Modeling of Pressure and Solution Gas for Chemical Floods

Roshanfekr, Meghdad; Johns, Russell T.; Delshad, Mojdeh; Pope, Gary A.

doi:10.2118/147473-ms

Cited by 6 publications

(8 citation statements)

References 23 publications

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“…The EoS models were first tuned to solubilization ratios from a salinity scan at atmospheric pressure as measured by Roshanfekr et al (2013). Figure 1 compares the tuned results using Hand's model and the HLD-NAC model parameters to the experimental data (Roshanfekr et al 2013) at an overall concentration of 2.0 volume % surfactant, WORϭ1, and temperature of 77sF.…”

Section: Resultsmentioning

confidence: 99%

“…Figure 1 compares the tuned results using Hand's model and the HLD-NAC model parameters to the experimental data (Roshanfekr et al 2013) at an overall concentration of 2.0 volume % surfactant, WORϭ1, and temperature of 77sF. Tuning the salinity scan with the new EoS requires adjustment using only one parameter, while five parameters are needed for Hand's model.…”

Section: Resultsmentioning

confidence: 99%

“…Polymer is commonly added to the injection fluid to keep the front stable and improve sweep efficiency (Green et al 2011). IFT is correlated to phase compositions (Huh 1979) and the microemulsion phase behavior is a function of surfactant properties, temperature, brine salinity, oil composition and pressure (Roshanfekr et al 2013, Roshanfekr andJohns 2011). These parameters can vary significantly in a SP flood throughout the reservoir.…”

Section: Introductionmentioning

confidence: 99%

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Simulation of Surfactant-Polymer Floods with a Novel Microemulsion Equation of State

Khorsandi

Qiao

Johns

et al. 2016

SPE Improved Oil Recovery Conference

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Reservoir simulation is a valuable tool for assessing the potential success of enhanced recovery processes. Current chemical flooding reservoir simulators, however, use Hand's model to describe surfactant-oilbrine systems even though Hand's model is not predictive, and can fit only a limited data set. Hand's model requires the tuning of multiple empirical parameters using experimental data that usually consist of salinity scans at constant reservoir temperature and atmospheric pressure. Given experimental data supporting the change in microemulsion phase behavior with key formulation properties (e.g. temperature, pressure, salinity, EACN, and overall composition), there is a need for an improved model that can capture changes in these relevant parameters at the reservoir scale. The recent EOS proposed for microemulsion phase behavior Johns 2014, 2016), which is based partially on the hydrophyllic-lypophyllic difference and net average curvature model (HLD-NAC, Acosta et al. 2003), has been supported by numerous experimental data and provides a more mechanistic phase behavior model than the Hand's model.In this paper, the EOS model with the extension to two-phase regions is incorporated for the first time into the chemical flooding simulators, UTCHEM, and our new in-house simulator PennSim. Hand's model is only used for comparison purposes, and is no longer needed even for flash calculations in the type II-and type IIϩ regions. The results show excellent agreement between UTCHEM and PennSim both in composition space and for composition/saturation profiles. Further, the HLD-NAC based EOS model and Hand's models are fitted to the same experimental data and the results of these simulations are nearly identical when variations of salinity, pressure and temperature are small. For large gradients, the results of the physics-based EOS deviates from Hand's model, and shows it is critical to incorporate these gradients in recovery predictions at large scale.

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Section: Resultsmentioning

confidence: 99%

Section: Resultsmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

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Simulation of Surfactant-Polymer Floods with a Novel Microemulsion Equation of State

Khorsandi

Qiao

Johns

et al. 2016

SPE Improved Oil Recovery Conference

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“…Several groups recently modeled live oil behavior including reservoir P and T conditions and gas solution [10,11,13,14,22]. This formulation of Equation (3) has been revisited by Trouillaud et al who expressed the gas molar fraction in terms of ratio of molar gas and oil volumes, and gas to oil ratio [13].…”

Section: Theoretical Sectionmentioning

confidence: 99%

“…chemistry of surfactants, types of salts, TDS -the amount of total dissolved solids -etc.). Investigations of gas dissolution, pressure and temperature effects on the {brine/formulation/ live oil} microemulsion have already been performed indicating competing effects [10][11][12][13]. Several recent works proposed reviews of these competing effects, for instance when increasing the gas to oil ratio and/or the pressure [10,13,14].…”

