Experimental study of oil recovery mechanisms during imbibition in tight sandstone with different fluid displacing agents under ambient and reservoir pressure

Yinghe, Chen; Wei, Jiang; Hadavimoghaddam, Fahimeh; Zhou, Xiaofeng; Ostadhassan, Mehdi; Zhao, Xinfang; Gayubov, Abdumalik; Li, Jiangtao; Wang, Anlun; Yang, Ying‐Wei; Shi, Xuedong

doi:10.1016/j.petrol.2022.111181

Cited by 9 publications

(5 citation statements)

References 23 publications

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“…Many studies have shown that in surfactant flooding, the lower the interface tension between oil displacement agent and crude oil, the higher the oil displacement efficiency of the oil displacement agent. − The effects of the different concentrations ANCC on the interface tension of saponin were observed, as shown in Figure . It can be seen from Figure a that with the increase of salinity, the interface tension first decreased and then increased.…”

Section: Resultsmentioning

confidence: 99%

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Effect of Amphiphilic CaCO₃ Nanoparticles on the Plant Surfactant Saponin Solution on the Oil–Water Interface: A Feasibility Research of Enhanced Oil Recovery

Tian,

Pu,

Wang

et al. 2023

Energy Fuels

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In order to solve the serious problem of oil shortage, the improvement of the emulsification effect of surfactants using nanoparticles was proposed to enhance oil recovery. In this work, first, an amphiphilic nano-calcium carbonate (ANCC) was synthesized, and the dispersion effect of ANCC in saponin solution was studied. It can be found from results that the dispersion effect of ANCC was the best in 5000 ppm of saponin solution, and the dispersion rate decreased with the increase of salinity. Then, the effect of ANCC on the emulsion property, interface tension, and expansion modulus of saponin solution was studied. It can be found from results that with the increase of ANCC concentration, the emulsion rate between saponin and crude oil increased, the water extraction rate decreased, the emulsion particle size decreased, the interface tension decreased, the expansion modulus increased, and the emulsion stability became better. At the same time, with the increase of temperature, the interface tension decreased, and the expansion modulus increased. With the increase of salinity, the interface tension decreased first and then increased, and the expansion modulus decreased. Finally, the effect of ANCC on the oil recovery of saponin solution flooding was studied by displacement experiments. It can be found from results that when the ANCC concentration was 100, 500, and 1000 ppm, the oil recovery was increased, respectively, by 18.42, 20.97, and 24.59%, indicating that the oil recovery gradually increased with the increase of the concentration of ANCC. This work is of great significance for enhanced oil recovery in surfactant flooding.

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Section: Resultsmentioning

confidence: 99%

“…The nano-surfactant fluids and crude oil (0.5∼1 μL) were injected into the sample pipe, and the interface tension was measured at 6000 r/min and 30 °C. In addition, the interface tension of nano-surfactant fluids was measured at different temperatures (30,40,50,60,70, and 80 °C), and NaCl was not added.…”

Section: Emulsion Property Experimentmentioning

confidence: 99%

Effect of Amphiphilic CaCO₃ Nanoparticles on the Plant Surfactant Saponin Solution on the Oil–Water Interface: A Feasibility Research of Enhanced Oil Recovery

Tian,

Pu,

Wang

et al. 2023

Energy Fuels

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“…The shale reservoir numerical simulation method − comprehensively considers the multiscale flow of shale oil, the stress-sensitive effect, and the coupling of the fluid flow and geomechanics in the shale reservoir. It can simulate the imbibition mechanism in the fracturing production process based on the finite difference method. − During numerical simulation, the imbibition effect in the reservoir matrix may be characterized by setting the capillary pressure and relative permeability. However, it is still difficult to take into account the influence of the chemical osmotic pressure in the simulation software.…”

Section: Methodsmentioning

confidence: 99%

Imbibition Mechanisms of Fracturing Fluid in Shale Oil Formation: A Review from the Multiscale Perspective

