Formulation of a combined low saline water and polymer flooding for enhanced oil recovery

Sarmah, Shilpi; Gogoi, Subrata Borgohain; Jagatheesan, Kumar; Hazarika, Kalpajit

doi:10.1080/01430750.2019.1683068

Cited by 9 publications

(6 citation statements)

References 18 publications

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“…Results indicate that for both the adsorbents the adsorption decreased when using alkalis with surfactant as reported by earlier researchers Sarmah et al (2019). Using surfactant, it followed the Freundlich isotherm while using SDS with alkali it followed Langmuir isotherm.…”

Section: Resultssupporting

confidence: 83%

“…The residual resistance factor, which is caused by chemical adsorption during CEOR process is similar to the endpoint relative permeability (Mohammed, 2008; Zheng et al, 2000). The adsorption of chemicals on to the porous media is strongly affected by salinity, solution pH, and polymer concentration (Hazarika & Gogoi, 2021; Hazarika & Gogoi, 2022a; Sarmah et al, 2019). For water wet reservoir, adsorption of chemicals control the excess water production by blocking the larger pore spaces without affecting oil production rate (Ogendal, 2016; Ogunberu & Asghari, 2004; Zaitoun & Kohler, 1998).…”

Section: Introductionmentioning

confidence: 99%

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Adsorption of surfactant during chemical enhanced oil recovery

Hazarika

Gogoi

2022

J Surfact & Detergents

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Surfactant is extensively used as chemicals during chemical enhanced oil recovery (CEOR) process. Effectiveness of surfactant CEOR process depends on several parameters like formation of micro emulsion, ultra-low interfacial tension (IFT) and adsorption of surfactant. First two parameters enhance the effectiveness while the last parameter reduces the effectiveness. Micro emulsions are highly desirable for CEOR due to its low interfacial tension (IFT) value and higher viscosity. In this research the size of the emulsions were studied with particle size analyzer to study the liquid-liquid absorption process and the entrapment of oil drops inside surfactant drop. Initially, the average surfactant drop size was found to be 100 nm, after mixing the surfactant slug with reservoir crude, the size was increase up to 10 times. It signifies the formation of micro emulsion between surfactant and oil. Another attempt was done in this research to study the adsorption mechanism of surfactant on reservoir rock. The process of adsorption was studied by Langmuir and Freundlich isotherm to understand the adsorption phenomena. In this study, it was found that the adsorption follows Freundlich isotherm and the adsorption phenomena was chemical for surfactant flooding process. In chemical adsorption phenomena, the rate of adsorption is high because, surfactant molecules are adsorbed layer after layer by the rock surface. Use of alkali along with surfactant reduces adsorption of surfactant since, alkali blocked the active clay sites before interacting with surfactant and hence the adsorption isotherm was found to be Langmuir and phenomena was physical adsorption.

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Section: Resultssupporting

confidence: 83%

Section: Introductionmentioning

confidence: 99%

Adsorption of surfactant during chemical enhanced oil recovery

Hazarika

Gogoi

2022

J Surfact & Detergents

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“…The rheological properties of the HPAM polymer control solution and the nanohybrid systems were evaluated by measuring the apparent viscosity using an Anton Paar rheometer (Anton Paar Analytical Instrument Company, Ashland, Virginia, USA) at 85 • C. This temperature is a frequently encountered reservoir temperature during polymer flooding [31]. The flow models of the HPAM polymer solution and the nanohybrid systems were extracted from the relationship between the shear stress and the shear rate as well as the viscosity vs. shear rate in a cartesian coordinate system at shear rates ranging from 10 s −1 -100 s −1 [32].…”

Section: Discussionmentioning

confidence: 99%

Enhancing the Performance of HPAM Polymer Flooding Using Nano CuO/Nanoclay Blend

et al. 2020

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A single polymer flooding is a widely employed enhanced oil recovery method, despite polymer vulnerability to shear and thermal degradation. Nanohybrids, on the other hand, resist degradation and maintain superior rheological properties at different shear rates. In this article, the effect of coupling CuO nanoparticles (NPs) and nanoclay with partially hydrolyzed polyacrylamide (HPAM) polymer solution on the rheological properties and the recovery factor of the nanohybrid fluid was assessed. The results confirmed that the NP agents preserved the polymer chains from degradation under mechanical, chemical (i.e., salinity), and thermal stresses and maintained good extent of entanglement among the polymer chains, leading to a strong viscoelastic attribute, in addition to the pseudoplastic behavior. The NP additives increased the viscosity of the HPAM polymer at shear rates varying from 10–100 s−1. The rheological properties of the nanohybrid systems varied with the NP additive content, which in turn provided a window for engineering a nanohybrid system with a proper mobility ratio and scaling coefficient, while avoiding injectivity issues. Sandpack flooding tests confirmed the superior performance of the optimized nanohybrid system and showed a 39% improvement in the recovery ratio relative to the HPAM polymer injection.

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“…The rheological properties of CO samples in Table 6 were determined using M3600DAQ software of the Viscometer as in Table 2 , by selecting the required test set up which included the temperature, rotational speeds in the set-up menu [ 48 ]. The test results were obtained in an excel sheet for speed (rpm), shear rate (s −1 ), shear stress (dy/cm 2 ), dynamic viscosity (cp) against the values given in the initial set-up.…”

Section: Methodsmentioning

confidence: 99%