Section: Introductionmentioning

confidence: 99%

Equivalent Alkane Carbon Number of Live Crude Oil: A Predictive Model Based on Thermodynamics

Creton

Mougin

2016

Oil Gas Sci. Technol. – Rev. IFP Energies nouvelles

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-We took advantage of recently published works and new experimental data to propose a model for the prediction of the Equivalent Alkane Carbon Number of live crude oil (EACNlo) for EOR processes. The model necessitates the a priori knowledge of reservoir pressure and temperature conditions as well as the initial gas to oil ratio. Additionally, some required volumetric properties for hydrocarbons were predicted using an equation of state. The model has been validated both on our own experimental data and data from the literature. These various case studies cover broad ranges of conditions in terms of API gravity index, gas to oil ratio, reservoir pressure and temperature, and composition of representative gas. The predicted EACNlo values reasonably agree with experimental EACN values, i.e. determined by comparison with salinity scans for a series of n-alkanes from nC 8 to nC 18 . The model has been used to generate high pressure high temperature data, showing competing effects of the gas to oil ratio, pressure and temperature. The proposed model allows to strongly narrow down the spectrum of possibilities in terms of EACNlo values, and thus a more rational use of equipments.Résumé -Développement d'un modèle pour prédire l'alcane équivalent d'une huile vive -En se basant sur de récents travaux de la littérature ainsi que sur de nouvelles données expérimentales, nous proposons un modèle permettant de prédire l'EACNlo (Equivalent Alkane Carbon Number of live crude oil) -alcane équivalent d'une huile vive (pétrole brut contenant des gaz dissous) -dans des contextes de recherche de tensioactifs pour des activités EOR. Pour mettre en oeuvre ce modèle, il faut s'assurer de la connaissance des conditions de pression et de température dans le réservoir et du rapport gaz sur huile. En outre, des propriétés volumétriques d'hydrocarbures nécessaires pour alimenter le modèle, sont estimées par l'utilisation d'équations d'état. La validation de notre modèle a été réalisée à partir de données expérimentales de la littérature et nos propres données obtenues pour des pétroles bruts. Ces différents cas d'études couvrent de larges gammes en termes de degrés API, de rapports gaz sur huile, de pressions et températures en condition de fond (réservoir) et de compositions pour le gaz représentatif. L'utilisation du modèle conduit à des valeurs d'EACNlo en accord avec les valeurs expérimentales, i.e. obtenues par comparaisons avec des analyses de salinités sur des séries d'alcanes linéaires de nC 8 à nC 18 . Le modèle a ensuite été utilisé pour générer des prédictions et ainsi étudier l'impact sur les prédictions des conditions de pressions et de températures et de la nature du gaz. Le modèle permet de restreindre la gamme de valeurs d'EACNlo et ainsi une meilleure utilisation des équipements expérimentaux.

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Robust Flash Calculation Algorithm for Microemulsion Phase Behavior

Khorsandi

Johns

2016

J Surfact & Detergents

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The HLD‐NAC model was recently modified to match and predict microemulsion phase behavior experimental data for Winsor type III regions. Until now, the HLD‐NAC model could not generate realistic phase behavior for type II− and type II+ two‐phase regions, leading to significant saturation and composition discontinuities when catastrophe theory is applied. These discontinuities lead to significant failures in modeling surfactant applications. We modify the HLD‐NAC equations to ensure consistency over the entire composition space including type II− and II+ regions. A robust and efficient algorithm is developed that always converges and provides continuous estimates with any formation variable of tie lines and triangles for all Winsor types. Discontinuities are eliminated and limiting tie lines near critical points are determined analytically. The tuning procedure is demonstrated using several sets of experimental data. Excellent predictability of tie lines and tie triangles, and solubilization ratios are shown.

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Modeling of Pressure and Solution Gas for Chemical Floods

Cited by 6 publications

References 23 publications

Simulation of Surfactant-Polymer Floods with a Novel Microemulsion Equation of State

Simulation of Surfactant-Polymer Floods with a Novel Microemulsion Equation of State

Equivalent Alkane Carbon Number of Live Crude Oil: A Predictive Model Based on Thermodynamics

Robust Flash Calculation Algorithm for Microemulsion Phase Behavior

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