The Experts below are selected from a list of 5013 Experts worldwide ranked by ideXlab platform
Yuhong Zhang - One of the best experts on this subject based on the ideXlab platform.
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underwater superoleophobic aptes sio2 pva organohydrogel for low temperature tolerant self healing Recoverable Oil water separation mesh
Chemical Engineering Journal, 2020Co-Authors: Yong Liu, Jianyu Yin, Pingping Zhao, Yuhong ZhangAbstract:Abstract Hydrogel is attracting more and more interest in the field of Oil-water separation because of its hydrophilicity and underwater oleophobicity. However, most traditional hydrogel composites have poor recycling performance, can not achieve self-repairing effect in the case of external mechanical damage, and inevitably freeze and at subzero temperatures because of a lot of water-soluble solvents in the gel network. These properties limit its application in the Oil-water separation field. Therefore, it is still a challenge to prepare self-repairing and recyclable gel-based materials for Oil/water separation in multiple environments. Here, superhydrophilic/underwater superoleophobic anti-freezing (3-aminopropyl) triethoxysilane-functionalized silica/polyvinyl alcohol (APTES-SiO2/PVA) organohydrogel and the related gel-coated mesh were successfully synthesized through a low-cost and simple process. The gel-coated mesh can separate Oil-water mixtures in various water environments (including deionized water, HCl solution (1 M), NaOH solution (1 M), saturated NaCl solution, artificial seawater and saturated NaCl solution (−20 °C)) with a separation efficiency of above 99%. Impressively, they can achieve self-repairing and the recycling of raw materials through the excellent remoldability of organohydrogel (sol-gel transformation). The low-cost and easy fabrication, harsh-environment tolerance, self-repairing and recyclable features make the organohydrogel-based mesh promising toward Oil/water separation under practical conditions.
Youfa Zhang - One of the best experts on this subject based on the ideXlab platform.
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Sprayed superamphiphilic copper foams for long term Recoverable Oil-water separation
Surface and Coatings Technology, 2018Co-Authors: Zhu Haiyan, Li Doudou, Cai Mingjuan, Youfa ZhangAbstract:Abstract Superamphiphilic copper foams were prepared by one-step spraying a water-borne solution of hydroxyl-functionalized multi-wall carbon nanotubes and melamine formaldehyde. Water or Oil droplets can spread on the coating rapidly and completely in air; meanwhile, Oil droplets underwater can retain quasi-spheres without any penetration all the time (superoleophobic underwater), and so the water droplets underOil can do (superhydrophobic underOil). The superamphiphilic copper foams which prewetted by water can effectively separate Oil and water solely driven by gravity, showing high separation efficiency and water flux (> 5000 L m− 2 h− 1) for a series of Oil-water mixtures. Furthermore, the as-prepared copper foams exhibited outstanding mechanical durability in the long-term mechanical wear process and excellent chemical stability under a series of harsh environment conditions, including strong acid and strong base. Meanwhile, The samples still retained the underwater superoleophobic property after 4 separation-water backwash cycles (> 140 continuous separation repetitions) with the separation efficiency always remaining above 95%, which indicated the excellent recoverability and recyclability.
Egberto Pereira - One of the best experts on this subject based on the ideXlab platform.
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The volumetric potential assessment of the Oil shales of Tremembé Formation, Taubaté Basin, Brazil
Journal of Petroleum Exploration and Production Technology, 2020Co-Authors: Fernanda Setta, Sérgio Bergamaschi, René Rodrigues, Cleveland Jones, Hernani Chaves, Marco Brito, Egberto PereiraAbstract:This assessment of the volumetric potential of the Oil shales of Tremembé Formation (Oligocene, Taubaté Basin, Brazil) was based on the sedimentological study of 2457 total organic carbon and 1007 Rock–Eval pyrolysis analyses of core samples from nine survey wells drilled in the central portion of Taubaté Basin. Along a 240-m-thick package in the upper part of Tremembé Formation, thirteen chemostratigraphic units with thicknesses varying from 10 to 35 m were identified. The upper interval (unit L), 30 m thick, exhibited the highest organic content and original generation potential and was thus studied in detail. In unit L, Oil yield maps were constructed, seeking to identify the most attractive areas for industrially exploiting the Oil shales, and volumetric calculations employing a probabilistic Monte Carlo method were conducted to quantify the potentially Recoverable Oil volume. Three exploratory scenarios based on yield values (S1 + S2) were considered for calculating the Oil volumes, seeking to offer different exploratory scenarios for decision making. For the scenario that considered only average yields above 100 mg HC/g rock, the Recoverable Oil volume is 525 million bbl (P90) to 884 million bbl (P10); for the scenario that considered only average yields above 80 mg HC/g rock, the Recoverable Oil volume is 1.4 billion bbl (P90) to 2.6 billion bbl (P10); and for the scenario that considered only average yields above 60 mg HC/g rock, the Recoverable Oil volume is 3.6 billion bbl (P90) to 5.4 billion bbl (P10).
