The Experts below are selected from a list of 324 Experts worldwide ranked by ideXlab platform
Yansong Zhao - One of the best experts on this subject based on the ideXlab platform.
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ethylene vinyl acetate copolymer and resin stabilized Asphaltenes synergistically improve the flow behavior of model waxy oils 2 effect of Asphaltene Content
Energy & Fuels, 2018Co-Authors: Bo Yao, Fei Yang, Xiaoping Zhang, Guangyu Sun, Gang Liu, Yansong ZhaoAbstract:In part 1 (10.1021/acs.energyfuels.7b03657), the synergistic effect of ethylene–vinyl acetate copolymer (EVA) pour point depressant (PPD) and rensin-stabilized Asphaltenes on improving the flowability of synthetic waxy oil has been verified. This paper is a continuous work studying the effect of the Asphaltene Content (0.01–3 wt %) on the synergistic effect between EVA PPD and resin-stabilized Asphaltenes. The results showed that, in the absence of EVA and with the increase of the Asphaltene Content, the precipitated wax crystals of the waxy oil tend to grow gradually from initial big needle-like to smaller and more regular (spherical-like) particles with a larger amount; therefore, adding aphaltenes can only decrease the apparent viscosity of waxy oil at the temperature range slightly lower than the wax precipitation temperature (WPT) (the precipitated wax crystal amount is low), and the temperature range is broadened by increasing the Asphaltene Content. When the temperature is decreased far below the W...
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Ethylene–Vinyl Acetate Copolymer and Resin-Stabilized Asphaltenes Synergistically Improve the Flow Behavior of Model Waxy Oils. 2. Effect of Asphaltene Content
Energy & Fuels, 2018Co-Authors: Bo Yao, Fei Yang, Xiaoping Zhang, Guangyu Sun, Gang Liu, Yansong ZhaoAbstract:In part 1 (10.1021/acs.energyfuels.7b03657), the synergistic effect of ethylene–vinyl acetate copolymer (EVA) pour point depressant (PPD) and rensin-stabilized Asphaltenes on improving the flowability of synthetic waxy oil has been verified. This paper is a continuous work studying the effect of the Asphaltene Content (0.01–3 wt %) on the synergistic effect between EVA PPD and resin-stabilized Asphaltenes. The results showed that, in the absence of EVA and with the increase of the Asphaltene Content, the precipitated wax crystals of the waxy oil tend to grow gradually from initial big needle-like to smaller and more regular (spherical-like) particles with a larger amount; therefore, adding aphaltenes can only decrease the apparent viscosity of waxy oil at the temperature range slightly lower than the wax precipitation temperature (WPT) (the precipitated wax crystal amount is low), and the temperature range is broadened by increasing the Asphaltene Content. When the temperature is decreased far below the W...
Bo Yao - One of the best experts on this subject based on the ideXlab platform.
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ethylene vinyl acetate copolymer and resin stabilized Asphaltenes synergistically improve the flow behavior of model waxy oils 2 effect of Asphaltene Content
Energy & Fuels, 2018Co-Authors: Bo Yao, Fei Yang, Xiaoping Zhang, Guangyu Sun, Gang Liu, Yansong ZhaoAbstract:In part 1 (10.1021/acs.energyfuels.7b03657), the synergistic effect of ethylene–vinyl acetate copolymer (EVA) pour point depressant (PPD) and rensin-stabilized Asphaltenes on improving the flowability of synthetic waxy oil has been verified. This paper is a continuous work studying the effect of the Asphaltene Content (0.01–3 wt %) on the synergistic effect between EVA PPD and resin-stabilized Asphaltenes. The results showed that, in the absence of EVA and with the increase of the Asphaltene Content, the precipitated wax crystals of the waxy oil tend to grow gradually from initial big needle-like to smaller and more regular (spherical-like) particles with a larger amount; therefore, adding aphaltenes can only decrease the apparent viscosity of waxy oil at the temperature range slightly lower than the wax precipitation temperature (WPT) (the precipitated wax crystal amount is low), and the temperature range is broadened by increasing the Asphaltene Content. When the temperature is decreased far below the W...
