Measurement and modeling of the phase behavior of solvent diluted bitumens

Agrawal, Pawan; Schoeggl, F. F.; Satyro, Marco A.; Taylor, Shawn D.; Yarranton, Harvey W.

doi:10.1016/j.fluid.2012.07.025

Cited by 55 publications

(81 citation statements)

References 53 publications

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“…The gas sample for Live B1 was contaminated with air, and the result of GC analysis was not reliable. The composition of dissolved gas in Live B1 was calculated on the basis of a simulation of the mixing procedure following the methodology by Agrawal et al (2012), as shown in Table 1. The composition is nearly identical to that of Live B2.…”

Section: Experimental Methodsmentioning

confidence: 99%

Viscosity Prediction for Solvent-Diluted Live Bitumen and Heavy Oil at Temperatures Up to 175-deg-C

Motahhari

Schoeggl

Satyro

et al. 2013

Journal of Canadian Petroleum Technology

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Accurate predictions of heavy-oil and bitumen viscosity as a function of temperature, pressure, and composition are required for the design of thermal and solvent-based recovery methods. In this case study, the applicability of the recently developed Expanded Fluid (EF) viscosity model is tested on measured viscosities of diluted dead and live heavy oil and bitumen at temperatures from 20 to 175 C and pressures up to 10 MPa. Density and viscosity data were collected for a condensate solvent, dead (gas-free) bitumen, and dead heavy oil from western Canada, and for the corresponding live oils and diluted mixtures of the dead and live oils with condensate solvent. Solubility, density, and viscosity data for heavy oil saturated with carbon dioxide (CO 2 ) were obtained from the literature.The model was fitted to the data of the dead oils and the condensate with average relative deviations less than 11%. The viscosity of the live bitumen and heavy oil was then predicted to within 21 and 31% of the measured value on the basis of measured and calculated live-oil densities, respectively. Diluting the live and dead bitumen with 3 to 30 wt% condensate or carbon dioxide reduced the viscosity by one to three orders of magnitude, and the viscosities were predicted with an average relative deviation less than 16 and 24% on the basis of measured and calculated mixture densities, respectively.

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Section: Experimental Methodsmentioning

confidence: 99%

Viscosity Prediction for Solvent-Diluted Live Bitumen and Heavy Oil at Temperatures Up to 175-deg-C

Motahhari

Schoeggl

Satyro

et al. 2013

Journal of Canadian Petroleum Technology

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“…Below its glass transition temperature, it appears as glassy particles (Rastegari et al, 2004) due to the kinetic inability of the droplets to coalesce (Sirota, 2005). Above its glass transition temperature, it appears as spherical droplets which coalesce forming a separate liquid phase (Agrawal et al, 2012;Johnston et al, 2017a). Hence, the amount, composition, and properties of asphaltene-rich phase can vary considerably with conditions.…”

Section: List Of Figures and Illustrationsmentioning

confidence: 99%

The Phase Behavior of Heavy Oil and Propane Mixtures

Mancilla-Polanco

Schoeggl

Johnston

et al. 2017

Day 2 Thu, February 16, 2017

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The phase behavior of propane diluted bitumen was mapped from temperatures between 20 and 180°C and pressures up to 10 MPa. Both vapor-liquid (VL) and liquid-liquid (LL) regions were observed. High pressure micrographs demonstrated that the heavy phase (a pitch phase) transitioned from a glass to a liquid state with increased temperature and feed propane content. Pressure-temperature and pressure-composition phase diagrams were constructed from saturation pressure and pitch phase onset data. The amount and composition of the heavy phase was also measured. Solvent-free pitch yields as high as 70 wt% of the bitumen were observed. Pseudoternary diagrams were also constructed to observe the partitioning of the species between the phases. Finally, the ability of a cubic equation-of-state with two forms of mixing rules were explored to model the data. The results can be used in the design of in situ and surface processes involving the addition of propane to bitumen.

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“…Literature reviews typically report the effect of phase equilibrium on CO 2 miscible displacement. Most of them emphasize the influence of fluid characterization on the prediction of multiphase regions or on the determination of phase boundaries for CO 2 ‐oil mixtures . In a different way, Hu et al plotted a line corresponding to experimental onset asphaltene precipitation in a CO 2 ‐oil mixture phase diagram but have not given the proper emphasis.…”

Section: Introductionmentioning

confidence: 99%

CO₂‐oil saturation pressure and onset asphaltene precipitation

et al. 2015

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Partial miscible flooding using CO2 injection has been shown to be a promising method for enhanced oil recovery, but this injection could result in asphaltene precipitation, which clogs the reservoir and production equipment. Therefore, an important parameter to be monitored is the onset of asphaltene precipitation. The efficient displacement of oil by CO2 depends on a variety of factors, including phase behaviour of CO2/crude‐oil mixtures that requires an accurate description of the CO2‐oil mixture bubble pressure. Observing bubble pressure behaviour, it is possible to exactly determine the CO2 molar fraction for onset asphaltene precipitation, which is expected to occur when the selected injection pressure is equal to the bubble pressure at the same CO2 molar fraction. However, assessment of oil characterization relating CO2‐oil mixture bubble pressure and onset asphaltene precipitation has not been found in the literature and should be properly addressed. In this work, we employed the Soave‐Redlich‐Kwong equation of state and used CO2‐oil mixture bubble pressure experimental data from literature to show that the accuracy of onset asphaltene precipitation is quite affected by the binary interaction parameter between methane and C7+ fractions, and the density of this heavy fraction.

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Measurement and modeling of the phase behavior of solvent diluted bitumens

Cited by 55 publications

References 53 publications

Viscosity Prediction for Solvent-Diluted Live Bitumen and Heavy Oil at Temperatures Up to 175-deg-C

Viscosity Prediction for Solvent-Diluted Live Bitumen and Heavy Oil at Temperatures Up to 175-deg-C

The Phase Behavior of Heavy Oil and Propane Mixtures

CO₂‐oil saturation pressure and onset asphaltene precipitation

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Measurement and modeling of the phase behavior of solvent diluted bitumens

Cited by 55 publications

References 53 publications

Viscosity Prediction for Solvent-Diluted Live Bitumen and Heavy Oil at Temperatures Up to 175-deg-C

Viscosity Prediction for Solvent-Diluted Live Bitumen and Heavy Oil at Temperatures Up to 175-deg-C

The Phase Behavior of Heavy Oil and Propane Mixtures

CO2‐oil saturation pressure and onset asphaltene precipitation

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Product

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CO₂‐oil saturation pressure and onset asphaltene precipitation