Deep-Vacuum Fractionation of Heavy Oil and Bitumen, Part I: Apparatus and Standardized Procedure

Díaz, O. Castellanos; Sánchez-Lemus, M. C.; Schoeggl, F. F.; Satyro, Marco A.; Taylor, Shawn D.; Yarranton, Harvey W.

doi:10.1021/ef500489y

Cited by 23 publications

(21 citation statements)

References 16 publications

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“…The BR-HO-A2, BR-HO-A3, and BR-HO-A4 oils were separated into a distillate cut and a residue (300 °C+) cut using spinning band distillation (SBD), as described elsewhere. 41 The residue was then separated into SARA fractions using the modified ASTM D4124 method as described elsewhere. 42 Molecular weight, density, and solubility parameters of the fractions were measured as described in section 2.2.…”

Section: Methodsmentioning

confidence: 99%

Application of the Modified Regular Solution Model to Crude Oils Characterized from a Distillation Assay

2020

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The modified regular solution model was developed to predict onset and amount (yield) of asphaltene precipitation from mixtures of crude oil and solvents. The most recent version of the model includes the partitioning of all components between a solvent-rich phase and an asphaltene-rich phase, where the solvents are pure components with known properties and the crude oil is represented as pseudo-components defined on the basis of a saturate, aromatic, resin, and asphaltene (SARA) assay. The molecular weight, density, and solubility parameter of each pseudo-component are determined from correlations. This model is sensitive to uncertainties in the SARA assay composition and is not compatible with the standard phase behavior modeling methodology based on pseudo-components defined from a distillation assay. In this contribution, the model was extended to crude oil pseudocomponents based on boiling cuts (TBP). The n-pentane-insoluble asphaltene fraction was characterized in the same way as the SARA-based model. The molecular weight and density of the TBP-based pseudo-components were predicted from well-established correlations. New correlations were proposed for the maltene pseudo-component solubility parameters as a function of the temperature and pressure. The TBP-based model was tested on two data sets: (1) onsets, yields, and phase compositions for a Western Canada bitumen mixed with n-alkanes from propane to n-heptane at temperatures and pressures up to 250 °C and 13.8 MPa, respectively, and (2) yields from eight oils from different geographical regions mixed with n-alkanes from n-pentane to noctane at temperatures and pressures up to 100 °C and 6.8 MPa, respectively. The overall absolute deviation was 2 wt % for both data sets, similar to the deviations found for the SARA-based model.

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Section: Methodsmentioning

confidence: 99%

Application of the Modified Regular Solution Model to Crude Oils Characterized from a Distillation Assay

2020

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“…The samples were removed from the water bath, and nitrogen purge was continued for 2 more days. These samples have been shown to release volatiles only above 120 °C; therefore, volatile losses were considered negligible. Finally, immediately before the precipitation experiments, n -heptane required for the experiment was treated with nitrogen in the same way as the MSB oil but with a purge time of 3 h instead of 24 h.…”

Section: Experimental Methodsmentioning

confidence: 99%

Effect of Air on the Kinetics of Asphaltene Precipitation from Diluted Crude Oils

et al. 2019

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The kinetics of asphaltene precipitation was investigated for five crude oils diluted with n-heptane at 21 °C in air and nitrogen atmospheres. The onset of precipitation, defined as the precipitant (n-heptane) content at which detectable asphaltene particles first appear, was measured in air at different contact times using optical microscopy and a gravimetric method. Asphaltene yields (mass asphaltene/mass oil) were measured in air over time gravimetrically. The data were compared with yields and "yield onsets" previously measured for the same mixtures in a nitrogen atmosphere. 1 In a nitrogen atmosphere, the yields increased and the onsets decreased over approximately 50 h but then reached plateau values, indicating that an equilibrium condition existed. In an air atmosphere, the yields and onsets were the same as in nitrogen for the first 50 h, but then the yields gradually increased for the duration of the experiments. The onsets shifted to lower values over time, and there was no equilibrium onset condition. Hence, precipitation data collected in air below 50 h can be used for kinetic modeling as is; however, data collected in air over longer times overstates asphaltene yields under anaerobic conditions and requires correction. It is hypothesized that the oxygen in the air catalyzes or participates in reactions that alter the asphaltenes and other crude oil components over time so that they become less soluble. The oxidation rate appears to correlate approximately with the asphaltene content of the oil. The population balance first developed by Maqbool et al., Modeling the Aggregation of Asphaltene Nanoaggregates in Crude Oil-Precipitant Systems. Energy Fuels, 25 (4), 2011, 1585-1596, and later modified by Duran et al., Kinetics of Asphaltene Precipitation/Aggregation from Diluted Crude Oil. Fuel, 255, 2019, 115859, was further adapted to account for the increase in yield over time due to oxygen by introducing a term for the generation of unstable asphaltene primary particles. The proposed model matched the precipitation yield data from this study and from the literature with an average absolute deviation of less than 2 wt %.

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“…Heptane was considered as solvent for separation of asphaltene from bitumen. Heptane was suggested as the logical solvent to obtain asphaltene, because the most insoluble material is precipitated by heptane and heavier solvents. , The asphaltene separation process is described as follows. , …”

Section: Methodsmentioning

confidence: 99%

Effect of Asphaltene on Phase Behavior and Thermophysical Properties of Solvent/Bitumen Systems

et al. 2017

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Solvent-aided bitumen production from oil sands has shown promise as an alternative to thermal recovery methods. Phase behavior studies of solvent/bitumen mixtures are necessary for reservoir simulation of recovery methods, process design and operation of surface facilities, and transportation. Bitumen and heavy crudes comprise a different weight fraction of asphaltene. In this study, the effect of asphaltene on phase behavior, viscosity, and density of solvent/bitumen systems is studied. Ethane (C2H6) and carbon dioxide (CO2) are considered as solvents. Phase behavior studies and property measurements are conducted on solvent/bitumen and solvent/deasphalted bitumen systems. Solubility of C2H6 and CO2 in the original and deasphalted bitumen are measured. The viscosity and density of the liquid phase are also measured by inline viscometer and densitometer at temperature and pressure ranges of 70–130 °C and 2–8 MPa, respectively. The measured data showed that the asphaltene has no significant effect on C2H6 solubility in bitumen. However, the solubility of CO2 in the original bitumen differs from that of the deasphalted bitumen. The significant effect of asphaltene on density and viscosity of bitumen is also quantified. Mixing rules are also employed to estimate the density and viscosity of asphaltene using the density and viscosity of bitumen and deasphalted bitumen.

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Deep-Vacuum Fractionation of Heavy Oil and Bitumen, Part I: Apparatus and Standardized Procedure

Cited by 23 publications

References 16 publications

Application of the Modified Regular Solution Model to Crude Oils Characterized from a Distillation Assay

Application of the Modified Regular Solution Model to Crude Oils Characterized from a Distillation Assay

Effect of Air on the Kinetics of Asphaltene Precipitation from Diluted Crude Oils

Effect of Asphaltene on Phase Behavior and Thermophysical Properties of Solvent/Bitumen Systems

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