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Ethylene–Vinyl Acetate Copolymer and Resin-Stabilized Asphaltenes Synergistically Improve the Flow Behavior of Model Waxy Oils. 2. Effect of Asphaltene Content
Energy & Fuels, 2018Co-Authors: Bo Yao, Fei Yang, Xiaoping Zhang, Guangyu Sun, Gang Liu, Yansong ZhaoAbstract:In part 1 (10.1021/acs.energyfuels.7b03657), the synergistic effect of ethylene–vinyl acetate copolymer (EVA) pour point depressant (PPD) and rensin-stabilized Asphaltenes on improving the flowability of synthetic waxy oil has been verified. This paper is a continuous work studying the effect of the Asphaltene Content (0.01–3 wt %) on the synergistic effect between EVA PPD and resin-stabilized Asphaltenes. The results showed that, in the absence of EVA and with the increase of the Asphaltene Content, the precipitated wax crystals of the waxy oil tend to grow gradually from initial big needle-like to smaller and more regular (spherical-like) particles with a larger amount; therefore, adding aphaltenes can only decrease the apparent viscosity of waxy oil at the temperature range slightly lower than the wax precipitation temperature (WPT) (the precipitated wax crystal amount is low), and the temperature range is broadened by increasing the Asphaltene Content. When the temperature is decreased far below the W...
Serhat Akin - One of the best experts on this subject based on the ideXlab platform.
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Asphaltene Deposition During Steam-Assisted Gravity Drainage: Effect of Non-Condensable Gases
Petroleum Science and Technology, 2006Co-Authors: S. Canbolat, Serhat Akin, Anthony R KovscekAbstract:Abstract Asphaltene deposition was investigated during laboratory-scale steam-assisted gravity drainage (SAGD) experiments to probe in situ upgrading of a heavy oil. Tests were conducted with and without the addition of non-condensable gases (carbon dioxide or n-butane) to the steam. The apparatus was a three-dimensional scaled physical model packed with crushed limestone saturated with 12.4° API heavy-crude oil. Temperature, pressure, and production data, as well as the Asphaltene Content of the produced oil, were monitored continuously during the experiments. For small well separations, as the fraction of non-condensable gas in the steam increased, the steam condensation temperature and the steam-oil ratio decreased. As a result of lower temperature, the heavy oil was less mobile in the steam chamber relative to pure steam injection. Thus, the heating period was prolonged and the recovery, as well as the rate of oil recovery, decreased. Asphaltene Content of the oil produced as a result of pure steam in...
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Mathematical modeling of steam-assisted gravity drainage
Computers & Geosciences, 2006Co-Authors: Serhat AkinAbstract:A mathematical model for gravity drainage in heavy-oil reservoirs and tar sands during steam injection in linear geometry is proposed. The mathematical model is based on experimental observations that the steam zone shape is an inverted triangle with the vertex fixed at the bottom production well. Both temperature and Asphaltene Content dependence of viscosity of the drained heavy oil and their impact on heavy oil production are considered. The developed model has been validated using experimental data presented in the literature. It is seen that the oil production rate is affected as the Asphaltene Content of the crude oil changes as a function of temperature. The oil production rate conforms well to previously published data covering a wide range of heavy oils and sands for gravity drainage.
Berna Hascakir - One of the best experts on this subject based on the ideXlab platform.
