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Journal articles on the topic 'Heavy crude oil'

Author: Grafiati

Published: 4 June 2021

Last updated: 5 February 2022

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1

Carrillo, Jesús Alirio, and Laura Milena Corredor. "Heavy Crude Oil Upgrading: Jazmin Crude." Advances in Chemical Engineering and Science 03, no. 04 (2013): 46–55. http://dx.doi.org/10.4236/aces.2013.34a1007.

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2

Weissman, Jeffrey G., and Richard V. Kessler. "Downhole heavy crude oil hydroprocessing." Applied Catalysis A: General 140, no. 1 (June 1996): 1–16. http://dx.doi.org/10.1016/0926-860x(96)00003-8.

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3

Al-Sayegh, Abdullah, Yahya Al-Wahaibi, Sanket Joshi, Saif Al-Bahry, Abdulkadir Elshafie, and Ali Al-Bemani. "Bioremediation of Heavy Crude Oil Contamination." Open Biotechnology Journal 10, no. 1 (November 11, 2016): 301–11. http://dx.doi.org/10.2174/1874070701610010301.

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Crude oil contamination is one of the major environmental concerns and it has drawn interest from researchers and industries. Heavy oils contain 24-64% saturates and aromatics, 14-39% resins and 11-45% asphaltene. Resins and asphaltenes mainly consist of naphthenic aromatic hydrocarbons with alicyclic chains which are the hardest to degrade. Crude oil biodegradation process, with its minimal energy need and environmentally friendly approach, presents an opportunity for bioremediation and as well for enhanced oil recovery to utilize heavy oil resources in an efficient manner. Biodegradation entails crude oil utilization as a carbon source for microorganisms that in turn change the physical properties of heavy crude oil by oxidizing aromatic rings, chelating metals and severing internal bonds/chains between molecules. Biodegradation does not necessarily lower quality of crude oil as there are cases where quality was improved. This paper provides information on heavy crude oil chemistry, bioremediation concept, biodegradation enzymes, cases of Microbial Enhanced heavy crude Oil Recovery (MEOR) and screening criteria towards a better understanding of the biodegradation application. Through the utilization of single microorganisms and consortia, researchers were able to biodegrade single pure hydrocarbon components, transform heavy crude oil fractions to lighter fractions, remove heavy metals and reduce viscosity of crude oil.

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4

Meyer, Richard F. "Prospects for Heavy Crude Oil Development." Energy Exploration & Exploitation 5, no. 1 (February 1987): 27–55. http://dx.doi.org/10.1177/014459878700500104.

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The problems of utilizing heavy crude oil and natural bitumens centre on their high viscosity which makes them difficult to produce, store, transport, and refine. These factors are reflected in costs. World reserves are substantial, however, perhaps as much as 7 trillion† barrels estimated to represent 0·9 trillion barrels of recoverable oil. Nearly 2·1 trillion barrels of heavy crude oil, more than 50% of the world's total reserve, are located in Venezuela largely in the Orinoco Oil Belt. About 75% of the natural bitumen, 2·6 trillion barrels, is located in Canada in the Athabasca, Cold Lake, and Peace River areas of Alberta. Most of the estimated undiscovered heavy crude oil in the world, approximately 630 billion barrels, is outside the US and Canada. Data required to determine the cost of finding natural bitumen and heavy oil are roughly the same as for other mineral commodities. Similarly for recovery costs. The variables are so extensive that dollar amounts have little meaning without qualification. Recovery depends on depth below surface. Near-surface deposits are recovered by mechanical mining. Deeper deposits must be won by thermal means. Transportation by pipeline is feasible only if the viscosity is lowered by partial upgrading, heating, or by the use of diluents. Part of the high cost of refining results from the major investment required for the large installations that are needed for economic rates of production.

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5

Xu, X. R., J. Y. Yang, B. L. Zhang, and J. S. Gao. "Demulsification of Extra Heavy Crude Oil." Petroleum Science and Technology 25, no. 11 (November 27, 2007): 1375–90. http://dx.doi.org/10.1080/10916460600803694.

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6

Leon, Vladimir, and Manoj Kumar. "Biological upgrading of heavy crude oil." Biotechnology and Bioprocess Engineering 10, no. 6 (December 2005): 471–81. http://dx.doi.org/10.1007/bf02932281.

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7

Storm, D. A., R. J. McKeon, H. L. McKinzie, and C. L. Redus. "Drag Reduction in Heavy Oil." Journal of Energy Resources Technology 121, no. 3 (September 1, 1999): 145–48. http://dx.doi.org/10.1115/1.2795973.

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Transporting heavy crude oil by pipeline requires special facilities because the viscosity is so high at normal field temperatures. In some cases the oil is heated with special heaters along the way, while in others the oil may be diluted by as much as 30 percent with kerosene. Commercial drag reducers have not been found to be effective because the single-phase flow is usually laminar to only slightly turbulent. In this work we show the effective viscosity of heavy oils in pipeline flow can be reduced by a factor of 3–4. It is hypothesized that a liquid crystal microstructure can be formed so that thick oil layers slip on thin water layers in the stress field generated by pipeline flow. Experiments in a 1 1/4-in. flow loop with Kern River crude oil and a Venezuela crude oil BCF13 are consistent with this hypothesis. The effect has also been demonstrated under field conditions in a 6-in. flow loop using a mixture of North Sea and Mississippi heavy crude oils containing 10 percent brine.

