperatura del tanque es de alrededor de 60 º C y 70kW cuando está alrededor de 50 ºC. Como era de esperar, la principal característica de este tipo de flujos es la convección natural resultante de las fuerzas de flotabilidad. Se aplican modelos turbulentos k-ε a los procesos de calentamiento y enfriamiento, mostrando estratificación térmica, sobre todo en la parte inferior de la cisterna. El líquido más caliente que se sitúa encima muestra complejos patrones de flujo. Durante los procesos de calentamiento, los modelos utilizados predicen un buen mezclado y distribución homogénea de la temperatura independientemente de esta pequeña estratificación en la parte inferior de la cisterna. De esta manera, ninguna concreta configuración de entradas-salidas simuladas muestra claras ventajas sobre el resto. Debido al aislamiento de la cisterna, la baja conductividad térmica del fluido y la gran cantidad de masa presente en el tanque el proceso de enfriamiento es lento (la temperatura media del fluido desciende 5.7 º C desde 60 º C en 15 días cuando el tanque está lleno y la temperatura ambiente es de -20 º C) y se encuentra en algún lugar en medio de los procesos de enfriamiento del sólido rígido y perfecta mezcla. Sin embargo, debido a la estratificación, algunas partes el líquido alcanzan la temperatura mínima admisible mucho más rápido que la media de temperatura. Por otra parte, como se esperaba, la fase de aire actúa como una resistencia térmica adicional, de todos modos, el proceso de enfriamiento es aún más rápido para niveles de llenado más bajos que el lleno.</p>
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Якимечко, Я. Я. "Удосконалення технології видобування високов'язких нафт струминними насосами з використанням енергії пульсуючих потоків". Thesis, Івано-Франківський національний технічний університет нафти і газу, 2013. http://elar.nung.edu.ua/handle/123456789/4651.
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Дисертація присвячена проблемі удосконалення технології видобування високов’язких нафт струминними насосами з розділеними робочими потоками з використанням енергії пульсуючих потоків із свердловин глибиною до 2000 м. В дисертації проведено теоретичні дослідження пульсаційно-хвильових явищ, зокрема кавітації, яку штучно створюють в потоці робочої рідини при проходженні нею через гідродинамічний кавітатор. Експериментально визначено характер пульсацій потоку робочої рідини, який полягає у зменшенні величин тиску на виході з вихрової камери з амплітудою від 0,21 до 0,28 МПа і частотою від 10 до 12 Гц. Встановлено, що виникнення кавітації на виході з гідродинамічного кавітатора спричиняє руйнування просторової структури високов’язкої нафти, розривання її полімолекулярних ланцюгів і призводить до зниження її в’язкості. Результати проведених лабораторних і стендових досліджень та промислових випробувань використані при розробці стандарту підприємства ВАТ «Укрнафта» СТП 320.00135390.016-98 «Технологія видобування високов’язких нафт за допомогою вставного струминного апарату з розділеними робочими потоками». Стандарт введено в дію вперше.<br>Диссертация посвящена проблеме совершенствования технологии добычи высоковязких нефтей струйными насосами с разделенными рабочими потоками с использованием энергии пульсирующих потоков из скважин глубиной до 2000 м. В диссертации приведены теоретические исследования импульсно-волновых явлений, в частности кавитации, которая искусственно создается в потоке рабочей жидкости при прохождении через гидродинамический кавитатор. Экспериментально определено характер пульсаций потока рабочей жидкости, который заключается в уменьшении величины давления на выходе из вихревой камеры с амплитудой от 0,21 до 0,28 МПа и частотой от 10 до 12 Гц. Установлено, что создание искусственной кавитации на выходе из гидродинамического кавитатора приводит к возникновению знакопеременных давлений, благодаря которым разрушается механическая структура высоковязкой нефти, что способствует снижению вязкости высоковязкой нефти. Во время стендовых эксепериментальных исследований наиболее интенсивное снижение кинематической вязкости в 4 раза наблюдалось на протяжении первых 120-200 секунд обработки нефти гидродинамическим кавитатором, что соответствует интервалу времени, за которое прокачивается весь объем нефти через устройство. В последующем вязкость уменьшается уже не так интенсивно, но стабильно. С целью определения работоспособности опытного образца комплекта оборудования для добычи высоковязких нефтей на скважине № 95 Бугруватовского месторождения были проведены промышленные приемные испытания. После проведения промышленных испытаний комиссией был составлен акт и сделаны выводы и рекомендации: 1. Комплект оборудования для добычи высоковязких нефтей работоспособен. 2. Рекомендуется внедрить на нефтедобывающих предприятиях Украины, разработав типичную технологию добычи высоковязких нефтей.
