Investigation of the microscopic displacement mechanisms and macroscopic behavior of alkaline flooding at different wettability conditions in shaly glass micromodels

Xia²,

et al. 2016

Front. Microbiol.

Biosurfactant producers are crucial for incremental oil production in microbial enhanced oil recovery (MEOR) processes. The isolation of biosurfactant-producing bacteria from oil reservoirs is important because they are considered suitable for the extreme conditions of the reservoir. In this work, a novel biosurfactant-producing strain Acinetobacter junii BD was isolated from a reservoir to reduce surface tension and emulsify crude oil. The biosurfactants produced by the strain were purified and then identified via electrospray ionization-Fourier transform ion cyclotron resonance mass spectrometry (ESI FT-ICR-MS). The biosurfactants generated by the strain were concluded to be rhamnolipids, the dominant rhamnolipids were C26H48O9, C28H52O9, and C32H58O13. The optimal carbon source and nitrogen source for biomass and biosurfactant production were NaNO3 and soybean oil. The results showed that the content of acid components increased with the progress of crude oil biodegradation. A glass micromodel test demonstrated that the strain significantly increased oil recovery through interfacial tension reduction, wettability alteration and the mobility of microorganisms. In summary, the findings of this study indicate that the newly developed BD strain and its metabolites have great potential in MEOR.

Section: Resultsmentioning

confidence: 99%

Rhamnolipids Produced by Indigenous Acinetobacter junii from Petroleum Reservoir and its Potential in Enhanced Oil Recovery

Xia²,

et al. 2016

Front. Microbiol.

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

“…Finally, the oil recovery factor of each process was measured and analyzed. It should be mentioned that after each experiment, the micromodel was cleaned based on the procedure reported in literature to maintain its water-wet wettability (Mehranfar and Ghazanfari, 2014).…”

Section: Glass Micromodelmentioning

confidence: 99%

“…Considerable decrease of the interfacial tension between the fluids and enhanced favorable mobility ratio would result in higher microscopic and macroscopic oil recovery (Liu et al, 2006;Saha et al, 2018). Accordingly, in-situ emulsification, which is the product of chemical reaction between the two displaced and displacing fluids in the reservoirs due to the injection of different chemicals including surfactant and alkalis, has been the subject of many recent studies (Alvarado, 1979;Kumar et al, 2010;Mehranfar and Ghazanfari, 2014;Taiwo et al, 2016).…”

Section: Introductionmentioning

confidence: 99%

“…This is mainly because alkali agents can react with the acidic components of crude oil and decrease the interfacial tension. Other prevailing mechanisms which are considered to be important in alkaline injection include wettability alteration, emulsification with entrainment, and emulsification with entrapment (Alvarado, 1979;Dong et al, 2007;Farias et al, 2012;Kumar et al, 2010;Mehranfar and Ghazanfari, 2014;Schmidt et al, 1984;Taiwo et al, 2016;Youssef et al, 2014).…”

Section: Introductionmentioning

confidence: 99%

See 1 more Smart Citation

Experimental study ofin-situW/O emulsification during the injection of MgSO₄and Na₂CO₃solutions in a glass micromodel

Palizdan

Doryani

Riazi

et al. 2020

In-situ emulsification of injected brines of various types is gaining increased attention for the purpose of enhanced oil recovery. The present experimental study aims at evaluating the impact of injecting various solutions of Na2CO3 and MgSO4 at different flow rates resembling those in the reservoir and near wellbore using a glass micromodel with different permeability regions. Emulsification process was visualized through the injection of deionized water and different brines at different flow rates. The experimental results showed that the extent of emulsions produced in the vicinity of the micromodel exit was profoundly higher than those at the entrance of the micromodel. The injection of Na2CO3 brine after deionized water caused the impact of emulsification process more efficiently for attaining higher oil recovery than that for the MgSO4 brine. For instance, the injection of MgSO4 solution after water flooding increased oil recovery only up to 1%, while the equivalent figure for Na2CO3 was 28%. It was also found that lower flow rate of injection would cause the displacement front to be broadened since the injected fluid had more time to interact with the oil phase. Finally, lower injection flow rate reduced the viscous force of the displacing fluid which led to lesser occurrence of viscous fingering phenomenon.

“…The primary control parameters of surfactant flooding include oil-water interfacial tension, the relative permeability curves, and the interpolation parameters at low and high interfacial tensions [32][33][34][35][36]. Without the addition of any surfactants, the IFT of the crude oil against its water was measured to be 19.73 mN/m using the axisymmetric drop shape analysis technique [37].…”

Section: Parameters Of Surfactant Floodingmentioning

confidence: 99%

Numerical Simulation and Optimization of Enhanced Oil Recovery by the In Situ Generated CO₂Huff-n-Puff Process with Compound Surfactant

Tang

et al. 2016

Journal of Chemistry

This paper presents the numerical investigation and optimization of the operating parameters of the in situ generated CO2Huff-n-Puff method with compound surfactant on the performance of enhanced oil recovery. First, we conducted experiments of in situ generated CO2and surfactant flooding. Next, we constructed a single-well radial 3D numerical model using a thermal recovery chemical flooding simulator to simulate the process of CO2Huff-n-Puff. The activation energy and reaction enthalpy were calculated based on the reaction kinetics and thermodynamic models. The interpolation parameters were determined through history matching a series of surfactant core flooding results with the simulation model. The effect of compound surfactant on the Huff-n-Puff CO2process was demonstrated via a series of sensitivity studies to quantify the effects of a number of operation parameters including the injection volume and mole concentration of the reagent, the injection rate, the well shut-in time, and the oil withdrawal rate. Based on the daily production rate during the period of Huff-n-Puff, a desirable agreement was shown between the field applications and simulated results.