Interfacial tension from the height and diameter of sessile drops and captive bubbles with an arbitrary contact angle

AbstractThe ultra-low permeability reservoir is regarded as an important energy source for oil and gas resource development and is attracting more and more attention. In this work, the active silica nanofluids were prepared by modified active silica nanoparticles and surfactant BSSB-12. The dispersion stability tests showed that the hydraulic radius of nanofluids was 58.59 nm and the zeta potential was − 48.39 mV. The active nanofluids can simultaneously regulate liquid–liquid interface and solid–liquid interface. The nanofluids can reduce the oil/water interfacial tension (IFT) from 23.5 to 6.7 mN/m, and the oil/water/solid contact angle was altered from 42° to 145°. The spontaneous imbibition tests showed that the oil recovery of 0.1 wt% active nanofluids was 20.5% and 8.5% higher than that of 3 wt% NaCl solution and 0.1 wt% BSSB-12 solution. Finally, the effects of nanofluids on dynamic contact angle, dynamic interfacial tension and moduli were studied from the adsorption behavior of nanofluids at solid–liquid and liquid–liquid interface. The oil detaching and transporting are completed by synergistic effect of wettability alteration and interfacial tension reduction. The findings of this study can help in better understanding of active nanofluids for EOR in ultra-low permeability reservoirs.

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Determination of the peripheral contact angle of sessile drops on solids from the rate of evaporation

Apparent and Microscopic Contact Angles ◽

10.1201/b11962-33 ◽

2014 ◽

pp. 457-466

Keyword(s):

Contact Angle ◽

Rate Of Evaporation ◽

Sessile Drops

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Interfacial Behaviour in Ferroalloys: The Influence of Sulfur in FeMn and SiMn Systems

Metallurgical and Materials Transactions B ◽

10.1007/s11663-021-02323-2 ◽

2021 ◽

Author(s):

Sergey Bublik ◽

Sarina Bao ◽

Merete Tangstad ◽

Kristian Etienne Einarsrud

Keyword(s):

Contact Angle ◽

Interfacial Tension ◽

Sessile Drop ◽

Interfacial Properties ◽

Apparent Contact Angle ◽

Holding Time ◽

Transfer Rates ◽

Experimental Parameters ◽

Interfacial Behaviour ◽

Modelling Approach

AbstractThe present study has investigated the influence of sulfur content in synthetic FeMn and SiMn from 0 to 1.00 wt pct on interfacial properties between these ferroalloys and slags. The effect of experimental parameters such as temperature and holding time was evaluated. Interfacial interaction between ferroalloys and slags was characterized by interfacial tension and apparent contact angle between metal and slag, measured based on the Young–Laplace equation and an inverse modelling approach developed in OpenFOAM. The results show that sulfur has a significant influence on both interfacial tension and apparent contact angle, decreasing both values and promoting the formation of a metal-slag mixture. Despite the fact that sulfur was added only to the ferroalloys, most of sulfur is distributed into slag after reactions with the metal phase. Increasing the maximum experimental temperature in the sessile drop furnace also resulted in a decrease of both interfacial properties, resulting in higher mass transfer rates and intensive reactions between metal and slag. The effect of holding time demonstrated that after reaching equilibrium in FeMn-slag and SiMn-slag systems (both with and without sulfur), interfacial tension and apparent contact angle remain constant.

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Carbon dioxide adsorption and interaction with formation fluids of Jordanian unconventional reservoirs

Journal of Petroleum Exploration and Production Technology ◽

10.1007/s13202-021-01333-9 ◽

2021 ◽

Author(s):

H. Samara ◽

T. V. Ostrowski ◽

F. Ayad Abdulkareem ◽

E. Padmanabhan ◽

P. Jaeger

Keyword(s):