Результаты проведенных лабораторных и стендовых исследований, а также промышленных испытаний использованы при разработке стандарта предприятия ОАО «Укрнефть» СТП 320.00135390.016-98 «Технология добычи высоковязких нефтей с помощью вставного струйного аппарата с разделенными рабочими потоками». Стандарт введен впервые.<br>The thesis deals with the improvement of technology of production of high-viscosity oils with the help of split flow jet pumps using energy of fluctuating flows from the up to 2000 m deep oil wells. The thesis carriesouttheoreticalinvestigation of pulse-wave phenomena, particularly of cavitation, which is artificially created in the stream of operating fluid during its passage through the hydrodynamicalpulsator (cavitator). The hydrodynamic analysis of the process of cavitation in the swirling flow was held, which has indicated that one part ofkineticenergythatissupplied to the jet device is used for the work of the pump and for the overcoming of friction, and another one - for the incrementation of internal heat of oil. The nature of operating fluid flow fluctuation is determined. It lies in the reduction of pulse chamber outlet pressure with the amplitude of 0,21 to 0,28 MPa and the frequency of 10 to 12 Hz. It is determinedthat the beginning of cavitation at the outlet of the cavitator causes heating of oil and reduction of its viscosity. The results of the laboratory research and bench test, as well as industrial test were used during the preparation of the standard of the OJSC “Ukmafta” (Company Specification 320.00135390.016-98 “Technology of Production of High-Viscosity Oils with the Help of Insert Split Flow Jet Device”). The standard is implemented for the first time.
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Кондрат, О. Р. "Прикладні і теоретичні основи підвищення ефективності дорозробки виснажених родовищ газу і нафти". Thesis, Івано-Франківський національний технічний університет нафти і газу, 2014. http://elar.nung.edu.ua/handle/123456789/4678.
Full textAbstract:
Дисертація присвячена розробленню нових і вдосконаленню традиційних технологій підвищення ступеня вилучення і поточного видобутку газу, нафти і конденсату з виснажених родовищ природних вуглеводнів. Запропоновано аналітичну залежність поточного пластового тиску в газовому родовищі від характеристик привибійної зони пласта і технологічних параметрів роботи свердловин та системи збору газу. Розроблено математичну модель процесу взаємодії у виснаженому газовому родовищі ділянок пласта різної проникності з перетіканням газу між ними. Сформульовано і розв’язано обернену задачу теорії розробки родовищ природних газів, яка дає змогу оцінити забалансові запаси газу в некондиційних колекторах. Встановлено основні закономірності процесу вилучення защемленого газу з обводнених газових родовищ з макронеоднорідними колекторами. Досліджено задачу формування і розформування конуса підошовної води стосовно до циклічної, періодичної експлуатації свердловин на родовищах з підошовною водою. Обґрунтовано методи вилучення сконденсованих вуглеводнів з виснажених газоконденсатних родовищ і залишкової високов’язкої нафти з обводнених нафтових родовищ. Запропоновано диференційований підхід до буріння ущільнювальних свердловин на виснажених нафтових родовищах. Обґрунтувано методи очищення привибійної зони газоконденсатних свердловин від сконденсованих вуглеводнів, води і твердої фази, винесення рідини з низьконапірних газових та газоконденсатних свердловин і піднімання високов’язкої нафти з нафтових свердловин.
Результати прикладних і теоретичних досліджень пройшли дослідно-промислові випробування і впроваджені на родовищах України.<br>Диссертация посвящена разработке новых и усовершенствованию традиционных технологий увеличения степени извлечения и текущей добычи газа, нефти и конденсата из истощенных месторождений природных углеводородов. В работе охарактеризованы особенности и проблемы завершающей стадии разработки месторождений газа и нефти, остаточные запасы углеводородов в истощенных месторождениях и известные технологии заключительной стадии разработки месторождений природных углеводородов. Обоснованы направления научных исследований актуальной проблемы повышения газонефтеконденсатоотдачи и интенсификации добычи газа, нефти и конденсата из истощенных месторождений природных углеводородов. По результатам теоретических исследований получена аналитическая зависимость текущего пластового давления в газовом месторождении с газовым режимом разработки от характеристик призабойной зоны пласта и технологических параметров работы скважин и системы сбора газа. Предложена математическая модель процесса взаимодействия в газовом месторождении с макронеоднородными коллекторами участков пласта различной проницаемости и степени дренирования с перетоками газа между ними. Сформулирована и решена в оптимизационной постановке обратная задача теории разработки газовых месторождений, которая позволяющая оценить забалансовые запасы газа в некондиционных коллекторах. Экспериментально на моделях пласта установлены основные закономерности извлечения защемленного газа с обводненных газовых месторождений с макронеоднородными коллекторами. Предложена технология повышения газоотдачи обводненных газовых месторождений снижением в них давления путем совместного отбора газа с водой из добывающих скважин при одновременном блокировании поступления в месторождение законтурной воды нагнетанием неуглеводородного газа в приконтурные скважины. По результатам экспериментов на моделях пласта разработаны технологии извлечения сконденсированных углеводородов из истощенных газоконденсатных месторождений и