Experimental study and surface complexation modeling of non-monotonic wettability behavior due to change in brine salinity/composition: Insight into anhydrite impurity in carbonates

Mogharrab, Javad Madadi; Ayatollahi, Shahab

doi:10.1016/j.molliq.2022.120117

Cited by 7 publications

(2 citation statements)

References 77 publications

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“…Low-salinity waterflooding (LSWF) is a promising method for improving oil recovery in oil reservoirs with low recovery rates. Although a definitive recovery mechanism remains uncertain, empirical evidence suggests that adjusting ion type and concentration in the water phase can enhance oil recovery by altering reservoir and fluid properties such as wettability, permeability, capillary pressure, and interfacial properties between water and oil [1][2][3][4][5][6][7][8].…”

Section: Introductionmentioning

confidence: 99%

Water/oil emulsion and asphaltene instability in different formations during low-salinity waterflooding: an experimental study

Salari,

Balavi,

Ayatollahi

et al. 2024

Scientia Iranica

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Previous studies have extensively investigated the effects of salinity on asphaltene behavior at the water-oil contact surface during Low-salinity waterflooding. However, the influence of rocks has often been overlooked. This study investigates the impact of rock type (calcite/quartz) on these phenomena in the presence of various brines (Formation Water (FW), Sea Water (SW), 2 and10 times diluted SW (2DSW, 10DSW), Distillated Water (DW)). UV-Vis spectroscopy was used to assess the asphaltene separation from fresh or aged bulk oil with brine, by using the "indirect method". Microscopic analysis of water droplet size was performed to evaluate emulsion stability. The results demonstrate that the UV-Vis absorbance for fresh oil is approximately 13.6 and that decreases to 11, 10.5, and 10.5 for the 2DSW/oil, calcite/SW/oil, and quartz/2DSW/oil emulsions, respectively. Additionally, the results show that for rock/FW/oil emulsion, compared to quartz, calcite presence increases asphaltene precipitation/deposition by about 38 wt.%. Furthermore, the findings reveal that, across all salinities, the average size of water droplets is larger when calcite is present than quartz, suggesting greater instability in the calcite. These outcomes align with the results of Interfacial tension (IFT) measurement, FTIR spectral analysis of oil, and zetapotential determination for suspended calcite/quartz particles in different brines.

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Section: Introductionmentioning

confidence: 99%

Water/oil emulsion and asphaltene instability in different formations during low-salinity waterflooding: an experimental study

Salari,

Balavi,

Ayatollahi

et al. 2024

Scientia Iranica

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“…Various laboratory and field studies have demonstrated that manipulating the type and the content of ions in the injection water, known as low-salinity waterflooding (LSWF), can lead to incremental oil recovery. Even though the effect of LSWF has been justified by several measurements such as rock wettability, relative permeability, capillary pressure, and rock-fluid and fluid–fluid interfacial properties, there is no consensus on the dominant governing mechanism. − Unlike the overwhelming number of papers on solid–liquid interactions and underlying mechanisms of enhanced oil recovery by LSWF, studies on the side effects of LSWF, such as asphaltene instability, (viscous) emulsion formation, and organic scaling–eventually impeding flow and leading to formation damage–are scarce. − It is worth mentioning that some experimental results suggest that emulsion production and asphaltene deposition, as the side effects of the LSWF process, could improve the injection performance by increasing the breakthrough time and sweep efficiency. − …”

Section: Introductionmentioning

confidence: 99%

The Simultaneous Effect of Brine Salinity and Dispersed Carbonate Particles on Asphaltene and Emulsion Stability

2023

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The oil recovery improvement by low-salinity waterflooding (LSWF) must be achieved with minimal formation damage. The asphaltic fractions of crude oil can be destabilized when in contact with incompatible injection brines resulting in organic formation damage. Due to the lack of fundamental understanding about the potential effect of rock presence on this phenomenon, in this study, the simultaneous effect of brine salinity and calcite rock presence on asphaltene instability in an emulsified system was investigated by developing a new experimental protocol. In this method, calcite rock is dispersed in different brines with total salinity ranging from 0−189,365 ppm and then mixed with oil to find the rock and brine effect on asphaltene and emulsion stability. UV−vis spectroscopy is performed on the supernatant oil phase before and after contact with brine to assess quantitatively asphaltene instability. Oil/water IFT measurements before and after contact and microscopic analysis of the water droplet size were conducted to evaluate the water/oil interface behavior. Besides, the zeta-potential for suspended calcite particles in different brines was measured to evaluate the electrokinetics of rock-oil interaction. The results show increased asphaltene instability when oil makes contact with the brine in an emulsified system. This highly depends on the brine type, and the maximum precipitation occurred at an intermediate salinity with two-times diluted seawater. While the trend of before-contact IFT and the water-in-oil emulsion size at different salinities is consistent, the UV−vis absorbance of bulk oil shows a reverse tendency with the after-contact IFT. Asphaltene deposition generally increased when solid calcite particles were present in the emulsified system, and at higher salinities, more asphaltene adsorption on the rock surface occurred due to a larger attractive force between rock and asphaltene. This trend is consistent with the results of the zeta-potential measurements. These novel findings can help avoid unrepresentative results regarding organic damage in LSWF.

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Experimental and theoretical investigation of the impact of crude-oil on the wettability behavior of calcite and silicate due to low salinity effect

Mazinani

Farhadi

Fatemi

2023

Fuel

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Experimental study and surface complexation modeling of non-monotonic wettability behavior due to change in brine salinity/composition: Insight into anhydrite impurity in carbonates

Cited by 7 publications

References 77 publications

Water/oil emulsion and asphaltene instability in different formations during low-salinity waterflooding: an experimental study

Water/oil emulsion and asphaltene instability in different formations during low-salinity waterflooding: an experimental study

The Simultaneous Effect of Brine Salinity and Dispersed Carbonate Particles on Asphaltene and Emulsion Stability

Experimental and theoretical investigation of the impact of crude-oil on the wettability behavior of calcite and silicate due to low salinity effect

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