Use of real crude oil fractions to describe the high pressure phase behavior of crude oil in carbon dioxide

Lucas, Marcos A.; Borges, Gustavo R.; Rocha, Inaura Carolina Carneiro da; Santos, Alexandre F.; Franceschi, Elton; Dariva, Cláudio

doi:10.1016/j.supflu.2016.08.004

Cited by 16 publications

(6 citation statements)

References 17 publications

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“…The observed phases are plotted in the temperature–density ( T –ρ) phase diagram for pure CO 2 for fluid systems 1–5 (Figure ) and indicate the change from a single to a two-phase system for increasing mixture density (ρ M ). The choice of representing the system in T –ρ was because in a T – P phase diagram the two-phase region would only be a line, according to the Gibbs phase rule and the three-phase regions in similar diagrams for CO 2 -rich oil mixtures are also expected to be very narrow. ,, Thus, the T –ρ diagram makes the numerical–experimental comparison easier to follow since the two- and three-phase regions are wider compared to a temperature–pressure phase diagram. In Figure , the supercritical (SC) region is highlighted as well as its gas-like and liquid-like regions, which are divided according to the critical properties-based phase identification criteria of Multiflash.…”

Section: Results and Discussionmentioning

confidence: 99%

“…24 An example is the "HiSep" technology, 25 where the aim is to compress the highdensity CO 2 -rich phase back into the reservoir, thus alleviating the processing requirements topside. Some experimental studies have been performed under static conditions, 12,26,27 but a more detailed understanding of such systems across a range of compositions and thermodynamic states is needed. According to Alzobaidi et al, 28 only a few studies have looked at stabilization of CO 2 −oil dispersions, as it is not expected that there are surfactants that can stabilize that interface.…”

Section: Introductionmentioning

confidence: 99%

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Phase Transitions and Separation Time Scales of CO₂–Crude Oil Fluid Systems: Wheel Flow Loop Experiments and Modeling

Fossen

Pasqualette²,

Carneiro³

2020

Energy Fuels

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Presented here is experimental and theoretical work on phase transitions and separation time scales for CO2–crude oil mixtures with CO2 content ranging from pure to 79 mol %. The experimental work was performed using the wheel flow loop located at the SINTEF Multiphase Flow Laboratory. Under constant volume conditions, phase transition temperature and pressures were determined, as well as the volume fractions of the respective phases. The results indicated good agreement between the experimentally determined phase transitions and the phase diagrams predicted by the thermodynamic model. It was shown that the measured torque was sufficient to determine the pressure–temperature conditions of the phase transitions. Furthermore, separation times were measured for both oil-in-CO2 and CO2-in-oil in a range of conditions for the respective fluid systems. Results showed that the separation times were considerably shorter for the CO2 continuous fluid system compared to oil continuous. Moreover, a comparison of Weber numbers for the various test conditions indicated that the drop sizes influence the overall separation time, which is affected by settling and coalescence processes. Finally, this study showed that the wheel flow loop is well suited for the study of CO2-rich systems for determination of volume fractions of phases, phase transitions, and transport and separation.

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Section: Results and Discussionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Phase Transitions and Separation Time Scales of CO₂–Crude Oil Fluid Systems: Wheel Flow Loop Experiments and Modeling

Fossen

Pasqualette²,

Carneiro³

2020

Energy Fuels

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“…The experimental apparatus and procedure were based on the static synthetic method, whose use is widely documented in the literature. − A diagram of the experimental apparatus used in this work for phase equilibrium measurements is shown in Figure .…”

Section: Methodsmentioning

confidence: 99%

Phase Behavior for the System Carbon Dioxide + p-Nitrobenzaldehyde: Experimental and Modeling

et al. 2019

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The experimental study and thermodynamic modeling of the phase behavior of pressurized reactional systems allows the optimization of several unit operations involved in the process of product formation. In this work, experimental data of phase equilibria for the CO 2 + p-nitrobenzaldheyde binary system were obtained through the static synthetic method. The range of temperature, pressure, and p-nitrobenzaldehyde molar fraction investigated were 281−353 K, 6.5−25.0 MPa, and 2.638 × 10 −3 to 5.903 × 10 −3 , respectively. A model previously developed to describe asymmetric mixtures presenting fluid and solid phases was applied to describe the phase behavior of the system. This model uses the Peng−Robinson equation of state (PR-EoS) to describe the properties of the fluid phases and an expression for the fugacity of p-nitrobenzaldehyde as a pure solid for the solid phase. Different model parametrization strategies were studied, and complete isopleths were calculated considering the fluid−fluid, solid−fluid, and solid−fluid−fluid phase equilibria over wide ranges of temperature and pressure. The experimental results showed nonmonotonic (local minimum) solid−fluid phase behavior for all mixture compositions investigated. The model employed and the parametrization strategies were able to describe the experimentally observed phase behavior.

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“…The CO 2 content is expected to further increase along production time due to the use of WAG, a secondary recovery method meant to increase oil recovery (Fraga et al, 2015). Experimental studies indicate that the presence of a high CO 2 fraction in the crude oil can impact the phase equilibria behavior significantly (Lucas et al, 2016).…”

Section: Introductionmentioning

confidence: 99%

Evaluation of the Solution Gas-Oil Ratio Correlation Proposed by Lasater Applied to Oils With High Co2 and High Gor

Fulchignoni¹,

Almeida²,

Fonseca³

2021

BJPG

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The application of any empirical correlation is recommended only within its range of validity. Nonetheless, the indiscriminate usage of black oil correlations for ﬂuid modeling happens frequently. This work evaluates Lasater’s (1958) correlation for the solution gas-oil ratio (Rs) ﬂuid property speciﬁcally for oils with high CO2 content and high GOR. The correlation results are compared to experimental data, and high prediction errors are observed. Finally, the inﬂuence of the Rs prediction error on the ﬂow simulation is assessed.

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Use of real crude oil fractions to describe the high pressure phase behavior of crude oil in carbon dioxide

Cited by 16 publications

References 17 publications

Phase Transitions and Separation Time Scales of CO₂–Crude Oil Fluid Systems: Wheel Flow Loop Experiments and Modeling

Phase Transitions and Separation Time Scales of CO₂–Crude Oil Fluid Systems: Wheel Flow Loop Experiments and Modeling

Phase Behavior for the System Carbon Dioxide + p-Nitrobenzaldehyde: Experimental and Modeling

Evaluation of the Solution Gas-Oil Ratio Correlation Proposed by Lasater Applied to Oils With High Co2 and High Gor

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Use of real crude oil fractions to describe the high pressure phase behavior of crude oil in carbon dioxide

Cited by 16 publications

References 17 publications

Phase Transitions and Separation Time Scales of CO2–Crude Oil Fluid Systems: Wheel Flow Loop Experiments and Modeling

Phase Transitions and Separation Time Scales of CO2–Crude Oil Fluid Systems: Wheel Flow Loop Experiments and Modeling

Phase Behavior for the System Carbon Dioxide + p-Nitrobenzaldehyde: Experimental and Modeling

Evaluation of the Solution Gas-Oil Ratio Correlation Proposed by Lasater Applied to Oils With High Co2 and High Gor

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Product

Resources

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Phase Transitions and Separation Time Scales of CO₂–Crude Oil Fluid Systems: Wheel Flow Loop Experiments and Modeling

Phase Transitions and Separation Time Scales of CO₂–Crude Oil Fluid Systems: Wheel Flow Loop Experiments and Modeling