Isolated mechanism study on in situ CO2 EOR

Wang, Shuoshi; Li, Keren; Chen, Changlong; Ogbonnaya, Onyekachi; Harwell, Jeffrey H.

doi:10.1016/j.fuel.2019.05.158

Cited by 16 publications

(12 citation statements)

References 70 publications

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“…The dimension of tested quartz plates was 1.7 cm × 6.7 cm. The quartz plates were aged by submerging in the targeted crude oil in a sealed chamber for 24 h at 60 ± 2 °C . The aged quartz plates were then dried in a closed chamber at ambient conditions (25 ± 2 °C and ambient pressure) at least 24 h prior to the contact angle measurements.…”

Section: Methodsmentioning

confidence: 99%

Evaluation of Silica-Based Nanofluid Foam in Waxy Oil Recovery and Its Role in Mitigation of Surfactant Loss

et al. 2021

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The use of silica nanoparticles (SNPs) has shown promising results in providing higher foam stability in chemically enhanced oil recovery (cEOR). In this study, hydrophobic SNPs stabilized in a carboxylate anionic surfactant were selected to improve the performance of surfactant foam flooding through the sand pack experiment. The effects of SNPs on foam flooding, including foam stability, surfactant adsorption, wettability alteration, and displacement efficiency, were investigated. The results confirmed that the addition of SNPs significantly enhanced foam stability. The surfactant adsorptions onto the sand medium were reduced by 54 and 27% in the presence of SNPs at 5000 and 1000 ppm, respectively. The addition of the SNP−surfactant could alter the wettability of the oilcoated surface to water-wet conditions as probed by the contact angle measurement. The displacement efficiency reached a cumulative recovery of 97.58% original oil in place (OOIP) by the SNP foam flooding system at 1000 ppm SNPs compared to 77% OOIP obtained from the neat surfactant foam system. Gas chromatography−time-of-flight−mass spectrometry (GC−TOF−MS) analysis was adopted to characterize the incremental change in crude oil compositions at each pore volume to probe the flooding performance in correspondence with the oil properties, i.e., waxy components. As a result of combining the effects of the SNP−surfactant on improving the foam stability, surface alteration, and minimizing the surfactant loss, more available surfactants could efficiently sweep the residual waxy and heavy oil components. The findings of this study revealed an understanding of improving oil displacement of waxy crude oil by SNP−surfactant-stabilized foam, which is applicable for waxy crude oil reservoirs.

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Section: Methodsmentioning

confidence: 99%

Evaluation of Silica-Based Nanofluid Foam in Waxy Oil Recovery and Its Role in Mitigation of Surfactant Loss

et al. 2021

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“…Self‐generated gas technology can effectively solve the storage and transportation problems of gas sources in offshore platform operation. Some early studies have proved its feasibility as a chemical flooding technique for enhanced oil recovery . For example, Wang used urea and ammonium carbamate as reaction agents for the in situ CO 2 technology.…”

Section: Introductionmentioning

confidence: 99%

“…They found that the in situ CO 2 technology was close to the complex combination flooding technology such as surfactant recovery and alkali flooding in terms of tertiary oil recovery . In addition, the effects of injection method, agent concentration, and high divalent ion level on the reaction kinetics and recovery performance of the urea system were also investigated . Zhu et al used an acid‐alternating base (AAB) system to generate CO 2 for blockage removal and enhanced oil recovery.…”

Section: Introductionmentioning

confidence: 99%

“…Some early studies have proved its feasibility as a chemical flooding technique for enhanced oil recovery. [25][26][27][28][29][30][31][32] For example, Wang used urea and ammonium carbamate as reaction agents for the in situ CO 2 technology. They found that the in situ CO 2 technology was close to the complex combination flooding technology such as surfactant recovery and alkali flooding in terms of tertiary oil recovery.…”

mentioning

confidence: 99%

“…[25][26][27] In addition, the effects of injection method, agent concentration, and high divalent ion level on the reaction kinetics and recovery performance of the urea system were also investigated. 28,29 Zhu et al 30 used an acid-alternating base (AAB) system to generate CO 2 for blockage removal and enhanced oil recovery. Although in situ gas technology can improve oil displacement efficiency, it still faces the problem of mobility control of gas flooding technology.…”

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confidence: 99%

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Experimental study on the enhanced oil recovery by in situ foam formulation

Chen

Wang

et al. 2020

Energy Science & Engineering

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In situ CO2 foams (ISCF) are studied systematically by combining in situ CO2 gas reactants (carbonate anhydrous, hydrochloric acid) and bio‐based surfactant. Sandpack flooding experiments at 60°C along with PVT experiments were carried out to analyze the oil displacement mechanisms. The results showed that ISCF could increase oil recovery from heterogeneous multilayer formation of permeability ratio over 6, and displacement efficiency increased with the injection volume increased before the injection of 1 PV. The incremental oil recovery by ISCF was much greater than that of conventional foam or in situ CO2 (ISC) without foam under the same injection conditions. The generated CO2 foam could reduce the interfacial tension between displacement phase and displaced phase effectively which contributed to the great increase in capillary number. The CO2 dissolution greatly reduced the viscosity of crude oil, and the highest viscosity reduction rate at 60°C could be as high as 98%. The Ca2+ concentration of produced liquids analysis revealed the ISCF could distribute intelligently the acid in heterogeneous formations.

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