остаточной высоковязкой нефти из обводненных нефтяных месторождений. На основании компьютерных экспериментов установлены закономерности процессов формирования и расформирования конусов подошовенной воды при периодической цикличной эксплуатации добывающих скважин на газовых месторождениях. Обоснован дифференциальный подход к бурению уплотняющих скважин на истощенных нефтяных месторождениях, который, в зависимости от распределения нефтенасыщенности и пластового давления на площади месторождения, предусматривает бурение в зонах концентрации невыработанных запасов нефти только добывающих или только нагнетательных скважин или одновременное бурение нагнетательных скважин в зонах пониженного пластового давления и добывающих - в зонах с повышенным пластовым давлением. На основании лабораторных экспериментов и опытно-промышленных работ обоснованы методы очистки призабойной зоны газоконденсатных скважин от сконденсированных углеводородов, воды и твердой фазы, выноса жидкости с низконапорных газовых и газоконденсатных скважин и интенсификации добычи высоковязкой нефти из нефтяных скважин. Результаты прикладных и теоретических исследований прошли опытнопромысловые испытания и внедрены на месторождениях Украины.<br>The thesis is devoted to the development of new and improvement of existing technologies of increasing the degree of recovery and current gas, oil and gas-condensate from the depleted fields of natural hydrocarbons. The analytical dependence of the current reservoir pressure in the gas field was proposed based on the near bottomhole zone characteristics of the reservoir and technological schedule of the wells and gas gathering system operation. The mathematical model of interaction between zones with different permeability in depleted gas field and gas migration between them was developed. The inverse problem of the theory of natural gas field development was formulated and solved, which allows to estimate outbalance gas reserves in substandard collectors. The basic regularities of the trapped gas recovery process from watered gas fields with macroheterogeneous collectors were determined. The problem of the formation and disbandment of the bottom water cone was investigated applied to the cyclic, periodic wells operation in the fields with bottom water. The methods of condensed hydrocarbons extracting from depleted gas-condensate fields and high-viscosity residual oil from flooded oil fields were substantiated. A differentiated approach to in-fill wells drilling in depleted oil fields was proposed. The methods of bottomhole zone cleaning from condensed hydrocarbons, water and solids, fluid removal from low-pressure gas and gas-condensate wells and lifting high-viscosity oil from oil wells were proved. The results of applied and theoretical studies have been pilot-scale tested and implemented in the fields of Ukraine.
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Babak, LotfizadehDehkordi Dr. "RHEOLOGY AND TRIBOLOGY OF LUBRICANTS WITH POLYMERIC VISCOSITY MODIFIERS." University of Akron / OhioLINK, 2015. http://rave.ohiolink.edu/etdc/view?acc_num=akron1438208488.
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Mohan, Avulapati Madan. "Air-Assited Atomization Strategies For High Viscosity Fuels." Thesis, 2012. https://etd.iisc.ac.in/handle/2005/2506.
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Atomization of fuel is an important pre-requisite for efficient combustion in devices such as gas turbines, liquid propellant rocket engines, internal combustion engines and incinerators. The overall objective of the present work is to explore air-assisted atomization strategies for high viscosity fuels and liquids. Air-assisted atomization is a twin-fluid atomization method in which energy of the gas is used to assist the atomization of liquids. Broadly, three categories of air-assisted injection, i.e., effervescent, impinging jet and pre-filming air-blast are studied. Laser-based diagnostics are used to characterize the spray structure in terms of cone angle, penetration and drop size distribution. A backlit direct imaging method is used to study the macroscopic spray characteristics such as spray structure and spray cone angle while the microscopic characteristics are measured using the Particle/droplet imaging analysis (PDIA) technique.
Effervescent atomization is a technique in which a small amount of gas is injected into the liquid at high pressure in the form of bubbles. Upon injection, the two-phase mixture expands rapidly and shatters the liquid into droplets and ligaments. Effervescent spray characteristics of viscous fuels such as Jatropha and Pongamia pure plant oils and diesel are studied. Measurements are made at various gas-to-liquid ratios (GLRs) and injection pressures. A Sauter Mean Diameter (SMD) of the order of 20 µm is achieved at an injection pressure of 10 bar and GLR of 0.2 with viscous fuels. An image-based method is proposed and applied to evaluate the unsteadiness in the spray. A map indicating steady/unsteady regime of operation has been generated. An optically accessible injector tip is developed which has enabled visualization of the two-phase flow structure inside the exit orifice of the atomizer. An important contribution of the present work is the correlation of the two-phase flow regime in the orifice with the external spray structure. For viscous fuels, the spray is observed to be steady only in the annular two-phase flow regime. Unexpanded gas bubbles observed in the liquid core even at an injection pressure of 10 bar indicate that the bubbly flow regime may not be beneficial for high viscosity oils.