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8

Friisø, Trond, Yannick Schildberg, Odile Rambeau, Tore Tjomsland, Harald Førdedal, and Johan Sjøblom. "COMPLEX PERMITTIVITY OF CRUDE OILS AND SOLUTIONS OF HEAVY CRUDE OIL FRACTIONS." Journal of Dispersion Science and Technology 19, no. 1 (January 1998): 93–126. http://dx.doi.org/10.1080/01932699808913163.

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9

Jing, Jiaqiang, Jiatong Tan, Haili Hu, Jie Sun, and Peiyu Jing. "Rheological and Emulsification Behavior of Xinjiang Heavy Oil and Model Oils." Open Fuels & Energy Science Journal 9, no. 1 (August 9, 2016): 1–10. http://dx.doi.org/10.2174/1876973x01609010001.

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Transparent model oils are commonly used to study the flow patterns and pressure gradient of crude oil-water flow in gathering pipes. However, there are many differences between the model oil and crude oils. The existing literatures focus on the flow pattern transition and pressure gradient calculation of model oils. This paper compares two most commonly used model oils (white mineral oil and silicon oil) with Xinjiang crude oil from the perspectives of rheological properties, oil-water interfacial tensions, emulsion photomicrographs and demulsification process. It indicates that both the white mineral oil and the crude oils are pseudo plastic fluids, while silicon oil is Newtonian fluid. The viscosity-temperature relationship of white mineral oil is similar to that of the diluted crude oil, while the silicon oil presents a less viscosity gradient with the increasing temperature. The oil-water interfacial tension can be used to evaluate the oil dispersing ability in the water phase, but not to evaluate the emulsion stability. According to the Turbiscan lab and the stability test, the model oil emulsion is less stable than that of crude oil, and easier to present water separation.

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10

Bybee, Karen. "Heavy-Crude-Oil Upgrading With Transition Metals." Journal of Petroleum Technology 59, no. 12 (December 1, 2007): 49–50. http://dx.doi.org/10.2118/1207-0049-jpt.

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11

Alaei, Mahshad, Mansour Bazmi, Alimorad Rashidi, and Alireza Rahimi. "Heavy crude oil upgrading using homogenous nanocatalyst." Journal of Petroleum Science and Engineering 158 (September 2017): 47–55. http://dx.doi.org/10.1016/j.petrol.2017.08.031.

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12

Mamonova, A. O., O. A. Plugatyreva, E. M. Khusnutdinova, and A. N. Khusnutdinov. "Features of very heavy crude oil transportation." IOP Conference Series: Materials Science and Engineering 570 (August 15, 2019): 012067. http://dx.doi.org/10.1088/1757-899x/570/1/012067.

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13

She, Yue Hui, Fu Chang Shu, Fan Zhang, Zheng Liang Wang, Shu Qiong Kong, and Long Jiang Yu. "The Enhancement of Heavy Crude Oil Recovery Using Bacteria Degrading Polycyclic Aromatic Hydrocarbons." Advanced Materials Research 365 (October 2011): 320–25. http://dx.doi.org/10.4028/www.scientific.net/amr.365.320.

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Two strains of bacteria degrading polycyclic aromatic hydrocarbons (PAHs) were isolated using enrichment cultures of various heavy crude oil samples obtained from the Dagang Oilfield. The strains, namely S17 and S28, are able to degrade crude oil using phenanthrene as the sole carbon and energy source. The crude oil composition analysis indicates both strains are able to degrade heavy hydrocarbon components in crude oil. Then, the viscosities of heavy crude oil with S17 and S28 were decreased, and the surface tension between fermentative fluid and air were also decreased. The core flooding tests demonstrated that the fermentation broth, containing the two strains, can improve the residual oil recovery ratio by approximately 12.26% after polymer flooding.

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14

Diehl, Liange O., Diogo P. Moraes, Fabiane G. Antes, Juliana S. F. Pereira, Maria de Fátima P. Santos, Regina C. L. Guimarães, José Neri G. Paniz, and Érico M. M. Flores. "Separation of Heavy Crude Oil Emulsions Using Microwave Radiation for Further Crude Oil Analysis." Separation Science and Technology 46, no. 8 (May 2011): 1358–64. http://dx.doi.org/10.1080/01496395.2011.560590.

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15

Topilnytskyy, Petro, Viktoria Romanchuk, Tetiana Yarmola, and Halyna Stebelska. "Study on Rheological Properties of Extra-Heavy Crude Oil from Fields of Ukraine." Chemistry & Chemical Technology 14, no. 3 (September 22, 2020): 412–19. http://dx.doi.org/10.23939/chcht14.03.412.

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16

Ibemesim, Ruth I., and Joseph F. Bamidele. "COMPARATIVE TOXICITY OF TWO OIL TYPES AND TWO DISPERSANTS ON THE GROWTH OF A SEASHORE GRASS, PASPALUM VAGINATUM(SWARTZ)." International Oil Spill Conference Proceedings 2008, no. 1 (May 1, 2008): 875–80. http://dx.doi.org/10.7901/2169-3358-2008-1-875.