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Effect of solvent type on emulsion formation in steam and solvent-steam flooding processes for heavy oil recovery
Colloids and Surfaces A: Physicochemical and Engineering Aspects, 2021Co-Authors: Taniya Kar, Berna HascakirAbstract:Abstract In this study, a series of steam and solvent-steam flooding experiments are conducted to study the produced oil quality in terms of water-oil emulsions. A set of seven experiments are performed, beginning with steam flooding, and solvent-steam flooding using propane, n-butane, n-pentane, n-hexane, and n-heptane as paraffinic solvents that are insoluble in Asphaltenes, and toluene, which is a polar solvent soluble in Asphaltenes. Co-injection of solvents along with steam improves the cumulative oil recovery and produced oil quality by promoting less water migration into the bulk oil phase, hence reducing water-Asphaltenes polar interactions. Asphaltene Content in the produced oil and the displaced residual oil is found to generally increase with increasing carbon number of paraffinic solvent. Hexane is found to be the most effective hydrocarbon solvent in solvent-steam flooding for bitumen recovery, with optimum amount of Asphaltene Content and dispersion in produced oil, and minimum amount of water trapped in the oil phase, hence alleviating emulsion complexity. This is a first attempt to assess the efficiency of a wide range of solvent-steam flooding performances in terms of obtained oil emulsion quality, which will be very influential for field applications in selecting a solvent for a particular reservoir.
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Carbon Dioxide Storage in High Asphaltene Content Oil Reservoirs
Day 1 Wed May 17 2017, 2017Co-Authors: Berna HascakirAbstract:Abstract Carbon dioxide storage in high viscosity and density hydrocarbon reservoirs that have high Asphaltenes Content is attractive. However, CO2 is an Asphaltenes insoluble solvent, hence, CO2 injection into these reservoirs is expected to cause Asphaltenes deposition. In pore-scale, how the deposition of Asphaltenes would impact the CO2 trapping and consequently CO2 storage is not known. This study proposes highly efficient trapping and storage of CO2 in high-Asphaltenes Content reservoirs. Our recent experimental studies on CO2 flooding into bitumen reservoirs revealed with Scanning Electron Microscopy (SEM) images that CO2 gets trapped in Asphaltenes phase. The CO2 trapping is occurred both in residual and displaced oil due to mainly the presence of clays in the reservoir rock. The CO2-displaced oil interaction promotes the formation of foamy oil. As the size of the CO2 bubbles in the displaced oil increases, the CO2 storage capacity of the displaced oil is enhanced. The bubble size is mainly controlled by the CO2 injection rate and the bigger CO2 bubbles in the displaced oil are obtained at lower CO2 injection rate. Hence, CO2 trapping in high Asphaltenes Content reservoirs can be more effective if the oil reservoir has high clay Content and when CO2 storage is achieved through low injection rates. However, because low injection rates provide more interaction time for Asphaltenes and CO2, Asphaltenes deposition may occur near injection well and deposition of Asphaltenes may inhibit the further propagation of CO2 which may limit the reservoir CO2 storage capacity. It should be also noted that the optimum CO2 injection rate for storage purpose can be different for every reservoir and hence, should be determined experimentally.
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Effective Extraction of High Viscosity and Low API Gravity Hydrocarbon Resources With Solvent-Steam Processes
All Days, 2016Co-Authors: Berna HascakirAbstract:Abstract Extraction of unconventional resources is vital to meet future hydrocarbon demand. However, the effective extraction of these unconventional resources cannot be accomplished by the application of conventional technologies. This study summarizes different combination of different Enhanced Oil Recovery (EOR) methods to recover effectively the low API gravity and high viscosity crudes to find the main factors affecting the EOR performances most. Several steam flooding, steam assisted gravity drainage, and solvent aided-steam processes (SA-SP) (both with Asphaltene solvent and non-solvents) were tested on heavy, extra-heavy, and bitumen resources. Carbon dioxide, propane, n-hexane, and toluene were tested as solvents. While carbon dioxide, propane, and n-hexane are Asphaltene non-solvents, toluene is Asphaltene solvent. The process performances were discussed in terms of cumulative oil recovery and produced oil quality. Produced oil qualities were compared according to their Asphaltene, clay, and water Contents. Asphaltene Content directly correlates to the water and clay Contents of the produced oil samples. As the Asphaltene Content of produced oil increases while the water Content increases, the clay Content decreases. The worst produced oil quality was obtained by SAGD and toluene-SAGD. The experiments conducted with the Asphaltenes insoluble solvents (carbon dioxide, propane, and n-hexane) produced the highest quality oil with low water Content and high deasphalted oil Content.
