Extended DLVO-based estimates of surface force in low salinity water flooding

Xie, Quan; Saeedi, Ali; Pooryousefy, Ehsan; Liu, Yongbing

doi:10.1016/j.molliq.2016.06.004

Cited by 128 publications

(90 citation statements)

References 38 publications

(64 reference statements)

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“…It is worth noting that divalent cations effect on disjoining pressure at various concentration were not documented in this section because 0.1 wt % CaCl 2 and MgCl 2 already rendered negative disjoining pressures (Figure 3). Similar trend was also reported by Xie et al [34] who showed that increasing NaCl concentration solution shifts the disjoining pressure from positive to negative due to reduced electrostatic screening, suggesting an oil-wet system. …”

Section: Effect Of Cation Type and Concentration On Disjoining Pressuresupporting

confidence: 89%

“…The surface species concentrations were calculated using PHREEQC version 3.3.9 (Parkhurst and Appelo 2013) and a diffuse layer surface model. Due to the fact that Ca 2+ and Mg 2+ have similar charge density, thus almost same disjoining pressure [34], we did not calculate the surface complexation in the presence of MgCl 2 , but NaCl and CaCl 2 with concentration of 0.1 and 5 wt % were included this section. It is also worth noting that, in our geochemical modelling, we did not consider the interaction between non-polar oil and calcite surfaces, e.g., hydrogen bonding, van der Waals interaction, ligand bridging, etc.…”

Section: Surface Complexation Modellingmentioning

confidence: 99%

“…Disjoining pressure results show that divalent cations (Ca 2+ and Mg 2+ ) compressed the double layer, thus increasing the adhesion between oil and minerals, and triggering an oil-wet system [27,34]. Surface complexation shows that divalent cations (Ca 2+ and Mg 2+ ) electrostatically linked oil and clays [35].…”

Section: Implications and Conclusionmentioning

confidence: 99%

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Drivers of Wettability Alteration for Oil/Brine/Kaolinite System: Implications for Hydraulic Fracturing Fluids Uptake in Shale Rocks

et al. 2018

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Abstract:Hydraulic fracturing technique is of vital importance to effectively develop unconventional shale resources. However, the low recovery of hydraulic fracturing fluids appears to be the main challenge from both technical and environmental perspectives in the last decade. While capillary forces account for the low recovery of hydraulic fracturing fluids, the controlling factor(s) of contact angle, thus wettability, has yet to be clearly defined. We hypothesized that the interaction of oil/brine and brine/rock interfaces governs the wettability of system, which can be interpreted using Derjaguin-Landau-Verwey-Overbeek (DLVO) and surface complexation modelling. To test our hypothesis, we measured a suit of zeta potential of oil/brines and brine/minerals, and tested the effect of ion type (NaCl, MgCl 2 and CaCl 2 ) and concentrations (0.1, 1, and 5 wt %). Moreover, we calculated the disjoining pressure of the oil/brine/mineral systems and compared with geochemical modelling predictions. Our results show that cation type and salinity governed oil/brine/minerals wettability. Divalent cations (Ca 2+ and Mg 2+ ) compressed the electrical double layer, and electrostatically linked oil and clays, thus increasing the adhesion between oil and minerals, triggering an oil-wet system. Increasing salinity also compressed the double layer, and increased the site density of oppositely charged surface species which made oil and clay link more strongly. Our results suggest that increasing salinity and divalent cations concentration likely decrease water uptake in shale oil reservoirs, thus de-risking the hydraulic fracturing induced formation damage. Combining DLVO and surface complexation modelling can delineate the interaction of oil/brine/minerals, thus wettability. Therefore, the relative contribution of capillary forces with respect to water uptake into shale reservoirs, and the possible impairment of hydrocarbon production from conventional reservoirs can be quantified.

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Section: Effect Of Cation Type and Concentration On Disjoining Pressuresupporting

confidence: 89%

Section: Surface Complexation Modellingmentioning

confidence: 99%

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Drivers of Wettability Alteration for Oil/Brine/Kaolinite System: Implications for Hydraulic Fracturing Fluids Uptake in Shale Rocks

et al. 2018

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“…While wettability alternation is considered as the main mechanism behind LSE, the understanding of which factors control the wettability variation is incomplete due to the complexity of the interactions occurring in the oil/brine/rock system. The two approaches that reveal the controlling factors behind the wettability alteration are (a) double-layer expansion between fine particles and limited fines release (LFR) between oil/rock contact areas (Nasralla and Nasr-El-Din 2014;Tang and Morrow 1999a;Xie et al 2016) and (b) surface complexation modeling (Brady and Krumhansl 2012;Brady and Thyne 2016;Brady et al 2015;Mahani et al 2017;Xie et al 2017).…”

Section: Introductionmentioning

confidence: 99%

How much would silica nanoparticles enhance the performance of low-salinity water flooding?

Dehaghani

Daneshfar

2019

Pet. Sci.