A novel method of external mixing twin-fluid atomization is developed. In this method, two identical liquid jets impinging at an angle are atomized using a gas jet. The effect of liquid viscosity (1 cP to 39 cP) and surface tension (22 mN/m to 72 mN/m) on this mode of atomization is studied by using water-glycerol and water-ethanol mixtures, respectively. An SMD of the order of 40 µm is achieved for a viscosity of 39 cP at a GLR of 0.13 at a liquid pressure of 8 bar and gas pressure of 5 bar. It is observed that the effect of liquid properties is minimal at high GLRs where the liquid jets are broken before the impingement as in the prompt atomization mode. Finally, a pre-filming air-blast technique is explored for transient spray applications. An SMD of 22 µm is obtained with diesel at liquid and gas pressures as low as 10 bar and 8.5 bar, respectively. With this technique, an SMD of 44 µm is achieved for Jatropha oil having a viscosity 10 times higher than that of diesel.
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Mohan, Avulapati Madan. "Air-Assited Atomization Strategies For High Viscosity Fuels." Thesis, 2012. http://etd.iisc.ernet.in/handle/2005/2506.
Full textAbstract:
Atomization of fuel is an important pre-requisite for efficient combustion in devices such as gas turbines, liquid propellant rocket engines, internal combustion engines and incinerators. The overall objective of the present work is to explore air-assisted atomization strategies for high viscosity fuels and liquids. Air-assisted atomization is a twin-fluid atomization method in which energy of the gas is used to assist the atomization of liquids. Broadly, three categories of air-assisted injection, i.e., effervescent, impinging jet and pre-filming air-blast are studied. Laser-based diagnostics are used to characterize the spray structure in terms of cone angle, penetration and drop size distribution. A backlit direct imaging method is used to study the macroscopic spray characteristics such as spray structure and spray cone angle while the microscopic characteristics are measured using the Particle/droplet imaging analysis (PDIA) technique.
Effervescent atomization is a technique in which a small amount of gas is injected into the liquid at high pressure in the form of bubbles. Upon injection, the two-phase mixture expands rapidly and shatters the liquid into droplets and ligaments. Effervescent spray characteristics of viscous fuels such as Jatropha and Pongamia pure plant oils and diesel are studied. Measurements are made at various gas-to-liquid ratios (GLRs) and injection pressures. A Sauter Mean Diameter (SMD) of the order of 20 µm is achieved at an injection pressure of 10 bar and GLR of 0.2 with viscous fuels. An image-based method is proposed and applied to evaluate the unsteadiness in the spray. A map indicating steady/unsteady regime of operation has been generated. An optically accessible injector tip is developed which has enabled visualization of the two-phase flow structure inside the exit orifice of the atomizer. An important contribution of the present work is the correlation of the two-phase flow regime in the orifice with the external spray structure. For viscous fuels, the spray is observed to be steady only in the annular two-phase flow regime. Unexpanded gas bubbles observed in the liquid core even at an injection pressure of 10 bar indicate that the bubbly flow regime may not be beneficial for high viscosity oils.
A novel method of external mixing twin-fluid atomization is developed. In this method, two identical liquid jets impinging at an angle are atomized using a gas jet. The effect of liquid viscosity (1 cP to 39 cP) and surface tension (22 mN/m to 72 mN/m) on this mode of atomization is studied by using water-glycerol and water-ethanol mixtures, respectively. An SMD of the order of 40 µm is achieved for a viscosity of 39 cP at a GLR of 0.13 at a liquid pressure of 8 bar and gas pressure of 5 bar. It is observed that the effect of liquid properties is minimal at high GLRs where the liquid jets are broken before the impingement as in the prompt atomization mode. Finally, a pre-filming air-blast technique is explored for transient spray applications. An SMD of 22 µm is obtained with diesel at liquid and gas pressures as low as 10 bar and 8.5 bar, respectively. With this technique, an SMD of 44 µm is achieved for Jatropha oil having a viscosity 10 times higher than that of diesel.
Books on the topic "High-viscosity oil"
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Spearot, JA, ed. High-Temperature, High-Shear Oil Viscosity: Measurement and Relationship to Engine Operation. ASTM International, 1989. http://dx.doi.org/10.1520/stp1068-eb.
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1945-, Spearot James A., ASTM Committee D-2 on Petroleum Products and Lubricants., and Symposium on High-Temperature, High-Shear (HTHS) Oil Viscosity (1988 : Anaheim, Calif.), eds. High-temperature, high-shear (HTHS) oil viscosity: Measurement and relationship to engine operation. ASTM, 1989.
Find full textBook chapters on the topic "High-viscosity oil"
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Li, Yongxiang, Xiatong Kang, Qi Gao, and Yongjie Jia. "Rheological Properties of Composite Modified Asphalt with Direct Coal Liquefaction Residues." In Lecture Notes in Civil Engineering. Springer Nature Singapore, 2023. http://dx.doi.org/10.1007/978-981-99-1748-8_5.