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The volumetric potential assessment of the Oil shales of Tremembé Formation, Taubaté Basin, Brazil
Journal of Petroleum Exploration and Production Technology, 2020Co-Authors: Fernanda Setta, Sérgio Bergamaschi, René Rodrigues, Marco Brito, Cleveland M. Jones, Hernani Aquini Fernandes Chaves, Egberto PereiraAbstract:This assessment of the volumetric potential of the Oil shales of Tremembe Formation (Oligocene, Taubate Basin, Brazil) was based on the sedimentological study of 2457 total organic carbon and 1007 Rock–Eval pyrolysis analyses of core samples from nine survey wells drilled in the central portion of Taubate Basin. Along a 240-m-thick package in the upper part of Tremembe Formation, thirteen chemostratigraphic units with thicknesses varying from 10 to 35 m were identified. The upper interval (unit L), 30 m thick, exhibited the highest organic content and original generation potential and was thus studied in detail. In unit L, Oil yield maps were constructed, seeking to identify the most attractive areas for industrially exploiting the Oil shales, and volumetric calculations employing a probabilistic Monte Carlo method were conducted to quantify the potentially Recoverable Oil volume. Three exploratory scenarios based on yield values (S1 + S2) were considered for calculating the Oil volumes, seeking to offer different exploratory scenarios for decision making. For the scenario that considered only average yields above 100 mg HC/g rock, the Recoverable Oil volume is 525 million bbl (P90) to 884 million bbl (P10); for the scenario that considered only average yields above 80 mg HC/g rock, the Recoverable Oil volume is 1.4 billion bbl (P90) to 2.6 billion bbl (P10); and for the scenario that considered only average yields above 60 mg HC/g rock, the Recoverable Oil volume is 3.6 billion bbl (P90) to 5.4 billion bbl (P10).
Anders Andreasen - One of the best experts on this subject based on the ideXlab platform.
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Applied Process Simulation-Driven Oil and Gas Separation Plant Optimization using Surrogate Modeling and Evolutionary Algorithms
2019Co-Authors: Anders AndreasenAbstract:In this article the optimization of a realistic Oil and gas separation plant has been studied. Two different fluids are investigated and compared in terms of the optimization potential. Using Design of Computer Experiment (DACE) via Latin Hypercube Sampling (LHS) and rigorous process simulations, surrogate models using Kriging have been established for selected model responses. The surrogate models are used in combination with a variety of different evolutionary algorithms for optimizing the operating profit, mainly by maximizing the Recoverable Oil production. A total of 10 variables representing pressure and temperature various key places in the separation plant are optimized to maximize the operational profit. The optimization is bounded in the variables and a constraint function is included to ensure that the optimal solution allows export of Oil with an RVP < 12 psia. The main finding is that, while a high pressure is preferred in the first separation stage, apparently a single optimal setting for the pressure in downstream separators does not appear to exist. In the second stage separator apparently two different, yet equally optimal, settings are revealed. In the third and final separation stage a correlation between the separator pressure and the applied inlet temperature exists, where different combinations of pressure and temperature yields equally optimal results.<br>
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Applied Process Simulation-Driven Oil and Gas Separation Plant Optimization using Surrogate Modeling and Evolutionary Algorithms
2019Co-Authors: Anders AndreasenAbstract:In this article the optimization of a realistic Oil and gas separation plant has been studied. Two different fluids are investigated and compared in terms of the optimization potential. Using Design of Computer Experiment (DACE) via Latin Hypercube Sampling (LHS) and rigorous process simulations, surrogate models using Kriging have been established for selected model responses. The surrogate models are used in combination with a variety of different evolutionary algorithms for optimizing the operating profit, mainly by maximizing the Recoverable Oil production. A total of 10 variables representing pressure and temperature various key places in the separation plant are optimized to maximize the operational profit. The optimization is bounded in the variables and a constraint function is included to ensure that the optimal solution allows export of Oil with an RVP < 12 psia. The main finding is that, while a high pressure is preferred in the first separation stage, apparently a single optimal setting for the pressure in downstream separators does not appear to exist. In the second stage separator apparently two different, yet equally optimal, settings are revealed. In the third and final separation stage a correlation between the separator pressure and the applied inlet temperature exists, where different combinations of pressure and temperature yields equally optimal results.<br>
Kevin Moran - One of the best experts on this subject based on the ideXlab platform.
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Study of Solvent−Bitumen−Water Rag Layers
Energy & Fuels, 2009Co-Authors: Sumit K. Kiran, Edgar Acosta, Kevin MoranAbstract:A major operational issue in the crude Oil industry is the formation of intermediate rag layers, (primarily water-in-Oil emulsions) in Oil−water separation processes that limit the amount and quality of Recoverable Oil. In this study, the formation of rag layers is evaluated as a function of solvent−bitumen−water ratios, solvent aromaticity, and temperature, with various imaging techniques. Using these techniques, it is possible to obtain an estimate of the amount of Oil, water, and asphalthenes in the rag layer and excess phases. On the basis of these material balances, it was observed that when bitumen is diluted with a more paraffinic (poor) solvent, such as Heptol 80/20 (80% heptane and 20% toluene), the asphaltenes in solution tend to adsorb/segregate at exposed Oil−water interfaces, impacting the extent of rag layer formation. Diluting similar systems with a more aromatic solvent (Heptol 50/50) reduces the surface activity of the asphaltenes, and the stability of rag layers, as evidenced by lower as...
