Effect of brine composition on oil-rock interaction by atomic force microscopy

Chandrasekhar, Sriram; Mohanty, Kishore K.

doi:10.1016/j.petrol.2018.02.001

Cited by 21 publications

(13 citation statements)

References 40 publications

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“…For the case of 1 wt% NaCl and 0.5 wt% HNP, evaporation effects might have caused substantial changes in adhesion force measurements after 3 h because the AFM fluid cell was not refilled over the course of the experiments. Nonetheless, it was determined that 3 h was sufficient time to obtain equilibrium adhesion, and this is in accordance with similar experiments performed elsewhere on brine composition effects on rock-oil interactions in carbonate reservoirs [23]. The short time frame makes force spectroscopy provide benefits of efficiency when compared to previous wettability evaluation methods that require days to weeks to obtain statistically tangible and reliable results due to the need for aging and steady state requirement [46,47].…”

Section: Methodssupporting

confidence: 84%

“…The spatial characterization of adhesion on a given sample area using CFM is referred to as chemical force mapping [44]. Studies with CFM have been reported previously [22,23,44]. Chemical force mapping was performed using a Keysight 5500 AFM (Santa Rosa, CA, USA) using the force volume spectroscopy feature.…”

Section: Methodsmentioning

confidence: 99%

“…The peak adhesion force characterized throughout this study is the point of maximum deflection from the zero base line on the retract portion of the force curve generated under chemical force spectroscopy using AFM [23]. For a functionalized tip in contact with a mineral substrate (substitute for a rock surface) immersed in a liquid medium, the integral area between the approach and retract portions of the force curve is known as the work of adhesion [43] (also see Figure 11).…”

Section: Relationship Between Adhesion Force Work Of Adhesion and Wettabilitymentioning

confidence: 99%

“…The AFM has also been applied to determine bitumen/water surface potential [18]; to characterize nanoparticle size distribution [19]; and to assess nanopores in shale gas rocks [20,21]. Recently, chemical force mapping has been used to probe ionically tuned brine and effects on adhesion in petroleum reservoir rock minerals [16,22,23]. There is also a body of literature on interpretations and broad applications of force measurements [24][25][26].…”

Section: Introductionmentioning

confidence: 99%

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Insights into Nanoscale Wettability Effects of Low Salinity and Nanofluid Enhanced Oil Recovery Techniques

2020

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In this study, enhanced oil recovery (EOR) techniques—namely low salinity and nanofluid EOR—are probed at the nanometer-scale using an atomic force microscope (AFM). Mica substrates were used as model clay-rich rocks while AFM tips were coated to present alkyl (-CH3), aromatic (-C6H5) and carboxylic acid (-COOH) functional groups, to simulate oil media. We prepared brine formulations to test brine dilution and cation bridging effects while selected concentrations (0 to 1 wt%) of hydrophilic SiO2 nanoparticles dispersed in 1 wt% NaCl were used as nanofluids. Samples were immersed in fluid cells and chemical force mapping was used to measure the adhesion force between polar/non-polar moieties to substrates. Adhesion work was evaluated based on force-displacement curves and compared with theories. Results from AFM studies indicate that low salinity waters and nanoparticle dispersions promote nanoscale wettability alteration by significantly reducing three-phase adhesion force and the reversible thermodynamic work of adhesion, also known as adhesion energy. The maximum reduction in adhesion energy obtained in experiments was in excellent agreement with existing theories. Electrostatic repulsion and reduced non-electrostatic adhesion are prominent surface forces common to both low salinity and nanofluid EOR. Structural forces are complex in nature and may not always decrease total adhesion force and energy at high nanoparticle concentration. Wettability effects also depend on surface chemical groups and the presence of divalent Mg2+ and Ca2+ cations. This study provides fresh insights and fundamental information about low salinity and nanofluid EOR while demonstrating the application of force-distance spectroscopy in investigating EOR techniques.