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AbstractIn order to solve the problem of high-value utilization of coal-to-oil residual direct coal liquefaction residual asphalt, it is compounded with SBS and aromatic oil to modify the matrix asphalt, and 9 compounding schemes are designed using orthogonal experimental methods. Dynamic frequency sweep tests using DSR and a simplified Carreau equation model fitted to the complex viscosity to obtain its zero shear viscosity; the creep recovery rate, irrecoverable creep flexibility and irrecoverable creep flexibility difference of each modified asphalt were determined by MSCR at different temperatures and stress levels, and the high temperature rheological properties of 9 composite modified asphalts were evaluated by grey correlation analysis of zero shear viscosity and high temperature rheological parameters. Bending beam rheological experiments were carried out on the aged composite modified asphalt to analyse its low temperature rheological properties based on the viscoelastic parameters and linear fitting of the Burgers model. The results show that: The high temperature deformation resistance of DCLR composite modified asphalt are better than the matrix asphalt, the most influential modifier is SBS, and the higher the dose, the stronger the high temperature deformation resistance. The unrecoverable creep flexibility Jnr3.2 at 70 °C can better respond to the high temperature performance of asphalt, the ratio of 9% DCLR + 4% SBS + 2% aromatic oil DCLR composite modified asphalt with the best high temperature performance. Burgers model can better reflect the creep process of asphalt, DCLR composite modified asphalt has some defects in low temperature performance, the higher the dose of DCLR, the poorer the low temperature performance of the composite modified asphalt. The low temperature sensitivity of DCLR composite modified asphalt has been reduced, low temperature crack resistance has been slightly enhanced.
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Orciuolo, Manfredi. "Mechanical Systems for Irrigation and Suction of High Viscosity Silicone Oil." In Basic and Advanced Vitreous Surgery. Springer New York, 1986. http://dx.doi.org/10.1007/978-1-4757-3881-0_8.
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Astafev, Vladimir, Valeria Olkhovskaya, Sergey Gubanov, Kirill Ovchinnikov, and Victor Konovalov. "Effect of Rising Reservoir Temperature on Production of High-Viscosity Oil." In Advances in Petroleum Engineering and Petroleum Geochemistry. Springer International Publishing, 2019. http://dx.doi.org/10.1007/978-3-030-01578-7_12.
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Liang, Liang-Xiao. "Research and Application of High-Efficiency Dehydration Technology for High Viscosity Foaming Crude Oil." In Springer Series in Geomechanics and Geoengineering. Springer Nature Singapore, 2023. http://dx.doi.org/10.1007/978-981-99-1964-2_271.
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Miller, K. S., B. E. Farkas, and R. P. Singh. "Viscosity Measurements of Fresh and Heat Stressed Frying Oil at High Temperatures." In Developments in Food Engineering. Springer US, 1994. http://dx.doi.org/10.1007/978-1-4615-2674-2_13.
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Yarmola, Тetiana, Viktoria Romanchuk, Volodymyr Skorokhoda, and Petro Topilnytskyy. "Effect of Polymer Additives on the Rheological Properties of Heavy High-Viscosity Oil." In Chemmotological Aspects of Sustainable Development of Transport. Springer International Publishing, 2022. http://dx.doi.org/10.1007/978-3-031-06577-4_2.
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Akhmetov, D. A., S. T. Zakenov, and O. G. Kirisenko. "Decision-Making on Steam Injection While High-Viscosity Oil Production Process Considering Uncertainty Conditions." In Advances in Intelligent Systems and Computing. Springer International Publishing, 2019. http://dx.doi.org/10.1007/978-3-030-35249-3_125.
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Jiang, Fan, Sijie Li, Yongcheng Xu, and Jiangdong Chen. "Numerical Analysis for Water Annulus Transportation of High-Viscosity Oil Under the Opening Ball Valve." In Proceedings of the International Petroleum and Petrochemical Technology Conference 2018. Springer Singapore, 2018. http://dx.doi.org/10.1007/978-981-13-2173-3_13.
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Fa-chao, Shan, Zhao Lun, Xu An-zhu, et al. "Study on Polymer Flooding Effect Evaluation and Parameter Optimization of High Viscosity Ordinary Heavy Oil Reservoir." In Proceedings of the International Field Exploration and Development Conference 2021. Springer Nature Singapore, 2022. http://dx.doi.org/10.1007/978-981-19-2149-0_460.
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Morrison, Barbara J., and Richard L. Bell. "Emission Estimates for a High Viscosity Crude Oil Surface Impoundment: 1. Field Measurements for Heat Transfer Model Validation." In Intermedia Pollutant Transport. Springer US, 1989. http://dx.doi.org/10.1007/978-1-4613-0511-8_11.
Full textConference papers on the topic "High-viscosity oil"
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Nunes, Felipe G., Elber V. Bendinelli, Mark D. Soucek, and Idalina V. Aoki. "Synthesis of High Solids Alkyds Modified with Reactive Diluents for Encapsulation and Use in Self-healing Coatings." In LatinCORR 2023. AMPP, 2023. https://doi.org/10.5006/lac23-20430.