Carbon Dioxide ◽

Contact Angle ◽

Interfacial Tension ◽

Oil Recovery ◽

Gas Adsorption ◽

Sessile Drop ◽

Global Climate ◽

Gravimetric Method ◽

Rock Surface ◽

Operating Pressure

AbstractShales are mostly unexploited energy resources. However, the extraction and production of their hydrocarbons require innovative methods. Applications involving carbon dioxide in shales could combine its potential use in oil recovery with its storage in view of its impact on global climate. The success of these approaches highly depends on various mechanisms taking place in the rock pores simultaneously. In this work, properties governing these mechanisms are presented at technically relevant conditions. The pendant and sessile drop methods are utilized to measure interfacial tension and wettability, respectively. The gravimetric method is used to quantify CO2 adsorption capacity of shale and gas adsorption kinetics is evaluated to determine diffusion coefficients. It is found that interfacial properties are strongly affected by the operating pressure. The oil-CO2 interfacial tension shows a decrease from approx. 21 mN/m at 0.1 MPa to around 3 mN/m at 20 MPa. A similar trend is observed in brine-CO2 systems. The diffusion coefficient is observed to slightly increase with pressure at supercritical conditions. Finally, the contact angle is found to be directly related to the gas adsorption at the rock surface: Up to 3.8 wt% of CO2 is adsorbed on the shale surface at 20 MPa and 60 °C where a maximum in contact angle is also found. To the best of the author’s knowledge, the affinity of calcite-rich surfaces toward CO2 adsorption is linked experimentally to the wetting behavior for the first time. The results are discussed in terms of CO2 storage scenarios occurring optimally at 20 MPa.

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A new slick water system for hydraulic fracturing in tight reservoir to enhance imbibition oil recovery

E3S Web of Conferences ◽

10.1051/e3sconf/202130301001 ◽

2021 ◽

Vol 303 ◽

pp. 01001

Author(s):

Yu Haiyang ◽

Ji Wenjuan ◽

Luo Cheng ◽

Lu Junkai ◽

Yan Fei ◽

...

Keyword(s):

Contact Angle ◽

Interfacial Tension ◽

Hydraulic Fracturing ◽

Oil Recovery ◽

Water System ◽

Natural Fracture ◽

Fracturing Fluid ◽

The Core ◽

Ultralow Permeability

In order to give full play to the role of imbibition of capillary force and enhance oil recovery of ultralow permeability sandstone reservoir after hydraulic fracturing, the mixed water fracture technology based on functional slick water is described and successfully applied to several wells in oilfield. The core of the technology is determination of influence factors of imbibition oil recovery, the development of new functional slick water system and optimization of volume fracturing parameters. The imbibition results show that it is significant effect of interfacial tension, wetting on imbibition oil recovery. The interfacial tension decreases by an order of magnitude, the imbibition oil recovery reduces by more than 10%. The imbibition oil recovery increases with the contact angle decreasing. The emulsifying ability has no obvious effect on imbibition oil recovery. The functional slick water system considering imbibition is developed based on the solution rheology and polymer chemistry. The system has introduced the active group and temperature resistant group into the polymer molecules. The molecular weight is controlled in 1.5 million. The viscosity is greater than 2mPa·s after shearing 2h under 170s-1 and 100℃. The interfacial tension could decrease to 10-2mN/m. The contact angle decreased from 58° to 22° and the core damage rate is less than 12%. The imbibition oil recovery could reach to 43%. The fracturing process includes slick water stage and linear gel stage. 10% 100 mesh ceramists and 8% temporary plugging agents are carried into the formation by functional slick water. 40-70 mesh ceramists are carried by linear gel. The liquid volume ratio is about 4:1 and the displacement is controlled at 10-12m3/min. The sand content and fracturing fluid volumes of single stage are 80m3 and 2500 m3 respectively. Compared with conventional fracturing, due to imbibition oil recovery, there is only 25% of the fracturing fluid flowback rate when the crude oil flew out. When the oil well is in normal production, about 50% of the fracturing fluid is not returned. It is useful to maintain the formation energy and slow down the production decline. The average cumulative production of vertical wells is greater than 2800t, and the effective period is more than 2 years. This technology overcoming the problem of high horizontal stress difference and lack of natural fracture has been successfully applied in Jidong Oilfield ultralow permeability reservoir. The successful application of this technology not only helps to promote the effective use of ultralow permeability reservoirs, but also helps to further clarify the role of imbibition recovery, energy storage and oil-water replacement mechanism.