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ABSTRACT The present study consists of assessing the effects of Abura heavy crude petroleum oil (AC) and Oredo light crude petroleum oil (OC) on the survival of Paspalum vaginatum. The effectiveness of two dispersants, Goldcrew and Corexit 9527, in removing oil from P. vaginatum previously sprayed with either Abura of Oredo crude petroleum oil was assessed, the effect of time of dispersant application following crude oil pollution on growth and survival of P. vaginatum was also studied. Plants treated with AC recovered after 8 days while 100% mortality was recorded for plants treated with OC + Corexit 9527 (O24C0 and O48C0). Corexit 9527 was not effective in ameliorating the lethal effects of Oredo crude oil. Although, P. vaginatum recovery was apparent 70 days after AC pollution and after cleaning with Goldcrew (A24GCand A48GC), both treatments resulted in significant (P <0.05) lower biomass and stem density compared to control. It is concluded that plants cleaned with Goldcrew dispersant after 24 h recovered faster than those cleaned after 48 h. Exposure of P. vaginatum to light crude oil or light crude oil + Corexit 9527 is detrimental and can inhibit growth where as it will recover when exposed to heavy crude oil or heavy crude oil + Goldcrew.

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17

Jurnal, Redaksi Tim. "ANALISIS PENGGUNAAN LISTRIK ARUS SEARAH UNTUK MENINGKATKAN LAJU PRODUKSI MINYAK BUMI JENIS MINYAK BERAT." Energi & Kelistrikan 9, no. 2 (November 23, 2018): 141–46. http://dx.doi.org/10.33322/energi.v9i2.40.

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rom EEOR, Electro Enhanced Oil Recovery, and a developing technology application which has been established earlier. The difference is ESOR relatively does not improve recovery factor of producing well. Ideally any crude oil producing well will be experiencing pressure decline which may affect crude oil production decrement, naturally. Regarding some similar researches around the world, the use of direct current electrical exposure was proven to increase number of heavy crude oil production. At least salinity, hydrocarbon chemical compounds and crude oil flow in the reservoir (electro-osmosis) involves during chemical processes in the reservoir while ESOR application. Number of electrons conducted from direct current electrical power supply will be a supporting media during chemical process of these parameters. Unfortunately after completing ESOR application in Lapangan X, the result was contradictive with this research hypothesis. Exposure of direct current electrical supply did not increased heavy crude oil production. On a contrary, parameter of salinity and API gravity as produced heavy crude oil quality, were improving significantly.

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18

Bannwart, Antonio C., Oscar M. H. Rodriguez, Carlos H. M. de Carvalho, Isabela S. Wang, and Rosa M. O. Vara. "Flow Patterns in Heavy Crude Oil-Water Flow." Journal of Energy Resources Technology 126, no. 3 (September 1, 2004): 184–89. http://dx.doi.org/10.1115/1.1789520.

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This paper is aimed to an experimental study on the flow patterns formed by heavy crude oil (initial viscosity and density 488 mPa s, 925.5kg/m3 at 20°C) and water inside vertical and horizontal 2.84-cm-i.d. pipes. The oil-water interfacial tension was 29 dyn/cm. Effort is concentrated into flow pattern characterization, which was visually defined. The similarities with gas-liquid flow patterns are explored and the results are expressed in flow maps. In contrast with other studies, the annular flow pattern (“core annular flow”) was observed in both horizontal and vertical test sections. These flow pattern tends to occur in heavy oil-water flows at low water input fractions. Because of the practical importance of core flow in providing an effective means for heavy oil production and transportation, this paper discusses criteria that favor its occurrence in pipes.

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19

Shishkova, Ivelina K., Dicho S. Stratiev, Mariana P. Tavlieva, Rosen K. Dinkov, Dobromir Yordanov, Sotir Sotirov, Evdokia Sotirova, et al. "Evaluation of the Different Compatibility Indices to Model and Predict Oil Colloidal Stability and Its Relation to Crude Oil Desalting." Resources 10, no. 8 (July 22, 2021): 75. http://dx.doi.org/10.3390/resources10080075.

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Thirty crude oils, belonging to light, medium, heavy, and extra heavy, light sulfur, and high sulfur have been characterized and compatibility indices defined. Nine crude oil compatibility indices have been employed to evaluate the compatibility of crude blends from the thirty individual crude oils. Intercriteria analysis revealed the relations between the different compatibility indices, and the different petroleum properties. Tetra-plot was employed to model crude blend compatibility. The ratio of solubility blending number to insolubility number was found to best describe the desalting efficiency, and therefore could be considered as the compatible index that best models the crude oil blend compatibility. Density of crude oil and the n-heptane dilution test seem to be sufficient to model, and predict the compatibility of crude blends.

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20

Quej-Ake, L. M., A. Contreras, and Jorge Aburto. "The effect of non-ionic surfactant on the internal corrosion for X52 steel in extra-heavy crude oil-in-water emulsions." Anti-Corrosion Methods and Materials 65, no. 3 (May 8, 2018): 234–48. http://dx.doi.org/10.1108/acmm-03-2017-1770.