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A great effort has been devoted to the research of self-healing coatings, as they provide anticorrosive protection even when the painting is damaged [1]. The encapsulation of drying oils is an established strategy to promote self-healing. Microcapsules release the seed oil upon mechanical damage, which triggers self-healing in the coating defect as the oil undergoes oxidative polymerization [2]. Alkyds are also a great candidate for microencapsulation due to their green nature, oxidative-driven polymerization, and better anticorrosive properties than seed oils [3]. However, the high viscosity of alkyds imposes great challenges for their encapsulation. In this work, a high solids alkyd from dehydrated castor oil (DCO) was developed with suitable viscosity for microencapsulation using seed oil-based reactive diluents.
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Akhmetzyanov, A. V., and A. V. Samokhin. "Thermal Wave Processes of Control the Development of Oil Fields with Abnormally High-Viscosity Reserves." In 2024 17th International Conference on Management of Large-Scale System Development (MLSD). IEEE, 2024. http://dx.doi.org/10.1109/mlsd61779.2024.10739425.
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ZHilyaeva, N. P. "High viscosity oil transportation." In Scientific dialogue: Young scientist. ЦНК МОАН, 2019. http://dx.doi.org/10.18411/spc-22-10-2019-03.
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Svarovskaya, L. I., L. K. Altunina, and V. S. Ovsyannikova. "Displacement of High-Viscosity Oil Using Microorganisms." In IOR 2005 - 13th European Symposium on Improved Oil Recovery. European Association of Geoscientists & Engineers, 2005. http://dx.doi.org/10.3997/2214-4609-pdb.12.c26.
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S. Oryngozhin, Ye. "INNOVATIVE�METHOD�OF�HIGH-VISCOSITY�OIL�PRODUCTION." In SGEM2012 12th International Multidisciplinary Scientific GeoConference and EXPO. Stef92 Technology, 2012. http://dx.doi.org/10.5593/sgem2012/s05.v2005.
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Zhang, Fan, Desheng Ma, Maozhang Tian, et al. "Study on a Novel Viscosity Reducer for High Viscosity and Low Permeability Reservoirs." In SPE Middle East Oil & Gas Show and Conference. Society of Petroleum Engineers, 2017. http://dx.doi.org/10.2118/183858-ms.
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Chernoletskiy, Kirill Vladimirovich, Sergey Viktorovich Kartamyshev, Timur Borisovich Zhuravlev, and Stanislav Olegovich Ursegov. "Nuclear Spectrometry Logs on High-Viscosity Oil Fields." In SPE Heavy Oil Conference and Exhibition. Society of Petroleum Engineers, 2011. http://dx.doi.org/10.2118/150628-ms.
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Akhiyarov, Denis Tauzikhovich, Hong-Quan Zhang, and Cem Sarica. "High-Viscosity Oil-Gas Flow in Vertical Pipe." In Offshore Technology Conference. Offshore Technology Conference, 2010. http://dx.doi.org/10.4043/20617-ms.
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Abas, Kafaa F., Inas J. Al-Nuaemi, and Musaab K. Rashed. "High viscosity paraffinic oil preparation for vacuum pump." In CONFERENCE ON MATHEMATICAL SCIENCES AND APPLICATIONS IN ENGINEERING: CMSAE-2021. AIP Publishing, 2023. http://dx.doi.org/10.1063/5.0161203.
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Donkov, P. V., V. A. Leonov, E. N. Akhatiamova, F. A. Kanzafarov, and S. G. Kanzafarov. "Pk High Viscosity Oil Reservoirs Development at Van-Yogan Oil Field." In IOR 2003 - 12th European Symposium on Improved Oil Recovery. European Association of Geoscientists & Engineers, 2003. http://dx.doi.org/10.3997/2214-4609-pdb.7.p009.
Full textReports on the topic "High-viscosity oil"
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Lodge, Arthur S. A New Method of Measuring Multigrade Oil Shear Elasticity and Viscosity at High Shear Rates,. Defense Technical Information Center, 1987. http://dx.doi.org/10.21236/ada190145.
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Frame, Edwin A., Adam C. Brandt, Ruben Sr A. Alvarez, Allen S. Comfort, and Luis A. Villahermosa. Feasibility of Using Full Synthetic Low Viscosity Engine Oil at High Ambient Temperatures in U.S. Army Engines. Defense Technical Information Center, 2011. http://dx.doi.org/10.21236/ad1007443.
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Machute, Ana, Lucas Tamele Jr., Arão Manhique, Afonso Macheca, and Hermínio Muiambo. Effect of jatropha curcas oil on the thermorheological properties of asphalt binder modified with recycled HDPE. Universidad de los Andes, 2024. https://doi.org/10.51573/andes.pps39.ss.cep.1.