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Nanofluids and low-salinity water (LSW) flooding are two novel techniques for enhanced oil recovery. Despite some efforts on investigating benefits of each method, the pros and cons of their combined application need to be evaluated. This work sheds light on performance of LSW augmented with nanoparticles through examining wettability alteration and the amount of incremental oil recovery during the displacement process. To this end, nanofluids were prepared by dispersing silica nanoparticles (0.1 wt%, 0.25 wt%, 0.5 wt% and 0.75 wt%) in 2, 10, 20 and 100 times diluted samples of Persian Gulf seawater. Contact angle measurements revealed a crucial role of temperature, where no wettability alteration occurred up to 80 °C. Also, an optimum wettability state (with contact angle 22°) was detected with a 20 times diluted sample of seawater augmented with 0.25 wt% silica nanoparticles. Also, extreme dilution (herein 100 times) will be of no significance. Throughout micromodel flooding, it was found that in an oil-wet condition, a combination of silica nanoparticles dispersed in 20 times diluted brine had the highest displacement efficiency compared to silica nanofluids prepared with deionized water. Finally, by comparing oil recoveries in both water-and oil-wet micromodels, it was concluded that nanoparticles could enhance applicability of LSW via strengthening wettability alteration toward a favorable state and improving the sweep efficiency.

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“…They proposed that the integration of pH gradient and DLE to be responsible for wettability alteration during low saline brine injection. Several studies have also shown the disjoining pressure (at small distances, where it is most effective) become more positive as the brine salinity is reduced [53,123,230,235]. Positive disjoining pressure indicates repulsion, which increase the thickness of water film and results in increased water-wetness (see Figure 11).…”

Section: Electrical Interactionsmentioning

confidence: 98%

 Brine-Dependent Recovery Processes (Smart-Water/Low-Salinity-Water) in Carbonate and Sandstone Petroleum Reservoirs: Review of Laboratory-Field Studies, Interfacial Mechanisms and Modeling Attempts

Awolayo¹,

Sarma²,

Nghiem³

2018

Preprint

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Brine-dependent recovery process has seen much global research efforts in the past two decades because of their benefits over other oil recovery methods. The process involves the tweaking of the ionic composition and strength of the injected water to improve oil production. In recent years, several studies ranging from laboratory coreflood experiments by many researchers to field trials by several companies admit to the potential of recovering additional oil in sandstone and carbonate reservoirs. Sandstone and carbonate rocks are composed of completely different minerals, with varying degree of complexity and heterogeneity, but wettability alteration has been widely considered as the consequence rather than the cause of brine-dependent recovery. However, there is no consensus on the cause as several mechanisms have been proposed to relate the wettability changes to the improved recovery. This review paper aims to provide a state-of-the-art development in published research and various efforts of the industry. This review outlines an overview of laboratory and field observations, descriptions of underlying mechanisms and their validity, the complexity of the oil-brine-rock interactions, modelling works, and comparison between sandstone and carbonate rocks. The provided information is intended to provide the reader with up-to-date information, point to relevant studies for those who are new and those implementing either laboratory- or field-scale projects to speed up the process of further investigations in this research area. Overall, the outcome of this review would potentially be of immense benefit to the oil industry.

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Extended DLVO-based estimates of surface force in low salinity water flooding

Cited by 128 publications

References 38 publications

Drivers of Wettability Alteration for Oil/Brine/Kaolinite System: Implications for Hydraulic Fracturing Fluids Uptake in Shale Rocks

Drivers of Wettability Alteration for Oil/Brine/Kaolinite System: Implications for Hydraulic Fracturing Fluids Uptake in Shale Rocks

How much would silica nanoparticles enhance the performance of low-salinity water flooding?

Brine-Dependent Recovery Processes (Smart-Water/Low-Salinity-Water) in Carbonate and Sandstone Petroleum Reservoirs: Review of Laboratory-Field Studies, Interfacial Mechanisms and Modeling Attempts

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Extended DLVO-based estimates of surface force in low salinity water flooding

Cited by 128 publications

References 38 publications

Drivers of Wettability Alteration for Oil/Brine/Kaolinite System: Implications for Hydraulic Fracturing Fluids Uptake in Shale Rocks

Drivers of Wettability Alteration for Oil/Brine/Kaolinite System: Implications for Hydraulic Fracturing Fluids Uptake in Shale Rocks

How much would silica nanoparticles enhance the performance of low-salinity water flooding?

&nbsp;Brine-Dependent Recovery Processes (Smart-Water/Low-Salinity-Water) in Carbonate and Sandstone Petroleum Reservoirs: Review of Laboratory-Field Studies, Interfacial Mechanisms and Modeling Attempts

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Brine-Dependent Recovery Processes (Smart-Water/Low-Salinity-Water) in Carbonate and Sandstone Petroleum Reservoirs: Review of Laboratory-Field Studies, Interfacial Mechanisms and Modeling Attempts