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A Mechanistic Understanding of Asphaltene Precipitation from Varying Saturate Concentration Perspective
Day 3 Fri November 20 2015, 2015Co-Authors: Andreas Prakoso, Abhishek Punase, Berna HascakirAbstract:Abstract Asphaltene precipitation can severely hamper the petroleum extraction by plugging the pores or precipitation in production lines. Although the effect of temperature and pressure on Asphaltene deposition is well known, how the variations in oil composition affect the Asphaltene precipitation mechanism requires more clarity. This work investigates the effect of compositional changes on Asphaltene stability. The impact of oil composition is explained by preparing pseudo-components by blending the crude oil with their own saturate fractions. A systematic characterization of 11 different bitumen and crude oil samples is carried out on the basis of their density, viscosity, Asphaltene Content, and Asphaltene composition. n-pentane is used to determine the Asphaltene Content of each sample by following a standard method. The Asphaltene composition is then determined with Fourier Transform InfraRed (FTIR) spectroscopy. The Asphaltene stability is tested by performing the onset Asphaltene precipitation (OAP) tests. The results from the characterization study indicated that there is no direct relationship between the Asphaltene Content and the density or the viscosity of the bulk samples. However, the FTIR profiles suggest that the polarity of the Asphaltene molecules greatly influence the size of the precipitated clusters. The outcomes from the OAP tests were used to decipher the thermodynamic equilibrium state on the mechanism of Asphaltene destabilization as per the change in the polar (resins and Asphaltenes) to nonpolar (saturates and aromatics), saturates to aromatics, and resins to Asphaltenes fraction of the bulk sample. It was observed that the increase in saturates concentration destabilized the Asphaltene molecules and resulted in more precipitation. The presence of polar functional groups, as observed from the FTIR of the saturate fraction are believed to cause higher Asphaltene precipitation. During oil production, the temperature and pressure changes can lead to Asphaltene deposition and alteration in the crude oil chemical composition. A holistic understanding of the thermodynamic equilibrium corresponding to these changes can be achieved by analyzing Asphaltene destabilization or restabilization processes, specifically by changing the saturate concentrations. These results are extremely useful to comprehend the Asphaltene stabilization mechanism and can improve the accuracy of existing Asphaltene models.
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The Pore Scale Description of Carbon Dioxide Storage into High Asphaltene Content Reservoirs
All Days, 2015Co-Authors: Raphael Coelho, Berna HascakirAbstract:Abstract The knowledge of how CO2 interacts with reservoir fluids and rock is essential for effective and reliable CO2 storage. This work investigates CO2 storage in unconventional oil reservoirs with high Asphaltene Content and explains the CO2 storage mechanism in pore-scale. Considering that Asphaltenes are insoluble in CO2, Asphaltene precipitation is induced during CO2 injection, controlling CO2 solubility and capillary trapping mechanisms. In this study, CO2-oil interaction is examined through core flooding experiments in a high Asphaltene Content (34.3 wt%) Canadian bitumen sample with 8.8º API. To study how irreversible clay-Asphaltene interaction affects CO2 capillary trapping, the reservoir rock is prepared with and without clay addition. The role of CO2 injection rate on solubility trapping with experiments at varying injection flow rates. Displaced fluids and postmortem samples are subjected to several analyses to observe the CO2 storage mechanisms in pore scale due to CO2-Asphaltene and CO2-clay-Asphaltene interactions. It was found that CO2-clay-Asphaltene interaction may favor CO2 capillary trapping into high Asphaltene