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The application of bio-oils in asphalt and polymer-modified asphalt (PMA), has recently received considerable attention as a pivotal method for enhancing the high-temperature performance of asphalt mixtures while maintaining good binder’s workability. In this study, Jatropha curcas oil (JCO) was selected and evaluated as an PMA modifier. JCO-rHDPE-modified bio-asphalt was prepared with different JCO contents: 1, 3, and 5 wt.%. Physical tests (penetration, softening point, and ductility), rheological tests (dynamic viscosity and rolling thin-film oven test–RTFOT), and thermogravimetric analysis (TGA) were employed to evaluate the effect of JCO on the rheological, aging, and thermal properties of unmodified and HDPE-modified asphalt. The addition of JCO was effective in reducing the age hardening of asphalt binders due to an increase in penetration and ductility and a decrease in the softening point, and penetration index values. Aged asphalt binder with a combination of JCO and rHDPE has improved resistance to thermo-oxidative aging, exhibiting lower oxidation and volatilization after RTFOT. TGA indicated that the addition of JCO and rHDPE increases the thermal stability of modified binders by delaying the initial decomposition temperature of neat asphalt by 10ºC. The incorporation of JCO leads to a decrease in the viscosity of both virgin and rHDPE-modified asphalt. Thus, JCO-rHDPE-modified asphalt has better workability as well as potentially reduced fuel consumption and harmful emissions at pavement service temperatures.
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Robinett, Fred. PR-471-14207-R01 Development of Field Pump Performance Testing Procedure. Pipeline Research Council International, Inc. (PRCI), 2015. http://dx.doi.org/10.55274/r0010037.
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Performance testing pumps in the field can be challenging and even more complicated when the pump is in crude oil pipeline service. Pumps installed in crude oil pipelines normally do not meet the basic requirements set forth in typical pump testing standards, additionally crude oil fluid properties are irregular, thus making it difficult to obtain the desired accuracy for proper evaluation and comparison to factory tests. All inconsistencies need to be evaluated and reconciled to successfully field performance test pumps pumping viscous fluid. The objective of this project is to develop a practical field test procedure that can be applied to large high volume centrifugal pumps in pipelines transporting viscous fluids, specifically crude oil. There are many variables affecting field performance testing of crude oil pipeline pumps making it nearly impossible to fully analyze all possible combination of test measurements. The field pump performance test procedure provides practical guidance to assess the potential uncertainty of the measurements and making sensible corrections. Using the field testing procedure actual pump viscous performances can be measured and the results used to validate performances measured during factory tests on water and corrected for viscosity per the Hydraulic Institute (HI) 9.6.7, "Effects of Liquid Viscosity on Rotordynamic Pump Performance". The long term goal is to utilize the measured viscous performances using the field pump performance testing procedure to either validate or improve the current correlations between pump water performance and viscous performance set forth by HI, which are principally based on smaller pump tests. By assuring the viscous corrections are correct the pump and drive system sizing may be optimized.
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Chutimaworapan, Suchada, Chaiyo Chaichantippayuth, and Areerat Laopaksa. Formulation of pharmaceutical products of Garcinia mangostana Linn. extracts. Chulalongkorn University, 2006. https://doi.org/10.58837/chula.res.2006.32.
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Part I: The purpose of the investigation was to develop the extraction process that was simple, practical and giving high yield. The maceration of dried powder of Garcinia mangostana fruit husk with ethyl acetate gave yellow crystalline powder of mangostin. The yield was calculated as 7.47%. The identification of the Garcinia mangostanahusk extract was carried out by thin-layer chromatography (TLC) and differential scanning calorimetry. The TLC of mangostin was done by using the alumina sheet and ethyl acetate: hexane (3:1) as mobile phase. The Rf value as compared with standard mangostin was 0.60. The DSC thermogram showed the board melting range of the crude extract at 165.04-166.80 °C. The quantitative analyses of mangostin were developed using the high performance liquid chromatography (HPLC) and ultraviolet (UV) spectrophotometry. The HPLC system using methanol: water (87:13) as mobile phase, clotrimazole as internal standard and using UV detector at 243 nm. The UV spectrophotometric method was carried out using the UV spectrophotometer at 243 nm. The validation of both systems gave high specificity, linearity, accuracy and precision. The solubility study of mangostin showed the low water insolubility. The water solubility was improving with increasing ethanol content. The in vitro microbiological activity of mangostin to Staphylococcus aureus ATCC 25923 and Streptococcus mutans ATCC KPSK2 was studied. The minimum inhibitory concentrations of the extract were 3 µg/ml and 1.5 µg/ml, respectively. The minimum bactericidal concentrations of the extract was 4 µg/ml and 3 µg/ml, respectively.Part II: The purpose of this study was to develop fast dissolving oral strips containing Garcinia mangostana husk extract. The films consisted of low viscosity hydrophilic polymers such as hydroxypropyl methylcellulose and hydroxypropylcellulose, acesulfame potassium as sweetener, and menthol and eucalyptus oil as flavoring agents. The physical and mechanical properties and dissolution