Investigation of <mml:math xmlns:mml="http://www.w3.org/1998/Math/MathML" id="M1"><mml:mrow><mml:msub><mml:mrow><mml:mtext>CO</mml:mtext></mml:mrow><mml:mtext mathvariant="bold">2</mml:mtext></mml:msub></mml:mrow></mml:math> Enhanced Oil Recovery Using Dimensionless Groups in Wettability Modified Chalk and Sandstone Rocks

Tabrizy, Vahid Alipour

doi:10.1155/2014/430309

Cited by 6 publications

(3 citation statements)

References 27 publications

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“…It should be noted that in the case of C p = 1000 ppm, average ganglia size increases at the lowest value of Ca, and S ro slightly decreases at intermediate values of q, which is not the case for the other concentrations. This behaviour has been reported before [9,56,57], and requires further investigation. The results presented in Fig.…”

Section: Interface Displacementsupporting

confidence: 69%

Effects of shear-thinning fluids on residual oil formation in microfluidic pore networks

Castro

Oostrom

Shokri

2016

Journal of Colloid and Interface Science

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Two-phase immiscible displacement in porous media is controlled by capillary and viscous forces when gravitational effects are negligible. The relative importance of these forces is quantified through the dimensionless capillary number Ca and the viscosity ratio M between fluid phases. When the displacing fluid is Newtonian, the effects of Ca and M on the displacement patterns can be evaluated independently. However, when the injecting fluids exhibit shear-thinning viscosity behaviour the values of M and Ca are interdependent. Under these conditions, the effects on phase entrapment and the general displacement dynamics cannot be dissociated. In the particular case of shear-thinning aqueous polymer solutions, the degree of interdependence between M and Ca is determined by the polymer concentration. In this work, two-phase immiscible displacement experiments were performed in micromodels, using shear-thinning aqueous polymer solutions as displacing fluids, to investigate the effect of polymer concentration on the relationship between Ca and M, the recovery efficiency, and the size distribution of the trapped non-wetting fluid. Our results show that the differences in terms of magnitude and distribution of the trapped phase are related to the polymer concentration which influences the values of Ca and M.

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Section: Interface Displacementsupporting

confidence: 69%

Effects of shear-thinning fluids on residual oil formation in microfluidic pore networks

Castro

Oostrom

Shokri

2016

Journal of Colloid and Interface Science

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“…Correlations between the recovery factor and dimensionless groups hold importance in optimizing and predicting the performance of EOR methods. Capillary number, gravity number, bond number, Peclet number, and trapping number are the most common dimensionless numbers used in water flooding and EOR processes [27][28][29][30][31]. The dimensionless numbers can provide a basis for identifying flow regimes under gravity and viscous effects when they are used to evaluate the EOR processes in heterogeneous reservoirs.…”

Section: Introductionmentioning

confidence: 99%

“…where σ is the water-oil interfacial tension, µ w is the displacing phase viscosity, and v is the superficial velocity of the injectant. For greater inclusivity, the conventional capillary number is modified for sandstone and chalk cores to consider the pore structure represented by capillary bundles, relating it to porosity and permeability [31]. Recently, several dimensionless numbers have been introduced to study CO 2 flooding concerning the displacement mechanisms [32].…”

Section: Introductionmentioning

confidence: 99%

Performance Quantification of Enhanced Oil Recovery Methods in Fractured Reservoirs

2021

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The enhanced oil recovery mechanisms in fractured reservoirs are complex and not fully understood. It is technically challenging to quantify the related driving forces and their interaction in the matrix and fractures medium. Gravity and capillary forces play a leading role in the recovery process of fractured reservoirs. This study aims to quantify the performance of EOR methods in fractured reservoirs using dimensionless numbers. A systematic approach consisting of the design of experiments, simulations, and proxy-based optimization was used in this work. The effect of driving forces on oil recovery for water injection and several EOR processes such as gas injection, foam injection, water-alternating gas (WAG) injection, and foam-assisted water-alternating gas (FAWAG) injection was analyzed using dimensionless numbers and a surface response model. The results show that equilibrium between gravitational and viscous forces in fracture and capillary and gravity forces in matrix blocks determines oil recovery performance during EOR in fractured reservoirs. When capillary forces are dominant in gas injection, fluid exchange between fracture and matrix is low; consequently, the oil recovery is low. In foam-assisted water-alternating gas injection, gravity and capillary forces are in equilibrium conditions as several mechanisms are involved. The capillary forces dominate the water cycle, while gravitational forces govern the gas cycle due to the foam enhancement properties, which results in the highest oil recovery factor. Based on the performed sensitivity analysis of matrix–fracture interaction on the performance of the EOR processes, the foam and FAWAG injection methods were found to be more sensitive to permeability contrast, density, and matrix block highs than WAG injection.

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A new approach for predicting oil recovery factor during immiscible CO2 flooding in sandstones using dimensionless numbers

Zivar

Pourafshary

2019

J Petrol Explor Prod Technol

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CO 2 injection is one of the most promising techniques to enhance oil recovery. The most favorable properties of CO 2 made this method popular and it has been widely used since 1950. Experimentally, the effect of CO 2 injection on incremental oil recovery is widely measured by the core-flooding approach. An accurate estimation of the recovery factor is required to analyze the performance of the method to design the enhanced oil recovery method successfully. Hence, knowledge of the effects of different parameters on recovery is essential. Various reported experimental CO 2 core-flooding data for the immiscible condition in sandstones were analyzed to develop the parametric relationships affecting ultimate oil recovery using data analytics. Selected data support a wide range of porosity (10.8-37.2%), permeability (1-18000 mD), injection pressure (2.73-11.44 MPa), injection rate (0.1-1.0 cm 3 /min), and crude oil types, which enhance the methodology used to develop more comprehensive dimensionless numbers and correlations to predict the oil recovery. Series of new dimensionless numbers were defined and used for the study to develop a correlation for predicting oil recovery factor. Capillary number, relative radius, injection pressure ratio, and oil composition number are used as dimensionless numbers in our approach. The oil recovery prediction by the developed correlation was in agreement with the experimental data. The proposed correlation shows that capillary number is the most effective parameter when predicting oil recovery. List of symbolsN c Capillary number (dimensionless) R r Relative radius (dimensionless) MMP Minimum miscibility pressure (MPa) MCM Multi-contact miscibility OCN Oil composition number (dimensionless) PRF Predicted oil recovery factor (dimensionless) P i Injection pressure (MPa) P r Injection pressure ratio (dimensionless) g CO 2 viscosity (Pa s) V Darcy velocity (m/s) go Interfacial tension between oil and CO 2 (N/m) w C i Weight fraction of composition i (dimensionless) k Permeability (mD) ∅ Porosity (fraction)

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Investigation of CO2 Enhanced Oil Recovery Using Dimensionless Groups in Wettability Modified Chalk and Sandstone Rocks

Cited by 6 publications

References 27 publications

Effects of shear-thinning fluids on residual oil formation in microfluidic pore networks

Effects of shear-thinning fluids on residual oil formation in microfluidic pore networks

Performance Quantification of Enhanced Oil Recovery Methods in Fractured Reservoirs

A new approach for predicting oil recovery factor during immiscible CO2 flooding in sandstones using dimensionless numbers

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