Content reservoirs. Reservoir clays play important roles in porosity and permeability reduction due to clay interactions with Asphaltenes. The low CO2 flow rate was found to favor solubility trapping. Therefore, our results suggest that the presence of clays and the CO2 injection rate are critical parameters controlling the effectiveness of CO2 storage in high Asphaltene Content reservoirs. Introduction Underground carbon dioxide (CO2) storage projects usually target the depleted light oil and natural gas fields due to operational expertise, favorable geological features, and existence of infrastructure [1; 2]. However, as CO2 emissions are projected to increase in the next 35 years [3], other storage alternatives are required to mitigate environmental impacts. In this context, CO2 storage in unconventional oil reservoirs with low API gravity may be an attractive candidate on the short to medium term [4; 5]. These low API gravity oils usually have high Asphaltene Content, which can represent up to 45.3 wt% of the crude oil [6]. CO2 injection can cause Asphaltenes precipitate in the pore space as CO2 is insoluble in Asphaltenes [7; 8]. Therefore, the effectiveness of CO2 microscopic storage mechanisms will be affected, particularly for capillary (or residual) and solubility trapping.
Fei Yang - One of the best experts on this subject based on the ideXlab platform.
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ethylene vinyl acetate copolymer and resin stabilized Asphaltenes synergistically improve the flow behavior of model waxy oils 2 effect of Asphaltene Content
Energy & Fuels, 2018Co-Authors: Bo Yao, Fei Yang, Xiaoping Zhang, Guangyu Sun, Gang Liu, Yansong ZhaoAbstract:In part 1 (10.1021/acs.energyfuels.7b03657), the synergistic effect of ethylene–vinyl acetate copolymer (EVA) pour point depressant (PPD) and rensin-stabilized Asphaltenes on improving the flowability of synthetic waxy oil has been verified. This paper is a continuous work studying the effect of the Asphaltene Content (0.01–3 wt %) on the synergistic effect between EVA PPD and resin-stabilized Asphaltenes. The results showed that, in the absence of EVA and with the increase of the Asphaltene Content, the precipitated wax crystals of the waxy oil tend to grow gradually from initial big needle-like to smaller and more regular (spherical-like) particles with a larger amount; therefore, adding aphaltenes can only decrease the apparent viscosity of waxy oil at the temperature range slightly lower than the wax precipitation temperature (WPT) (the precipitated wax crystal amount is low), and the temperature range is broadened by increasing the Asphaltene Content. When the temperature is decreased far below the W...
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Ethylene–Vinyl Acetate Copolymer and Resin-Stabilized Asphaltenes Synergistically Improve the Flow Behavior of Model Waxy Oils. 2. Effect of Asphaltene Content
Energy & Fuels, 2018Co-Authors: Bo Yao, Fei Yang, Xiaoping Zhang, Guangyu Sun, Gang Liu, Yansong ZhaoAbstract:In part 1 (10.1021/acs.energyfuels.7b03657), the synergistic effect of ethylene–vinyl acetate copolymer (EVA) pour point depressant (PPD) and rensin-stabilized Asphaltenes on improving the flowability of synthetic waxy oil has been verified. This paper is a continuous work studying the effect of the Asphaltene Content (0.01–3 wt %) on the synergistic effect between EVA PPD and resin-stabilized Asphaltenes. The results showed that, in the absence of EVA and with the increase of the Asphaltene Content, the precipitated wax crystals of the waxy oil tend to grow gradually from initial big needle-like to smaller and more regular (spherical-like) particles with a larger amount; therefore, adding aphaltenes can only decrease the apparent viscosity of waxy oil at the temperature range slightly lower than the wax precipitation temperature (WPT) (the precipitated wax crystal amount is low), and the temperature range is broadened by increasing the Asphaltene Content. When the temperature is decreased far below the W...
