Abstract:Hydrocarbon-miscible gas flooding typically involves injection of an associated gas (AG) mixture containing mainly methane (CH 4 ) enriched with light hydrocarbon fractions and possibly acid gases. The AG mixture has been recognized as an excellent candidate for miscible gas injection (MGI). However, in general, the viscosity of the AG at reservoir conditions is significantly lower than that of crude oil leading to an unfavorable mobility ratio and low volumetric sweep efficiency during flooding. This study as… Show more
“…The severe cases of unfavorable mobility ratios may lead to early water (chemical) or gas breakthrough to production wells (Agi et al 2018;Al Hinai 2017). High reservoir conditions such as high temperature in most cases contribute to these aforementioned factors, because the viscosity of the injected fluids decreases tremendously with temperature causing fingering to oil bank.…”
In this study, an industrial-based surfactant known as MFomax surfactant has been modified with unfunctionalized and silanefunctionalized silica nanoparticles (NPs) to select the high viscous nano-fluid (NF) for generation of in situ foam to assess the differential pressure buildup (∆p) behavior in the porous media. Different weight concentrations of NPs and MFomax from 0.1 to 0.5% were studied using Design Expert Software to generate full matrix design of NF formulations. The viscosity data were analyzed with the aid of response surface analytical tool to investigate the response of NPs loading on the NF viscosity for optimization. The microstructural properties of the NFs were characterized using spectroscopic equipment. Subsequently, the high viscous NF was selected to generate in situ foam in comparison with the precursor MFomax foam for ∆p buildup assessment at 110 °C and 2023 psi in the native reservoir core. Results have shown that both the silica NPs could significantly improve the MFomax viscosity; however, the silane-functionalized silica NPs have more effect to improve the viscosity and other microstructural properties than the unfunctionalized NPs, and thus, they were selected for further experimental studies. The coreflood ∆p buildup assessment shows that NF foam built more ∆p having average value of 46 psi against 25 psi observed in the case of the precursor MFomax foam. Thus, this study demonstrates that functionalized silica NPs could improve the MFomax viscosity and eventually generates high ∆p buildup at high-temperature high-pressure conditions.
“…The severe cases of unfavorable mobility ratios may lead to early water (chemical) or gas breakthrough to production wells (Agi et al 2018;Al Hinai 2017). High reservoir conditions such as high temperature in most cases contribute to these aforementioned factors, because the viscosity of the injected fluids decreases tremendously with temperature causing fingering to oil bank.…”
In this study, an industrial-based surfactant known as MFomax surfactant has been modified with unfunctionalized and silanefunctionalized silica nanoparticles (NPs) to select the high viscous nano-fluid (NF) for generation of in situ foam to assess the differential pressure buildup (∆p) behavior in the porous media. Different weight concentrations of NPs and MFomax from 0.1 to 0.5% were studied using Design Expert Software to generate full matrix design of NF formulations. The viscosity data were analyzed with the aid of response surface analytical tool to investigate the response of NPs loading on the NF viscosity for optimization. The microstructural properties of the NFs were characterized using spectroscopic equipment. Subsequently, the high viscous NF was selected to generate in situ foam in comparison with the precursor MFomax foam for ∆p buildup assessment at 110 °C and 2023 psi in the native reservoir core. Results have shown that both the silica NPs could significantly improve the MFomax viscosity; however, the silane-functionalized silica NPs have more effect to improve the viscosity and other microstructural properties than the unfunctionalized NPs, and thus, they were selected for further experimental studies. The coreflood ∆p buildup assessment shows that NF foam built more ∆p having average value of 46 psi against 25 psi observed in the case of the precursor MFomax foam. Thus, this study demonstrates that functionalized silica NPs could improve the MFomax viscosity and eventually generates high ∆p buildup at high-temperature high-pressure conditions.