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Purpose The purpose of this research is to study different extra-heavy crude oil-in-water emulsions that can be found in practice for corrosion process of X52 steel adding 60 mg.L-1 of non-ionic surfactant and a corrosion inhibitor (CI). Electrochemical impedance spectroscopy and Tafel plots are carried out. Thus, Bode-modulus and Bode-phase angle plots are discussed. Adsorption isotherms obtained from corrosion rate (CR) values are taken into account. Design/methodology/approach Two-electrode arrangement is used to characterize the pseudo-capacitance values for X52 steel exposed to water and crude oil phases, mainly. Electrochemical evaluations for X52 steel exposed to extra-heavy crude oil-in-water emulsions are recorded in a conventional three-electrode cell to study the corrosion process as was documented in detail by Quej-Ake et al. (2015). Therefore, all electrodes are placed as close as possible to eliminate the iR-drop. Findings Pseudo-capacitance analysis shows that X52 steel immersed in oilfield produced water was more susceptible to corrosion than that immersed in ocean water solution and extra-heavy crude oil phase. After being analyzed, the X52 steel surface coverage and adsorption process for surfactant and CI could be concluded that surfactant could protect the metal surface. In a coalescence extra-heavy crude oil-in-water emulsion, the water medium generated a new solution that was more corrosive than the original water phase. Wash crude oil process was provoked in emulsion systems to sweep up the salts, mainly. Thus, corrosive species that can be recovered inside extra-heavy crude oil may appear, and in turn a new more corrosive solution could be obtained. Taking into account the straight line obtained in Bode-modulus plot for X52 exposed to extra-heavy crude oil, it is possible to point out that the negative value of the slope or R2 can be related to a coefficient (Jorcin et al., 2006). It is important to mention that electrochemical responses for X52 steel exposed to extra-heavy crude oil-in-water under coalescence emulsions revealed that corrosion and diffusion processes exist. Therefore, a possible good inhibitor is surfactant in emulsion systems. Originality/value CR and anodic and cathodic slopes suggest that the surfactant acted as mixed CI. Of these, susceptible anodic (MnS and perlite or cementite) and cathodic (ferrite) sites on steel surface could be affected, due to which physicochemical adsorption could happen by using electrochemical parameters analysis. Thus, no stable emulsions should be taken into account for extra-heavy crude oil transportation, because corrosion problems in atmospheric distillation process of the crude oil due to stable emulsion cannot be easily separated. In this manner, coalescent emulsions are more adequate for transporting extra-heavy crude oil because low energy to separate the water media is required.

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21

Li, Jingjing, Xiaodong Chen, Xiaodong Tang, Liuyang Deng, and Yutao Wei. "Upgrading heavy and extra-heavy crude oil by iron oil-soluble catalyst for transportation." Petroleum Science and Technology 35, no. 11 (June 3, 2017): 1160–65. http://dx.doi.org/10.1080/10916466.2017.1314303.

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22

Bybee, Karen. "A Heavy- to Light-Crude-Oil Upgrading Process." Journal of Petroleum Technology 59, no. 12 (December 1, 2007): 51–53. http://dx.doi.org/10.2118/1207-0051-jpt.

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23

Denney, Dennis. "Challenges in Heavy Crude Oil - Grane, an Overview." Journal of Petroleum Technology 58, no. 06 (June 1, 2006): 53–54. http://dx.doi.org/10.2118/0606-0053-jpt.

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24

Weissman, J. G., R. V. Kessler, R. A. Sawicki, J. D. M. Belgrave, C. J. Laureshen, S. A. Mehta, R. G. Moore, and M. G. Ursenbach. "Down-Hole Catalytic Upgrading of Heavy Crude Oil." Energy & Fuels 10, no. 4 (January 1996): 883–89. http://dx.doi.org/10.1021/ef9501814.

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25

Yaghi, Basma M., and Ali Al-Bemani. "Heavy Crude Oil Viscosity Reduction for Pipeline Transportation." Energy Sources 24, no. 2 (February 2002): 93–102. http://dx.doi.org/10.1080/00908310252774417.

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26

Wyslouzil, B. E., M. A. Kessick, and J. H. Masliyah. "Pipeline flow behaviour of heavy crude oil emulsions." Canadian Journal of Chemical Engineering 65, no. 3 (June 1987): 353–60. http://dx.doi.org/10.1002/cjce.5450650301.

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27

Miadonye, Adango, and Brittany MacDonald. "Microwave Radiation Induced Visbreaking of Heavy Crude Oil." Journal of Petroleum Science Research 3, no. 3 (2014): 130. http://dx.doi.org/10.14355/jpsr.2014.0303.04.

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28

Ali, M. Farhat, Ahmed Bukhari, and Misbah-ul-Hasan. "STRUCTURAL CHARACTERIZATION OF ARABIAN HEAVY CRUDE OIL RESIDUE." Fuel Science and Technology International 7, no. 8 (January 1989): 1179–208. http://dx.doi.org/10.1080/08843758908962284.

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29

Ignatenko, V. Ya, Yu V. Kostina, S. V. Antonov, and S. O. Ilyin. "Oxidative Functionalization of Asphaltenes from Heavy Crude Oil." Russian Journal of Applied Chemistry 91, no. 11 (November 2018): 1835–40. http://dx.doi.org/10.1134/s1070427218110149.

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30

Sadykov, A. N., D. F. Fazliev, V. A. Kharlamov, and R. Sh Nigmatullina. "Oil fractions of heavy crude from bituminous rocks." Chemistry and Technology of Fuels and Oils 22, no. 1 (January 1986): 3–5. http://dx.doi.org/10.1007/bf00736105.

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31

Sun, R., and C. A. Shook. "Inversion of heavy crude oil-in-brine emulsions." Journal of Petroleum Science and Engineering 14, no. 3-4 (May 1996): 169–82. http://dx.doi.org/10.1016/0920-4105(95)00043-7.

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32

Lam-Maldonado, M., J. A. Melo-Banda, D. Macias-Ferrer, P. Schacht, J. M. Mata-Padilla, A. I. Reyes de la Torre, M. A. Meraz Melo, and J. M. Domínguez. "NiFe nanocatalysts for the hydrocracking heavy crude oil." Catalysis Today 349 (June 2020): 17–25. http://dx.doi.org/10.1016/j.cattod.2018.08.005.

