An investigation on the applicability of Parachor model for the prediction of MMP using five equations of state

Ashrafizadeh, Seyed Nezameddin; Ghasrodashti, A. Ameri

doi:10.1016/j.cherd.2010.10.015

Cited by 22 publications

(10 citation statements)

References 23 publications

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“…This method could be used to measure the MMP for vaporing gas drives, but less accurate for condensing gas drives by falling-drop experiments. More recently, vanishing interfacial tension (VIT) method is proposed as a successful laboratorial approach to evaluate fluid-fluid miscibility (Rao 1997;Rao and Lee 2003;Ayirala 2005;Ayirala and Rao 2006;Orr and Jessen 2007;Ashrafizadeh and Ghasrodashti 2011). It relies on the concept that interfacial tension (IFT) reduces to zero when fluid-fluid or gas-fluid phases approach the point of miscibility.…”

Section: Introductionmentioning

confidence: 99%

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Application of PC-SAFT Equation of State for CO2 Minimum Miscibility Pressure Prediction in Nanopores

Wang

Chen

2016

SPE Improved Oil Recovery Conference

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CO 2 miscible injection is generally one of the most efficient enhanced oil recovery (EOR) methods and widely used in the conventional oil reservoirs. The applicability of CO 2 EOR technology for unlocking the resources from unconventional tight and shale formations and the mechanisms of miscible flooding in these reservoirs still remain unclear. An important parameter used to evaluate the feasibility of CO 2 miscible flooding is the minimum miscibility pressure (MMP). Even though experimental approaches, empirical correlations and theoretical methods have performed well in measuring or predicting MMP between CO 2 and crude oil in conventional reservoirs, they may not be suitable for unconventional formations as phase behavior and MMP can be significantly affected by confinement effect in small pores (e.g., nanopores) in such formations.In this study, a new MMP prediction model based on the modified Parachor Model associated with the Perturbed-Chain Statistical Associating Fluid Theory (PC-SAFT) is developed to determine CO 2 MMP both in the bulk phase and nanopores. The Parachor Model is modified to account for the confinement effect of nanopore walls on the equilibrium interfacial tension (IFT). The Equilibrium IFT reduction in nanopores is related to a temperature-dependent and slit pore width-dependent modification term. The parameters of the new Parachor Model are determined by matching the vapor-liquid surface tension values for CH 4 , C 2 H 6 , C 3 H 8 , n-C 4 H 10 , and n-C 8 H 18 in nanopores, respectively. The prediction ability of the new model is verified by comparing the predicted MMP in the bulk phase with the results of other theoretical approaches and slim-tube experimental data. Finally, the new model is applied to estimate the MMP between Bakken oil and CO 2 stream. The effect of temperature, slit pore width, and impure components in the injected CO 2 on the MMP are also studied. The newly developed model successfully reproduces MMP in bulk phase as compared with both other methods and experimental data. The overall average absolute relative deviation (AARD) for MMP is within 8 %. The calculated equilibrium IFT for liquid-vapor phase has a good agreement with molecular simulation results. For Bakken oil-CO 2 system, if the slit pore width is larger than 10 nm, MMP is independent on pore width; otherwise, it decreases significantly with the decrease of the pore width. If pore width decreases to 3 nm, 67.5 % decrease in the IFT is observed and 23.5% reduction is achieved for MMP between Bakken oil and CO 2 stream, indicating that it is easier to reach miscibility in nanopores, and CO 2 miscible flooding might be a promising enhanced oil recovery (EOR) technology for tight oil and shale oil reservoirs. Furthermore, MMP increases with an increase of temperature in bulk phase, whereas IFT and MMP decrease with an increase of temperature in nanopores.

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Section: Introductionmentioning

confidence: 99%

“…The most influential one among these models is Parachor IFT model. Ashrafizadeh and Ghasrodashti (2011) investigated the application of five cubic EoS models along with a Parachor Model to predict MMP. Even though the model can predict the MMP within an acceptable accuracy, it cannot be directly applied to unconventional reservoirs.…”

Section: Introductionmentioning

confidence: 99%

Application of PC-SAFT Equation of State for CO2 Minimum Miscibility Pressure Prediction in Nanopores

Wang

Chen

2016

SPE Improved Oil Recovery Conference

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“…All the experiments were performed at a constant temperature of 30°C. The first contact miscibility pressure between CO 2 and oil was determined using different correlations (Dehghani et al, 2008;Ashrafizadeh and Ameri Ghasrodashti, 2011) and compared with the results obtained from the CMG-WINPROP TM (Computer Modeling Group) and PVTsim phase behavior simulators. According to the results, the FCM pressure of the synthetic oil was 7000 kPa at 30°C.…”