“…However, if the miscible PDMS‐CO 2 thickener scenario is considered at the beginning of the reservoir life, it can be more effective than other scenarios. [ 16 ] In addition, the JBN technique was used to obtain the gas/oil relative permeability. The PDMS thickener provides the miscible conditions during the coreflooding scenarios.…”
Section: Resultsmentioning
confidence: 99%
“…Lee et al [ 17 ] illustrated that the small molecule thickeners of hydroxy aluminium soap and tri‐alkyl‐tin fluoride significantly enhances the viscosity of propane and butane 6‐10‐fold compared to the cross‐linked phosphate ester mixtures. Alhinai et al [ 16 ] used the poly 1‐decene (P‐1‐D), PDMS, and (polymethylhydrosiloxane) PMHS as small molecule thickeners for miscible thickened natural gas flooding. Also, a hydrocarbon gas mixture containing methane (60%), ethane (9%), propane (6%), and carbon dioxide (25%) was considered as an injection gas at reservoir conditions.…”
Section: Introductionmentioning
confidence: 99%
“…[ 8–14 ] Consequently, in recent decades, experimental and theoretical research has been conducted toward improving gas mobility control by polymer thickeners for gas‐based enhanced oil recovery (EOR). [ 15–18 ] There are two strategies for improving gas mobility control by polymer thickeners: the dissolution of ultra‐high molecular weight polymers into gases, and the dissolution of small molecules as direct thickeners, which both lead to viscosity enhancement. Polymers as direct thickeners for gas mobility control were first used by Heller et al [ 19 ] They indicated that oil‐soluble polymers or nonpolar organic polymers are more effective when dissolved in carbon dioxide than water‐soluble polymers.…”
Recently, polymer thickeners have been considered for CO2 mobility control during enhanced oil recovery (EOR) processes. Despite that, the requirement of co‐solvents is a controversial challenge for the solution of high‐molecular weight thickeners in gases. This study is focused on small molecule thickeners for carbon dioxide EOR without adding co‐solvents. Polydimethylsiloxane (PDMS) was used as a CO2‐philic thickener in different low molecular weights. Cloud‐point pressure, relative viscosity, and interfacial tension (IFT) between intermediate crude oil and pure/thickened CO2 were measured at reservoir conditions. Also, the impact of PDMS‐CO2 thickener on gas mobility control was evaluated during the coreflooding experiments in secondary and tertiary modes. The experimental results show that PDMS caused an increase in relative viscosity up to 4.7‐fold and successfully thickened CO2. In addition, the minimum miscibility pressure of PDMS‐thickened CO2 was lower than that of pure CO2, and miscible PDMS‐CO2 thickener occurred at higher PDMS molecular weights. However, the gas breakthrough time can be considerably delayed if the PDMS‐thickened CO2 was flooded directly, which increased the oil recovery factor between 6% to 15% during tertiary recovery.
“…Most previous studies, reported that for low/high molecular weight polymers, a concentration of 1.5-7 wt% is required to thicken CO 2 albeit at very high pressure [6]. In recent studies, [16,17] P-1-D has been found to have sufficient solubility in both CO 2 and associated gas (AG) mixtures (at temperatures above 358 K and pressures of 50-55 MPa) to considerably increase gas viscosity. The viscosity enhancement of P-1-D in an AG mixture (25 mol% CO 2 ) and CO 2 was measured in a capillary viscometer at different pressures (50-55 MPa), 377 K, and varying P-1-D concentrations (1.5-9 wt%).…”
Section: Direct Carbon Dioxide Thickeners 21 Polymeric Thickenersmentioning
Direct gas thickening technique has been developed to control the gas mobility in the miscible gas injection process for enhanced oil recovery. This technique involves increasing the viscosity of the injected gas by adding chemicals that exhibit good solubility in common gasses, such as CO 2 or hydrocarbon (HC) solvents. This chapter presents a review of the latest attempts to thicken CO 2 and/or hydrocarbon gases using various chemical additives, which can be broadly categorised into polymeric, conventional oligomers, and small-molecule self-interacting compounds. In an ideal situation, chemical compounds must be soluble in the dense CO 2 or hydrocarbon solvents and insoluble in both crude oil and brine at reservoir conditions. However, it has been recognised that the use of additives with extraordinary molecular weights for the above purpose would be quite challenging since most of the supercritical fluids are very stable with reduced properties as solvents due to the very low dielectric constant, lack of dipole momentum, and low density. Therefore, one way to attain adequate solubility is to elevate the system pressure and temperature because such conditions give rise to the intermolecular forces between segments or introduce functional groups that undergo self-interacting or intermolecular interactions in the oligomer molecular chains to form a viscosity-enhancing supramolecular network structure in the solution. According to this review, some of the polymers tested to date, such as polydimethylsiloxane, polyfluoroacrylate styrene, and poly(1,1-dihydroperfluorooctyl acrylate), may induce a significant increase of the solvent viscosity at high concentrations. However, the cost and environmental constraints of these materials have made the field application of these thickeners unfeasible. Until now, thickeners composed of small molecules have shown little success to thicken CO 2 , because CO 2 is a weak solvent due to its ionic and polar characteristics. However, these thickeners have resulted in promising outcomes when used in light alkane solvents.
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