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33

Кутуков, Сергей Евгеньевич, Ольга Витальевна Четверткова, and Андрей Иванович Гольянов. "Q-H characteristics for heavy crude oil pipeline." SCIENCE & TECHNOLOGIES OIL AND OIL PRODUCTS PIPELINE TRANSPORTATION, no. 1 (February 28, 2021): 32–39. http://dx.doi.org/10.28999/2541-9595-2021-11-1-32-39.

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Проблема повышения точности технологических расчетов нефтепроводов обрела особую остроту на фоне модернизации системы обнаружения утечек и разработки программного обеспечения в области планирования грузопотоков в системе магистральных трубопроводов. Расхождение результатов гидравлических расчетов и фактических параметров перекачки вызвано, в частности, такими факторами, как игнорирование мультифазного характера течения нефти (особенно на недогруженных участках нефтепроводов, проложенных по пересеченной местности), отсутствие актуальных данных по состоянию длительно эксплуатируемых труб, применение методик расчета потерь энергии на трение, базирующихся на постулатах классической гидравлики. В настоящей статье авторами предложен метод определения гидравлической характеристики трубопровода на установившемся режиме эксплуатации, перекачивающего неньютоновские реологически сложные нефти в диапазоне малых скоростей сдвига, который предполагает непосредственную интерпретацию экспериментальных данных вискозиметрии и исключает погрешности аппроксимации кривой течения реологической моделью и осреднения параметра вязкости. С этой целью рассмотрены вопросы аномалии вязкости и тиксотропии неньютоновских нефтей. Дано обоснование предлагаемого метода и представлено практическое приложение излагаемой методики на примере анализа гидравлической характеристики магистрального нефтепровода Атырау-Самара, по которому транспортируется смесь нефтей с частично разрушенной внутренней структурой. The problem of improving the accuracy of technological calculations for oil pipelines has become especially acute against the background of modernization of the leak detection system and development of software in the field of planning cargo flows in the trunk pipeline system. Discrepancy between hydraulic calculation results and actual pumping parameters is caused, in particular, by such factors as ignoring the multiphase oil flow nature (especially in under-loaded sections of oil pipelines laid over rough terrain), the lack of up-to-date data on the state of long-operating pipes, the use of methods for calculating friction-related energy losses based on the postulates of classical hydraulics. In this article, the authors propose a method for determining the hydraulic characteristics of a pipeline at steady state operation, pumping non-Newtonian rheologically complex oils in the range of low shear rates, which implies a direct interpretation of experimental viscometry data, excluding errors in approximating the flow curve by a rheological model and averaging the viscosity parameter. For this purpose, the anomaly of viscosity and thixotropy of non-Newtonian oils are considered. The article provides a substantiation of the proposed method and presents a practical application of the described technique by the example of the analysis of the hydraulic characteristics of the Atyrau-Samara main oil pipeline, through which an oil blend with partially destroyed internal structure is transported.

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34

Che Mohamed Hussein, Siti Nurliyana, Fatin Syahirah Mohamed Fuad, and Marina Ismail. "Synthesis of Zinc Oxide Nanoparticles for Oil Upgrading and Wax Deposition Control: Effect of Calcination Temperature." Indonesian Journal of Chemistry 20, no. 4 (June 10, 2020): 746. http://dx.doi.org/10.22146/ijc.43317.

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In this study, ZnO nanoparticles were synthesized using a sol-gel method for oil upgrading and wax deposition control. The synthesized ZnO nanoparticles were used to measure viscosity and wax deposition in the heavy crude oil and to investigate the effectiveness of the nanoparticles in the reduction of viscosity and wax deposition control of the heavy crude oil. This study investigated the effect of calcination temperature on ZnO nanoparticles during synthesis towards viscosity reduction and wax deposition control. ZnO nanoparticles were calcined at different temperatures ranging from 300 to 900 °C. The calcined ZnO nanoparticles were characterized using X-ray diffraction (XRD), Field Emission Scanning Electron microscope (FESEM), and Energy-dispersive X-ray spectroscopy (EDX) for its structure, size, shape, and morphology. The characterization results showed a hexagonal wurtzite structure of ZnO nanoparticles. The physical properties and rheology of heavy crude oil were characterized by using Electronic Rheometer and cold finger method to analyze the viscosity, shear rate, and wax deposition of the heavy crude oil for performance study. Decreased in crystallite size from 15.59 to 12.84 nm was observed with increasing calcination temperature from 300 to 400 °C, and a further increase of calcination temperature from 400 to 900 °C, the crystallite size increased from 12.84 to 41.58 nm. The degree viscosity reduction (DVR %) of heavy crude oil was observed to increase by 41.7%, with decreasing ZnO nanoparticles size from 30.11 nm to 12.84 nm. The optimum calcination temperature was 400 °C. Wax deposition decreases by 32.40% after the addition of ZnO nanoparticles into heavy crude oil.

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35

Zameek, Mohamed Azil Zain, Mee Wei Lim, and Ee Von Lau. "Terminal Velocity of Heavy Crude Oil in Aqueous Solution: Effects of pH and Salinity." International Proceedings of Chemical, Biological and Environmental Engineering 96 (2016): 46–52. http://dx.doi.org/10.7763/ipcbee.2016.v96.8.