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Section: Methodssupporting

confidence: 84%

Section: Methodsmentioning

confidence: 99%

Section: Relationship Between Adhesion Force Work Of Adhesion and Wettabilitymentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

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Insights into Nanoscale Wettability Effects of Low Salinity and Nanofluid Enhanced Oil Recovery Techniques

2020

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“…Calcite, as the most stable polymorph of CaCO 3 at ambient conditions, has been frequently used to represent the solid matrix of carbonate rocks. Such model oil–brine–calcite systems have been utilized to study the adsorption of a fatty acid on the calcite surface and the impact of aqueous ions, such as Ca 2+ , Mg 2+ , and SO 4 2– , on the wettability of aged calcite surface. , Recently, the wettability of calcite surfaces has been the subject of various theoretical studies using quantum mechanics, molecular dynamics, , and surface complex models. , Moreover, many experimental investigations have been conducted in this area using atomic force microscopy (AFM) to probe the adhesive forces between the organic matter and carbonate surfaces and shed more light on the underlying physical and chemical interactions that govern the wettability. , Nonetheless, very few studies have been conducted to systematically investigate the impacts of the adsorption of polar components (e.g., carboxylic materials) on the wettability of carbonate minerals under elevated temperature and pressure conditions. Moreover, the effects of displacement processes on the adsorption/desorption phenomena and the consequent changes in wettability have been mostly overlooked.…”

Section: Introductionmentioning

confidence: 99%

Wettability of Calcite Surfaces: Impacts of Brine Ionic Composition and Oil Phase Polarity at Elevated Temperature and Pressure Conditions

2020

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The interactions among the polar components of oil, aqueous phase ions, and carbonate minerals, as well as their subsequent effects on surface wettability, can significantly impact the fluid distribution and recovery in a hydrocarbon reservoir. In this study, we investigate the adsorption/ desorption of molecules from oils with different levels of polarity on calcite surfaces during different displacement processes under elevated pressure and temperature conditions. We measured dynamic contact angles (CA) on untreated and aged calcite substrates using brines with different salinities and compositions and model oils, that is, mixtures of varying concentrations of stearic acid (SA) and n-decane. In particular, the impacts of the concentrations of Ca 2+ , SO 4 2− , and OH − ions on the adsorption phenomena were explored. For the nonpolar oil, increasing brine salinity or removing Ca 2+ ions from the aqueous phase impacted the potentials of oil−brine and brine−mineral interfaces and shifted the wettability of calcite surface toward more water-wet conditions. In the presence of polar oil, the adsorption of the polar components controls the surface wettability. Higher concentrations of Ca 2+ /SO 4 2− could facilitate/obstruct the polar component adsorption and thus increase/decrease the dynamic oil−water CAs. It is also observed that the brine salinity does not impact the wettability if excess SA is added to the oil phase, that is, if the oil phase is strongly polar. Moreover, the adsorption of SA on the calcite surface under experimental conditions is found to be reversible during the displacement events. The surface energy calculation for the adsorption process indicates that the surface coverage of calcite by SA is more sensitive to the presence of Ca 2+ in brine than the concentration of polar components in oil. We also conducted several experiments on calcite substrates aged with SA. The measurements demonstrate that the adsorbed SA molecules are detached when the aged mineral surface is exposed to a lower-salinity brine at high temperatures, and the SA molecules could be adsorbed back on the surface once the displacement is halted.

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Displacement behavior and mechanism of long-term water flooding in sandstone oil reservoirs

Cao

Dai

Wang

et al. 2021

J. Cent. South Univ.

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Effect of brine composition on oil-rock interaction by atomic force microscopy

Cited by 21 publications

References 40 publications

Insights into Nanoscale Wettability Effects of Low Salinity and Nanofluid Enhanced Oil Recovery Techniques

Insights into Nanoscale Wettability Effects of Low Salinity and Nanofluid Enhanced Oil Recovery Techniques

Wettability of Calcite Surfaces: Impacts of Brine Ionic Composition and Oil Phase Polarity at Elevated Temperature and Pressure Conditions

Displacement behavior and mechanism of long-term water flooding in sandstone oil reservoirs

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