et al. 2023

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The breakthrough of shale oil in North America led to a worldwide energy revolution. Shale reservoirs show multiscale properties and a large proportion of nanopores compared to conventional reservoirs, which makes the imbibition mechanisms of fracturing fluids within shale reservoirs exceptionally complicated. For instance, the fracturing fluid shows a distinct imbibition behavior at different scales. Traditional models face significant challenges in imbibition characterization. Understanding the imbibition mechanisms in shale oil formations from a multiscale perspective can help to make full use of the positive effect and enhance oil recovery. We review imbibition mechanisms in shale reservoirs from the nanoscale to the reservoir scale. The imbibition principles in a single nanopore and the improvement of the traditional characterization models are clarified. Then, at the pore scale, we elaborate on the imbibition laws obtained from the microfluidic chip, pore network model, and direct simulations. We also outline the imbibition dynamics at the core scale, the influences of capillary forces and osmotic pressure, and the variations of the pore structure. Finally, the imbibition behavior at the reservoir scale and field examples considering the imbibition effect are introduced. We analyze the existing problems on each scale and discuss the future trends in this area. This work is expected to help readers systematically understand the mechanisms and behavior of fracturing fluid imbibition in shale oil reservoirs at different scales and accelerate the exploitation of shale resources.

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“…(3) As the proportion of water in the produced fluid gradually increases, the displacement pressure gradually decreases to a stable stage. (4) After injecting 0.2 vol.% nanofluid, the displacement pressure 5) The particles in the nanofluid cause a transient high pressure during the initial stage of waterflooding by pore blockage, but as the blocked pores are cleared, the pressure gradually decreases and stabilizes [24]. The subsequent waterflooding pressure is lower than the waterflooding pressure without nanofluid, indicating that the 0.2 vol.% nanofluid indeed has a pressure reduction and enhanced oil recovery effect.…”

Section: Characteristics Of Nanofluid Displacementmentioning

confidence: 99%

An Experimental Study on the Effect of a Nanofluid on Oil-Water Relative Permeability

Tian,

Zhao,

et al. 2024

FDMP

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The low porosity and low permeability of tight oil reservoirs call for improvements in the current technologies for oil recovery. Traditional chemical solutions with large molecular size cannot effectively flow through the nanopores of the reservoir. In this study, the feasibility of Nanofluids has been investigated using a high pressure high temperature core-holder and nuclear magnetic resonance (NMR). The results of the experiments indicate that the specified Nanofluids can enhance the tight oil recovery significantly. The water and oil relative permeability curve shifts to the high water saturation side after Nanofluid flooding, thereby demonstrating an increase in the water wettability of the core. In the Nanofluid flooding process the oil recovery was enhanced by 15.1%, compared to waterflooding stage. The T2 spectra using the NMR show that after Nanofluid flooding, a 7.18% increment in oil recovery factor was gained in the small pores, a 4.9% increase in the middle pores, and a 0.29% increase in the large pores. These results confirm that the Nanofluids can improve the flow state in micro-sized pores inside the core and increase the ultimate oil recovery factor.

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Experimental study of oil recovery mechanisms during imbibition in tight sandstone with different fluid displacing agents under ambient and reservoir pressure

Cited by 9 publications

References 23 publications

Effect of Amphiphilic CaCO₃ Nanoparticles on the Plant Surfactant Saponin Solution on the Oil–Water Interface: A Feasibility Research of Enhanced Oil Recovery

Effect of Amphiphilic CaCO₃ Nanoparticles on the Plant Surfactant Saponin Solution on the Oil–Water Interface: A Feasibility Research of Enhanced Oil Recovery

Imbibition Mechanisms of Fracturing Fluid in Shale Oil Formation: A Review from the Multiscale Perspective

An Experimental Study on the Effect of a Nanofluid on Oil-Water Relative Permeability

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Experimental study of oil recovery mechanisms during imbibition in tight sandstone with different fluid displacing agents under ambient and reservoir pressure

Cited by 9 publications

References 23 publications

Effect of Amphiphilic CaCO3 Nanoparticles on the Plant Surfactant Saponin Solution on the Oil–Water Interface: A Feasibility Research of Enhanced Oil Recovery

Effect of Amphiphilic CaCO3 Nanoparticles on the Plant Surfactant Saponin Solution on the Oil–Water Interface: A Feasibility Research of Enhanced Oil Recovery

Imbibition Mechanisms of Fracturing Fluid in Shale Oil Formation: A Review from the Multiscale Perspective

An Experimental Study on the Effect of a Nanofluid on Oil-Water Relative Permeability

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Effect of Amphiphilic CaCO₃ Nanoparticles on the Plant Surfactant Saponin Solution on the Oil–Water Interface: A Feasibility Research of Enhanced Oil Recovery

Effect of Amphiphilic CaCO₃ Nanoparticles on the Plant Surfactant Saponin Solution on the Oil–Water Interface: A Feasibility Research of Enhanced Oil Recovery