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36

Langevin, D., S. Poteau, I. Hénaut, and J. F. Argillier. "Crude Oil Emulsion Properties and Their Application to Heavy Oil Transportation." Oil & Gas Science and Technology 59, no. 5 (September 2004): 511–21. http://dx.doi.org/10.2516/ogst:2004036.

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37

Uçar, Suat, and Selhan Karagöz. "Co-processing of olive bagasse with crude rapeseed oil via pyrolysis." Waste Management & Research: The Journal for a Sustainable Circular Economy 35, no. 5 (January 18, 2017): 480–90. http://dx.doi.org/10.1177/0734242x16680729.

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The co-pyrolysis of olive bagasse with crude rapeseed oil at different blend ratios was investigated at 500ºC in a fixed bed reactor. The effect of olive bagasse to crude rapeseed oil ratio on the product distributions and properties of the pyrolysis products were comparatively investigated. The addition of crude rapeseed oil into olive bagasse in the co-pyrolysis led to formation of upgraded biofuels in terms of liquid yields and properties. While the pyrolysis of olive bagasse produced a liquid yield of 52.5 wt %, the highest liquid yield of 73.5 wt % was obtained from the co-pyrolysis of olive bagasse with crude rapeseed oil at a blend ratio of 1:4. The bio-oil derived from olive bagasse contained 5% naphtha, 10% heavy naphtha, 30% gas oil, and 55% heavy gas oil. In the case of bio-oil obtained from the co-pyrolysis of olive bagasse with crude rapeseed oil at a blend ratio of 1:4, the light naphtha, heavy naphtha, and light gas oil content increased. This is an indication of the improved characteristics of the bio-oil obtained from the co-processing. The heating value of bio-oil from the pyrolysis of olive bagasse alone was 34.6 MJ kg−1 and the heating values of bio-oils obtained from the co-pyrolysis of olive bagasse with crude rapeseed oil ranged from 37.6 to 41.6 MJ kg−1. It was demonstrated that the co-processing of waste biomass with crude plant oil is a good alternative to improve bio-oil yields and properties.

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Riaza, Stephanie, Farid B. Cortés, and Julián Otalvaro. "Emulsions with heavy crude oil in presence of nanoparticles." Boletín de Ciencias de la Tierra, no. 36 (July 1, 2014): 55–68. http://dx.doi.org/10.15446/rbct.n36.46282.

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A study about the use of silica nanoparticles in crude oils from the Castilla field and the effects on stability, drop size and emulsion viscosity was carried out. The interest in the use of this type of nanoparticles is created by the inversion effect that these produce in the W/O emulsion at high water cuts upper than 48%. The emulsion is transformed in W/O/W being the latter the least viscous due to the water is the external phase and it allows to the crude oil slides easily on any surface. In this study, two types of naturally emulsified crude oil with different water cuts and a synthetic emulsion were used. This kind of behavior created by nanoparticles over the emulsion could be an alternative solution to the viscosity, fluidity and mobility problems that affect the extraction and transportation in heavy crude oil.

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Marsden, S. S., Kiyoshi Ishimoto, and Lidian Chen. "Slurries and emulsions of waxy and heavy crude oils for pipeline transportation of crude oil." Colloids and Surfaces 29, no. 1 (January 1988): 133–46. http://dx.doi.org/10.1016/0166-6622(88)80176-8.

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Sun, Yumei, Zhanguo Ning, Fan Yang, and Xianzhen Li. "Characteristics of Newly Isolated Geobacillus sp. ZY-10 Degrading Hydrocarbons in Crude Oil." Polish Journal of Microbiology 64, no. 3 (September 18, 2015): 253–63. http://dx.doi.org/10.5604/01.3001.0009.2120.

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An obligately thermophilic strain ZY-10 was isolated from the crude oil in a high-temperature oilfield, which was capable of degrading heavy crude oil. Phenotypic and phylogenetic analysis demonstrated that the isolate should be grouped in the genus Geobacillus, which shared the highest similarity (99%) of the 16S rDNA sequence to Geobacillus stearothermophilus. However, the major cellular fatty acid iso-15:0 (28.55%), iso-16:0 (24.93%), iso-17:0 (23.53%) and the characteristics including indole production, tolerance to NaN3 and carbohydrate fermentation showed some difference from the recognized species in the genus Geobacillus. The isolate could use tridecane, hexadecane, octacosane and hexatridecane as sole carbon source for cell growth, and the digesting rate of long-chain alkane was lower than that of short-chain alkane. When the isolate was cultured in the heavy crude oil supplement with inorganic salts and trace yeast extract, the concentration of short-chain alkane was significantly increased and the content of long-chain alkane was decreased, suggesting that the larger hydrocarbon components in crude oil were degraded into shorter-chain alkane. Strain ZY-10 would be useful for improving the mobility of crude oil and upgrading heavy crude oil in situ.

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Johnston, Robert J., and Thomas G. Mason. "Asphaltene Aggregation Kinetics in Crude Oil Using Confocal Microscopy." Microscopy and Microanalysis 7, S2 (August 2001): 542–43. http://dx.doi.org/10.1017/s1431927600028786.

