Experimental and simulation study of surfactant flooding using a combined surfactant system for enhanced oil recovery

Pannu, Sombir; Phukan, Ranjan; Tiwari, Pankaj

doi:10.1080/10916466.2022.2052089

Cited by 4 publications

(3 citation statements)

References 13 publications

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“…Researchers continue to explore and optimize the use of different nanoparticles to maximize their efficiency in enhancing oil recovery. Various researchers have reported experimental and modeling studies for improving the EOR technology 12, 15, 22, 26. Numerical computations have helped to explore the potential of nano‐flooding.…”

Section: Introductionmentioning

confidence: 99%

Modeling of Enhanced Oil Recovery Using Nanofluid

Godiwal,

Mandal

2023

Chem Eng & Technol

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Nanofluid flow in porous media was modeled for enhanced oil recovery. The effects of parameters such as the matrix porosity, nanoparticles, and diffusion coefficients on the oil recovery factor were reported. The velocity, temperature, and oil saturation contours were examined. The study showed that the oil recovery and heat transfer were enhanced by the use of a nanofluid. A 30 % and 10 % increase in the oil recovery factor were found using the Al2O3‐water nanofluid as compared to water and the polystyrene‐water nanofluid, respectively. The temperature in the porous matrix was significantly reduced by the Al2O3‐water nanofluid as compared to the polystyrene‐water nanofluid and water. In the future, this model could be used to screen the performance of other chemical agents and eventually lead to a more efficient and sustainable oil extraction process.

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Section: Introductionmentioning

confidence: 99%

Modeling of Enhanced Oil Recovery Using Nanofluid

Godiwal,

Mandal

2023

Chem Eng & Technol

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“…Injecting chemicals into the reservoir activates several liquid–liquid and solid–liquid interactions. The liquid–liquid interaction can improve the capillary number by reducing surface and interfacial tension (IFT), thereby enhancing oil recovery (Pannu et al, 2022). Similarly, solid–liquid interactions can induce favorable wettability alterations, further promoting higher oil recovery (Phukan & Saha, 2022).…”

Section: Introductionmentioning

confidence: 99%

Adsorption behavior of surfactants on sandstone reservoir rocks with carbonate cements and its influence on wettability alteration

Phukan,

Saha,

Mazumdar

2023

J Surfact & Detergents

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This study investigates the adsorption behaviors of surfactants in sandstone reservoir rocks containing various amounts of carbonate cement/minerals and their impact on wettability alteration under low‐salinity conditions. Two types of rock samples from sandstone reservoirs of Assam oilfields in India are selected based on XRD results. These rock types are (i) high carbonate cement (HCC) core sample with higher carbonate cement (calcite 5.6% and dolomite 4.0%), and (ii) low carbonate cement (LCC) core sample with lower carbonate cement (calcite = 0.5% and dolomite 0%). The study reveals that the mineralogy of sandstone reservoir rocks especially the carbonate minerals affects the brine‐rock interactions including wettability alternation and surfactant adsorption. Notable differences (2° to 8°) in contact angles for the two rock types at different salinities revealed that carbonate cement in sandstone thus impacts brine‐rock interactions. Further, low salinity surfactant (LSS) could positively alter the wettability of both rock types to water‐wet conditions (contact angle <60°). The most favorable wettability alterations (up to 30°) were achieved with cationic LSS solutions for both core types. Using LSS solutions also reduced the adsorption of anionic surfactant by around 40% and 33% for HCC and LCC rock samples, respectively. The study's novelty emanates from investigating the impact of sandstone reservoir rock mineralogy with varying amounts of carbonate cements on the adsorption behavior of surfactants under low‐salinity conditions. Moreover, this study provides a better understanding of the interrelationship existing between the degree of wettability alteration and the amount of surfactant adsorbed by sandstone rocks.

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“…In recent decades, surfactant flooding has drawn increasing attention due to its merits, such as its interfacial property. Many studies have been conducted on both the physical properties of surfactant solution [1][2][3][4][5][6] and the numerical simulation of the flow of surfactant flooding [7,8]. A problem in these studies is that the present numerical simulation of surfactant flooding is not perfect, as the theoretical description of the flow property of surfactant solution still has defects.…”

Section: Introductionmentioning

confidence: 99%

Prediction of the Viscoelastic Properties of a Cetyl Pyridinium Chloride/Sodium Salicylate Micellar Solution: (II) Prediction of the Step Rate Experiments

Huang

2022

Polymers

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The reliable viscoelastic characterization and prediction of micellar solution is still required in industrial applications of the solution, e.g., in surfactant flooding and pharmaceuticals. Based on the recent theoretical characterization of the viscoelastic properties of a cetyl pyridinium chloride/sodium salicylate (CPyCl/NaSal) wormlike micellar solution with a structuralized constitutive model in the work published in 2022, the present work predicted five groups of transient shear viscoelasticities of the solution experimentally obtained in 2010, which include the first normal stress difference (N1) versus time curve in the start-up experiment, the shear stress (τ12) in the start-up experiment, τ12 in the long-term start-up experiment, the stress relaxation upon cessation of steady shear flow, and the transient N1/τ12 in the step strain experiment. The study findings clearly show an improvement in the predictions of the viscoelastic properties of the micellar solution compared with those predicted previously. For example, the experimental N1/τ12 is 9 at the strain of 9 in the step strain experiment, and the corresponding previous and present predictions are 2.47 and 8.45, respectively.

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Experimental and simulation study of surfactant flooding using a combined surfactant system for enhanced oil recovery

Cited by 4 publications

References 13 publications

Modeling of Enhanced Oil Recovery Using Nanofluid

Modeling of Enhanced Oil Recovery Using Nanofluid

Adsorption behavior of surfactants on sandstone reservoir rocks with carbonate cements and its influence on wettability alteration

Prediction of the Viscoelastic Properties of a Cetyl Pyridinium Chloride/Sodium Salicylate Micellar Solution: (II) Prediction of the Step Rate Experiments

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