Section: Methodsmentioning

confidence: 99%

Experimental and Numerical Investigation on the Performance of Gas Oil Gravity Drainage at Different Miscibility Conditions

Ghasrodashti

Farajzadeh

Suiçmez

et al. 2012

SPE Improved Oil Recovery Symposium

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Gas oil gravity drainage is an effective oil recovery process, which has been proven in the field. Under favorable conditions the displacement is stable and for the right surface tension combinations the residual oil saturation is low. In the absence of gas dissolution, the recovery after gas injection is usually low as a large amount of oil remains capillary trapped in the matrix blocks. However, when the main gas constitutes is soluble in the oil, the dissolution leads to mixing and interfacial tension (IFT) reduction, which cause gravity enhanced transfer between matrix and fracture. Therefore, a study of the mechanisms that control the interactions between fracture and matrix (e.g. capillarity, gravity, phase behavior and flow behavior) can help to optimize recovery. This paper concerns an experimental study to investigate whether gravity drainage is also an effective recovery process in fractured reservoirs. In this study, we describe six gas injection experiments conducted at different miscibility conditions, i.e., immiscible, developed miscible and first contact miscible (FCM), using CO 2 , nitrogen and flue gas. In addition, the impact of switching from an immiscible (Nitrogen, Flue gas) injection gas to non-equilibrium and fully miscible CO 2 injection is investigated. In one of the experiments, we study the effect of a permeability barrier on the recovery efficiency from the matrix block when CO 2 is injected in the fracture at immiscible and miscible conditions. Accurate modeling for the transfer between fracture and matrix is also essential for accurate recovery predictions. In this study, a numerical model is developed to perform compositional simulations of gas injection for different miscibility scenarios. Results revealed that ultimate oil recovery increases considerably once miscibility is reached. Miscibility can usually be achieved at high pressures only. High pressure gas injection has two disadvantages, viz., (1) one may need a larger mass of gas to fill the pore space from where the oil is recovered and (2) the density of injected gas increases significantly, which reduces the density difference between the gas and oil. This leads to less effective gravity mediated recovery. Even if the impermeable layer impairs the performance of the gas oil gravity drainage (GOGD) process for immiscible gas injection, it improves the recoveries for first contact miscible gas injection.

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“…From the petroleum industry point of view, PR and SRK EOSs are the most popular ones compared with two or more parametric equations. Despite the simplicity and easy application of these two types of equations, they can provide comparable results with experimental data . Details of these EOSs are as follows:…”

Section: Theory/calculationmentioning

confidence: 99%

A simulation approach to achieve the best miscible enrichment in gas flooding and chemical injection process for enhanced oil recovery

Sardari

Movaghar

2017

Asia-Pacific J Chem Eng

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The effect of injected gas composition (as minimum miscible enrichment) on minimum miscibility pressure (MMP) and respective oil recovery has been studied through numerical slim tube simulation on a wide range of gas compositions. An initial comparative study on the performances of representative equations of state for predicting MMP in slim tube simulations has proven Peng–Robinson equation of state to provide results with better agreement with experimental data. Different injection scenarios are then designed to understand the effects of varying percentages of each component (like CO2) into the injected gas mixture on MMP. MMP decreased when the concentration of CO2 and intermediate components (C2–C6) increased. It was also found that when C7+ content in the injected gas increased, recovery factor decreased significantly. Further investigations on the effect of adding benzene, toluene, and xylene as chemicals into the injected gas (in slim tube simulations) also prove that addition of these aromatics can obviously improve oil recovery and decrease MMP and toluene gives the better results in comparison with the other ones. © 2017 Curtin University of Technology and John Wiley & Sons, Ltd.

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An investigation on the applicability of Parachor model for the prediction of MMP using five equations of state

Cited by 22 publications

References 23 publications

Application of PC-SAFT Equation of State for CO2 Minimum Miscibility Pressure Prediction in Nanopores

Application of PC-SAFT Equation of State for CO2 Minimum Miscibility Pressure Prediction in Nanopores

Experimental and Numerical Investigation on the Performance of Gas Oil Gravity Drainage at Different Miscibility Conditions

A simulation approach to achieve the best miscible enrichment in gas flooding and chemical injection process for enhanced oil recovery

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