Predicting the Viscosity of Hydrocarbon Mixtures and Diluted Heavy Oils Using the Expanded Fluid Model

Ramos-Pallares, F.; Schoeggl, F. F.; Taylor, Shawn D.; Satyro, Marco A.; Yarranton, Harvey W.

doi:10.1021/acs.energyfuels.5b01951

Cited by 32 publications

(27 citation statements)

References 38 publications

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“…The SARA assays were measured following the modified ASTM D4124 method; the details are presented elsewhere . The specific gravity and molecular weight of the samples in Table were measured as described elsewhere , using a calibrated Anton Paar DMA 4500M oscillating U-tube density meter and a Jupiter model 833 vapor pressure osmometer, respectively. The precipitants used were n -pentane (purity of >98%) and n -heptane (purity of >99%) obtained from VWR.…”

Section: Methodsmentioning

confidence: 99%

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Extending the Modified Regular Solution Model To Predict Component Partitioning to the Asphaltene-Rich Phase

Ramos-Pallares

Yarranton

2019

Energy Fuels

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The modified regular solution (MRS) model is an activity coefficient approach previously developed to predict the onset and amount of asphaltene precipitation from n-paraffin-diluted crude oils. The activity coefficients in this model are determined from an enthalpic contribution based on the regular solution theory and a Flory–Huggins (configurational) entropic contribution. The inputs are the molar volume and solubility parameter of the crude oil pseudo-components, which are defined on the basis of the saturate, aromatic, resin, and asphaltene (SARA) fractions; however, only asphaltenes and resins are free to partition between the two phases. Hence, the model cannot predict the amount and composition of the heavy asphaltene-rich phase. In this study, the MRS model was updated to account for the partitioning of all components based on phase equilibrium data from a Western Canada bitumen mixed with n-pentane and n-heptane at ambient conditions. To match the measured phase compositions, the entropic contribution in the solvent-rich phase was set to the Flory–Huggins term and the contribution from the asphaltene-rich phase was set to zero. An approach to predict the solubility parameters and density of the pseudo-components at other temperatures and pressures was also proposed. The model was tested on a data set containing phase mass and phase compositions of a Western Canada bitumen mixed with n-heptane, n-pentane, n-butane, and propane at temperatures from 20 to 250 °C and pressures up to 13 MPa. The average absolute deviations in the phase mass and compositions were 7 and 12 wt %, respectively. The maximum deviations were found for the asphaltene-rich phase compositions. The model was also tested on a data set of asphaltene yields from oils from different disparate geographical locations at temperatures from 0 to 50 °C at 0.1 MPa. The average absolute deviation was 1 wt %.

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Section: Methodsmentioning

confidence: 99%

“…This data set was used to test the correlations for the prediction of the high temperature and pressure density of SARA fractions. It consists of the density data for the WC-B-A3 bitumen, previously reported by Ramos-Pallares et al, at temperatures from 25 to 175 °C and pressures up to 10 MPa.…”

Section: Data Collected In This Study and Organization Of Data Setsmentioning

confidence: 99%

Extending the Modified Regular Solution Model To Predict Component Partitioning to the Asphaltene-Rich Phase

Ramos-Pallares

Yarranton

2019

Energy Fuels

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“…The mixture density was determined from known component densities using a regular solution mixing rule (zero excess volume of mixing). The mixture viscosities were determined from the expanded fluid viscosity model fitted to known viscosity data . The diffusivities were determined from a correlation to the mixture viscosity from Grimaldos et al Details are provided in the Supporting Information.…”