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Confocal laser scanning microscopy (CLSM) has been used to study asphaltene aggregation kinetics by employing the microscope's automated acquisition to generate time-lapsed projection maps of aggregating asphaltenes in the autofluorescent matrix of crude oil. Heavy crude oils contain asphaltene particles resulting in the production of optically observable micron-sized asphaltene aggregates. These aggregates form as a result of attractive interactions induced by mixing the heavy crude oil with a poor solvent. This technique has been employed to determine the volume fraction of aggregated asphaltenes, ϕagg, and the time evolution of this phenomenon. The measurements cover a range of various concentrations of asphaltene volume fractions of the heavy asphaltenic oil, ϕm, from ϕm =0.001 to ϕm =0.4.At each ϕm,after the mixtures have been made, approximately 20 μl of the crude oil is placed in a 20 μm deep flat-well quartz cell and immediately placed on a microscope stage.

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Kesava Raju, Ch Siva, Bhaskar Pramanik, Tanmoy Kar, Peddy V. C. Rao, Nettem V. Choudary, and Raman Ravishankar. "Low molecular weight gels: potential in remediation of crude oil spillage and recovery." RSC Advances 6, no. 58 (2016): 53415–20. http://dx.doi.org/10.1039/c6ra10462b.

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A molecular gelator which has strong gelation ability for different crude oils (light to heavy crudes), and a wide range of refinery products is reported for the first time for its potential application in oil spillage/recovery.

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J., Nmegbu C. G., Oritom Hezekiah Braye, and Wami E. N. "Thermal Recovery of Niger Delta Heavy Crude." European Journal of Engineering Research and Science 4, no. 4 (April 4, 2019): 11–16. http://dx.doi.org/10.24018/ejers.2019.4.4.1213.

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Unconventional oil reserve estimate in Nigeria which is at an average of 42 billion barrels of hydrocarbon deposits, surpasses the proven reserve of 37.2 billion barrels of conventional oil reservoirs. With these statistics, the need to evaluate the prospects of production from these unconventional reservoir systems becomes a subject of interest. In this study, a thermal approach towards the recovery of a Niger Delta heavy crude oil was conducted by the viscosity reduction mechanism via hot water injection. Fluid characterization via laboratory tests revealed that the Niger Delta retrieved heavy crude sample had a viscosity 17.80 cp,13.24oAPI and a density of 0.997.6 g/cc. This sample was subjected to a series of recovery processes with hot water temperature ranging from 75 OC to 100 OC at an interval of 5oC, using a locally constructed apparatus. It was used to simulate a reservoir bulk volume of 30 litres and 8.871 liters pore volume having fluid saturations of 20% formation brine. The heavy crude viscosities were found to be in the magnitude of 1.95cp to 0.87 cp for injected hot water of 75 OC to 100 OC after post recovery tests. Temperature losses to the rock matrix of a heavy crude reservoirs and optimum injection temperatures for a known reservoir bulk volume were also established via experimental processes. The validity of assertion that hot water injection can considerably alter flow properties of heavy oils was experimentally confirmed upon comparing with a convention al water injection process.

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Medina, Oscar E., Carol Olmos, Sergio H. Lopera, Farid B. Cortés, and Camilo A. Franco. "Nanotechnology Applied to Thermal Enhanced Oil Recovery Processes: A Review." Energies 12, no. 24 (December 9, 2019): 4671. http://dx.doi.org/10.3390/en12244671.

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The increasing demand for fossil fuels and the depleting of light crude oil in the next years generates the need to exploit heavy and unconventional crude oils. To face this challenge, the oil and gas industry has chosen the implementation of new technologies capable of improving the efficiency in the enhanced recovery oil (EOR) processes. In this context, the incorporation of nanotechnology through the development of nanoparticles and nanofluids to increase the productivity of heavy and extra-heavy crude oils has taken significant importance, mainly through thermal enhanced oil recovery (TEOR) processes. The main objective of this paper is to provide an overview of nanotechnology applied to oil recovery technologies with a focus on thermal methods, elaborating on the upgrading of the heavy and extra-heavy crude oils using nanomaterials from laboratory studies to field trial proposals. In detail, the introduction section contains general information about EOR processes, their weaknesses, and strengths, as well as an overview that promotes the application of nanotechnology. Besides, this review addresses the physicochemical properties of heavy and extra-heavy crude oils in Section 2. The interaction of nanoparticles with heavy fractions such as asphaltenes and resins, as well as the variables that can influence the adsorptive phenomenon are presented in detail in Section 3. This section also includes the effects of nanoparticles on the other relevant mechanisms in TEOR methods, such as viscosity changes, wettability alteration, and interfacial tension reduction. The catalytic effect influenced by the nanoparticles in the different thermal recovery processes is described in Sections 4, 5, 6, and 7. Finally, Sections 8 and 9 involve the description of an implementation plan of nanotechnology for the steam injection process, environmental impacts, and recent trends. Additionally, the review proposes critical stages in order to obtain a successful application of nanoparticles in thermal oil recovery processes.

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Gorshkova, K. L., and L. G. Tugashova. "CONJOINT WORK OF A FUZZY REGULATOR WITH A MATHEMATICAL MODEL OF PREPARATION OF EXTRA HEAVY CRUDE OIL." Oil and Gas Studies, no. 4 (September 1, 2017): 129–33. http://dx.doi.org/10.31660/0445-0108-2017-4-129-133.

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In this paper we propose a variant of conjoint work of a fuzzy controller with a mathematical model of the preparation of extra heavy crude oil by reducing energy expenditures for transportation of heavy oil. This is accomplished through the use of models-identifiers of state of the flows in the circuit of control system of installation for oil heating in the primary preparation of extra heavy crude oil for it’s adaptation in the conditions of uncertainty on the basis of systemstructured mathematical modeling of the process.