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Nanoparticle-induced ion-sensitive reduction in decane–water interfacial tension

Physical Chemistry Chemical Physics ◽

10.1039/c8cp04041a ◽

2018 ◽

Vol 20 (35) ◽

pp. 22796-22804 ◽

Cited By ~ 7

Author(s):

Boyao Wen ◽

Chengzhen Sun ◽

Bofeng Bai

Keyword(s):

Contact Angle ◽

Interfacial Tension

The ion-sensitive contact angle and interaction between nanoparticles at the interface are responsible for the reduction of interfacial tension.

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Interfacial tension and equilibrium contact angle of corn oil on polished stainless steel in supercritical CO2 and N2

The Journal of Supercritical Fluids ◽

10.1016/j.supflu.2019.104665 ◽

2020 ◽

Vol 156 ◽

pp. 104665

Author(s):

Eileen Santos ◽

Prashant R. Waghmare ◽

Feral Temelli

Keyword(s):

Contact Angle ◽

Stainless Steel ◽

Interfacial Tension ◽

Supercritical Co2 ◽

Corn Oil ◽

Equilibrium Contact Angle ◽

Polished Stainless Steel

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A Core Flood and Microfluidics Investigation of Nanocellulose as a Chemical Additive to Water Flooding for EOR

Nanomaterials ◽

10.3390/nano10071296 ◽

2020 ◽

Vol 10 (7) ◽

pp. 1296 ◽

Cited By ~ 1

Author(s):

Reidun C. Aadland ◽

Salem Akarri ◽

Ellinor B. Heggset ◽

Kristin Syverud ◽

Ole Torsæter

Keyword(s):

Contact Angle ◽

Interfacial Tension ◽

Oil Recovery ◽

Cellulose Nanofibrils ◽

Water Flooding ◽

Low Salinity ◽

The Core ◽

Low Salinity Water ◽

Salinity Water ◽

Core Flood

Cellulose nanocrystals (CNCs) and 2,2,6,6-tetramethylpiperidine-1-oxyl (TEMPO)-oxidized cellulose nanofibrils (T-CNFs) were tested as enhanced oil recovery (EOR) agents through core floods and microfluidic experiments. Both particles were mixed with low salinity water (LSW). The core floods were grouped into three parts based on the research objectives. In Part 1, secondary core flood using CNCs was compared to regular water flooding at fixed conditions, by reusing the same core plug to maintain the same pore structure. CNCs produced 5.8% of original oil in place (OOIP) more oil than LSW. For Part 2, the effect of injection scheme, temperature, and rock wettability was investigated using CNCs. The same trend was observed for the secondary floods, with CNCs performing better than their parallel experiment using LSW. Furthermore, the particles seemed to perform better under mixed-wet conditions. Additional oil (2.9–15.7% of OOIP) was produced when CNCs were injected as a tertiary EOR agent, with more incremental oil produced at high temperature. In the final part, the effect of particle type was studied. T-CNFs produced significantly more oil compared to CNCs. However, the injection of T-CNF particles resulted in a steep increase in pressure, which never stabilized. Furthermore, a filter cake was observed at the core face after the experiment was completed. Microfluidic experiments showed that both T-CNF and CNC nanofluids led to a better sweep efficiency compared to low salinity water flooding. T-CNF particles showed the ability to enhance the oil recovery by breaking up events and reducing the trapping efficiency of the porous medium. A higher flow rate resulted in lower oil recovery factors and higher remaining oil connectivity. Contact angle and interfacial tension measurements were conducted to understand the oil recovery mechanisms. CNCs altered the interfacial tension the most, while T-CNFs had the largest effect on the contact angle. However, the changes were not significant enough for them to be considered primary EOR mechanisms.

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