Section: Gravity Drainage Modelmentioning

confidence: 99%

Investigation of Mechanisms for Gravity Drainage of Heavy Oil and Solvent Mixtures in a Hele-Shaw Cell

et al. 2020

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One reason it is challenging to predict oil recovery rates from solvent-based heavy oil recovery methods is that the interplay of the mass transfer and convective flow mechanisms is not well understood. An apparatus was designed and commissioned to investigate these mechanisms in a controllable flow geometry. The apparatus consisted of a Hele-Shaw cell (parallel glass plates) that was partially filled with bitumen and rotated to set a target initial slope of the bitumen layer. Toluene was fed at the top of the bitumen at a constant volumetric flow rate. The flow rate, composition, and properties of the drained liquid were measured over time, and photographs of the bitumen profile were taken periodically. The measurements were performed at ambient conditions at injection flow rates from 0.1 to 2 cm3/min, gap widths of 0.5 and 1 mm, and initial angles of inclination between 30 and 45°. The data were modeled with a two-dimensional numerical model in which the fluid was divided into columns, each with a solvent (drainage) layer and a bitumen layer. The following recovery mechanisms were identified: (1) diffusion of bitumen into the drainage layer represented with Fick’s Law, (2) open duct flow of the drainage layer represented as a falling film, and (3) flow of the bitumen phase settling under its own weight. The model with a single fixed tuning parameter matched all of the bitumen production rates with an average deviation of 7.4%.

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“…Pipeline requirements, while slightly varying, are typically a minimum acceptable viscosity of 350 cSt and a maximum acceptable density of 940 kg m −3 ( • API gravity = 19) at 15.6 • C [18]. Therefore, the bitumen, a near solid substance at ambient conditions (viscosity > 200,000 cSt), must be mixed with sufficient amounts of diluent, typically 30 vol.%, in order to meet pipeline specifications [6,7,19]. This practice imposes a large economic strain on the cost of bitumen recovery, and increases the total cost of a barrel of bitumen by 20% [20,21].…”

Section: Introductionmentioning

confidence: 99%

Partial Upgrading of Athabasca Bitumen Using Thermal Cracking

Kaminski

Husein

2019

Catalysts

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The current industry practice is to mix bitumen with a diluent in order to reduce its viscosity before it can be pumped to refineries and upgraders. The recovery of the diluent and its recycling to the producers, on the other hand, pose major environmental and economic concerns. Hence, onsite partial upgrading of the extracted bitumen to pipeline specifications presents an attractive alternative. In this work, thermal cracking of Athabasca bitumen was carried out in an autoclave at 400 °C, 420 °C and 440 °C in presence and absence of drill cuttings catalyst. At 400 °C, despite no coke formation, the reduction in viscosity was insufficient, whereas at 440 °C, the coke yield was significant, ~20 wt.%. A balance between yield and viscosity was found at 420 °C, with 88 ± 5 wt.% liquid, ~5 wt.% coke and a liquid viscosity and °API gravity of 60 ± 20 cSt and 23 ± 3, respectively. Additionally, the sulfur content and the Conradson carbon residue were reduced by 25% and 10%, respectively. The catalytic thermal cracking at 420 °C further improved the quality of the liquid product to 40 ± 6 cSt and 25 ± 2 °API gravity, however at slightly lower liquid yield of 86 ± 6 wt.%. Both catalytic and non-catalytic cracking provide a stable liquid product, which by far exceeds pipeline standards. Although small relative to the energy required for upgrading in general, the pumping energy requirement for the partially upgraded bitumen was 3 times lower than that for diluted bitumen. Lastly, a 5-lump, 6-reaction, kinetic model developed earlier by our group successfully predicted the conversion of the bitumen to the different cuts.

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Predicting the Viscosity of Hydrocarbon Mixtures and Diluted Heavy Oils Using the Expanded Fluid Model

Cited by 32 publications

References 38 publications

Extending the Modified Regular Solution Model To Predict Component Partitioning to the Asphaltene-Rich Phase

Extending the Modified Regular Solution Model To Predict Component Partitioning to the Asphaltene-Rich Phase

Investigation of Mechanisms for Gravity Drainage of Heavy Oil and Solvent Mixtures in a Hele-Shaw Cell

Partial Upgrading of Athabasca Bitumen Using Thermal Cracking

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