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McSpadden, Charles L. "U.S. Refining — Changing Supply and Slate Requirements." Energy Exploration & Exploitation 12, no. 2-3 (March 1994): 177–90. http://dx.doi.org/10.1177/014459879401200208.

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With international refining industries facing a number of challenges in the near future, it seems clear that those who survive will be ones with the ability to turn serious problems into real opportunities. In the U.S. refining industry, challenges such as slow growth in product demand, increasing reliance on imported raw materials, and continued exposure to offshore exporting refineries will have critical effects on the ability of the industry to capitalize on available opportunities. Other challenges include the ability to tolerate continued declines in crude oil quality and the serious monetary questions related to compliance with environmental legislation, including air, soil, and water clean-up. This paper presents the challenges which the U.S. refining industry faces over the coming years, and seeks to address those issues which will impact the success or failure of the industry as a whole. The paper begins with a focus on the demand for U.S. petroleum products, encompassing brief historical data and forecasts of demand for the next few years. Closely related to demand is the subject of U.S. refinery operations, including product import and yield patterns. In this vein, the paper offers forecasts of crude runs to stills, as well as forecasts of capacity changes. Because profitability of U.S. refineries is affected by raw material costs, the paper next probes the possibilities resulting from world crude oil price fluctuations, considering the reemergence of Iraq as a market player. Forecasts of profit margins for U.S. refiners in 1998 are also offered. Turning to crude oil supplies and qualities, the paper examines the downward trend of U.S. crude oil production, providing a forecast of the decline by 1998. An associated trend, that of U.S. crude oil imports, is also evaluated, with a discussion of the origins of these imports included. The paper then presents a brief discussion of the principal recipient of Canadian crude oil exports, the U.S. Midwest (PADD II), encompassing statistics for refinery runs and deliveries of crudes. Volumes of Canadian crude exported to the region are also presented, as well as crude oil qualities in the region. Finally, heavy crude oil prices are examined because of the degradation of average crude oil qualities consumed by U.S. refiners. Spreads between light and heavy crudes are contemplated, with a forecast for the current-dollar WTI/Maya price spread provided.

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Suarez-Dominguez, Edgardo J., Josue Fco Perez-Sanchez, Arturo Palacio-Perez, Elena Izquierdo-Kulich, and Susana Gonzalez-Santana. "Flow enhancer influence on non-isothermal systems for heavy crude oil production." Acta Universitaria 30 (June 17, 2020): 1–8. http://dx.doi.org/10.15174/au.2020.2645.

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Production of heavy and extra-heavy crude oils generally entails high costs, especially in the winter season, due to heat losses. This work studies the effect of a flow enhancer (a chemical formulation based on biodiesel and oxidized biodiesel of soy oil) on the viscosity of heavy crude oil from different wells in Northern Mexico. The observed results indicate a non-linear decreasing behavior of viscosity concerning temperature and volume fraction of the viscosity reducer. It is also presented a theoretical model that predicts the flow increase that can be achieved using the enhancer in systems in which crude oil temperature is higher than the temperature of the environment. Results showed adequate correspondence between experimental and predicted data. It was found that the enhancer increases the volume of crude oil that can be processed without varying pressure gradient.

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Zhou, Ying Ming, Shu Wei Wang, and Lin Lin. "An Application of BP Neural Network Model to Predict the Moisture Content of Crude Oil." Advanced Materials Research 524-527 (May 2012): 1327–30. http://dx.doi.org/10.4028/www.scientific.net/amr.524-527.1327.

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With the constant expansion of super heavy oil SAGD conversion development, the accurate testing of the crude oil in the high moisture content range is particularly important. In this paper, against the characteristics of Adopting SAGD technology exploiting heavy oil, BP neural network prediction model and calculation method has been adopted to predict the moisture content of crude oil. Through the study, the experimental data of the model were verified by the maximum prediction error is less than 3%, the accuracy of the forecast moisture content of crude oil to meet the site requirements. Through this study, the experimental data to the model was validated by the maximum prediction error is less than3%, the prediction accuracy of which to moisture content of crude oil is able to meet the requirements of the project site.

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Diab, Fadi. "The Study of the Desulfurization of Crude Oil in the Qatar Reservoirs System." Brilliant Engineering 1, no. 4 (May 17, 2020): 16–21. http://dx.doi.org/10.36937/ben.2020.004.003.

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According to problems of environmental pollution problems due to burning fuels having high Sulfur as furnace oil and because of related limitations, Sulfur removal methods have been emphasized to heavy crude oil patches. If Sulfur removal is necessary to furnace oil, and parts of crude oil would be processed but it should be pointed that this process include of operational problems as furnace oil Sulfur removal because of asphaltic components and metal contaminations developed chemical methods to mercaptan may not be used to crude oil and heavy parts. Therefore, it is attempted to provide new method to remove Sulfur composition from crude oil. in this paper all related methods to remove Sulfur compositions have been evaluated and operational problems have been assessed. Then, the best possible method has been introduced and supplementary discussion and economic evaluation have been provided.

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Guan, Da Lu, and Fang Yang. "An Electrical Design for Crude Oil Dilution." Advanced Materials Research 756-759 (September 2013): 4175–78. http://dx.doi.org/10.4028/www.scientific.net/amr.756-759.4175.

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The paper introduces an electrical design to dilute heavy crude oil. The design is based on the feedback principle and includes detection part, control part and actuator part. The practice proves the design is reliable and accurate to realize the proportion between the crude oil flow and dilution liquid flow.

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