time of film bases were compared with commercial product strips A. From the dissolution time data, it was found that the film prepared from mixed polymer between HPMC 3 cps and HPC LV at ratios 2:1, 3:1, 4:1 and 5:1 were not significantly different from commercial product strips A (p>0.05). The films containing extract were light yellow and had porous surface based on observation from scanning electron microscopy. The dissolution profiles of all formulations showed the rapid release more than 80 percent of mangostin from films within 3-7 minutes and the fastest release was from formulation of HPMC 3 cps and HPC LV at ratio 5:1. Differential scanning calorimetry results exhibited that the Garcinia mangostana extract and additives were not in crystalline form in the films. The fast dissolving oral strips containing Garcinia mangostana husk extract showed in vitro antimicrobial activity against oro-dental bacteria, namely, Staphylococcus aureus aTCC 25923 and Streptococcus mutans ATCC KPSK2. Unter strese conditions at 40 degree Celcius and 75 percent relative humidity, the strips showed a good stability.The purpose of the study was to develop monoglyceride-based drug delivery systems containing Garcinia Mangostana extract. The system is based on the ability of mixtures of monoglyceride (dlyceryl monooleate) and triglycerides to form liquid crystals upon contact with water. The drug delivery systems can be administered by syringe and transformed into high-viscous liquid crystalline phases at the injection site. Ternary phase diagrams were constructed from various triglycerides: sesame oil, soybean oil and olive oil. In this study, monoglyceride-based drug delivery systems were prepared in the ratio of triglycerides: monoglyceride: water as 8: 62: 30 and 12: 58: 30. These systems could sustain release of Garcinia Mangostana husk extract over a period of 48 hr and followed squared root of time kinetics during the initial 24 hr of the release phase, indicating that the rate of release was diffusion-controlled. The system containing sesame oil showed the highest drug release. The increasing triglyceride content did not affect the release profiles. Differential scanning calorimetry results demonstrated that Garcinia Mangostana husk extract could be incorporated into drug delivery systems without causing phase transition. In the in vitro test, monoglyceride-based drug delivery systems containing Garcinia mangostana husk extract did not show the antimicrobial activity probably due to the high lipophilicity of the extract therefore it did not diffuse into the medium. Additionally, the drug delivery systems containing Garcinia mangostana husk extract showed good stability under the stress condition.
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Stavland, Arne, Siv Marie Åsen, Arild Lohne, Olav Aursjø, and Aksel Hiorth. Recommended polymer workflow: Lab (cm and m scale). University of Stavanger, 2021. http://dx.doi.org/10.31265/usps.201.
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Polymer flooding is one of the most promising EOR methods (Smalley et al. 2018). It is well known and has been used successfully (Pye 1964; Standnes & Skjevrak 2014; Sheng et al. 2015). From a technical perspective we recommend that polymer flooding should be considered as a viable EOR method on the Norwegian Continental Shelf for the following reasons: 1. More oil can be produced with less water injected; this is particularly important for the NCS which are currently producing more water than oil 2. Polymers will increase the aerial sweep and improve the ultimate recovery, provided a proper injection strategy 3. Many polymer systems are available, and it should be possible to tailor their chemical composition to a wide range of reservoir conditions (temperature and salinity) 4. Polymer systems can be used to block water from short circuiting injection production wells 5. Polymer combined with low salinity injection water has many benefits: a lower polymer concentration can be used to reach target viscosity, less mechanical degradation, less adsorption, and a potential reduction in Sor due to a low salinity wettability effect. There are some hurdles when considering polymer flooding that needs to be considered: 1. Many polymer systems are not at the present considered as green chemicals; thus, reinjection of produced water is needed. However, results from polymer degradation studies in the IORCentre indicates that a. High molecular weight polymers are quickly degraded to low molecular weight. In case of accidental release to the ocean low molecular weight polymers are diluted and the lifetime of the spill might be quite short. According to Caulfield et al. (2002) HPAM is not toxic, and will not degrade to the more environmentally problematic acrylamide. b. In the DF report for environmental impact there are case studies using the DREAM model to predict the transport of chemical spills. This model is coupled with polymer (sun exposure) degradation data from the IORCentre to quantify the lifetime of polymer spills. This approach should be used for specific field cases to quantify the environmental risk factor. 2. Care must be taken to prepare the polymer solution offshore. Chokes and vales might be a challenge but can be mitigating according to the results from the large-scale testing done in the IORCentre (Stavland et al. 2021). None of the above-mentioned challenges are server enough to not consider polymer flooding. HPAM is neither toxic, nor bio-accumulable, or bio-persistent and the CO2 footprint from a polymer flood may be significantly less than a water flood (Dupuis et al. 2021). There are at least two contributing factors to this statement, which we will return in detail to in the next section i) during linear displacement polymer injection will produce more oil for the same amount of water injected, hence the lifetime of the field can be shortened ii) polymers increase the arial sweep reducing the need for wells.