Combined imbibition system with black nanosheet and low-salinity water for improving oil recovery in tight sandstone reservoirs

Zhu, Daoyi; Zhao, Yu-Heng; Zhang, Hongjun; Zhao, Qi; Shi, Chenyang; Qin, Junhui; Su, Zhenghao; Wang, Guiqi; Liu, Yang; Hou, Jirui

doi:10.1016/j.petsci.2022.12.004

Cited by 10 publications

(11 citation statements)

References 36 publications

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“…The research object of this study is the shale oil reservoirs of the Lucaogou Formation in the Jimsar Sag, Xinjiang oilfield. The reservoir has the geological characteristics of integrated source and storage, and a dispersed “sweet spot”, with an average reservoir temperature of 80 °C [ 54 , 55 ] and an original formation pressure of about 40 MPa [ 56 , 57 ]. The Luchaogou Formation (P 2 l) consists of upper (P 2 l 2 ) and lower (P 2 l 1 ) sections, each with its own “sweet spot” enrichment sections.…”

Section: Models and Methodologymentioning

confidence: 99%

Study on the Effects of Wettability and Pressure in Shale Matrix Nanopore Imbibition during Shut-in Process by Molecular Dynamics Simulations

Jiang,

Lv,

Jia

et al. 2024

Molecules

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Shut-in after fracturing is generally adopted for wells in shale oil reservoirs, and imbibition occurring in matrix nanopores has been proven as an effective way to improve recovery. In this research, a molecular dynamics (MD) simulation was used to investigate the effects of wettability and pressure on nanopore imbibition during shut-in for a typical shale reservoir, Jimsar. The results indicate that the microscopic advancement mechanism of the imbibition front is the competitive adsorption between “interfacial water molecules” at the imbibition front and “adsorbed oil molecules” on the pore wall. The essence of spontaneous imbibition involves the adsorption and aggregation of water molecules onto the hydroxyl groups on the pore wall. The flow characteristics of shale oil suggest that the overall push of the injected water to the oil phase is the main reason for the displacement of adsorbed oil molecules. Thus, shale oil, especially the heavy hydrocarbon component in the adsorbed layer, tends to slip on the walls. However, the weak slip ability of heavy components on the wall surface is an important reason that restricts the displacement efficiency of shale oil during spontaneous imbibition. The effectiveness of spontaneous imbibition is strongly dependent on the hydrophilicity of the matrix pore’s wall. The better hydrophilicity of the matrix pore wall facilitates higher levels of adsorption and accumulation of water molecules on the pore wall and requires less time for “interfacial water molecules” to compete with adsorbed oil molecules. During the forced imbibition process, the pressure difference acts on both the bulk oil and the boundary adsorption oil, but mainly on the bulk oil, which leads to the occurrence of wetting hysteresis. Meanwhile, shale oil still existing in the pore always maintains a good, stratified adsorption structure. Because of the wetting hysteresis phenomenon, as the pressure difference increases, the imbibition effect gradually increases, but the actual capillary pressure gradually decreases and there is a loss in the imbibition velocity relative to the theoretical value. Simultaneously, the decline in hydrophilicity further weakens the synergistic effect on the imbibition of the pressure difference because of the more pronounced wetting hysteresis. Thus, selecting an appropriate well pressure enables cost savings and maximizes the utilization of the formation’s natural power for enhanced oil recovery (EOR).

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Section: Models and Methodologymentioning

confidence: 99%

Study on the Effects of Wettability and Pressure in Shale Matrix Nanopore Imbibition during Shut-in Process by Molecular Dynamics Simulations

Jiang,

Lv,

Jia

et al. 2024

Molecules

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“…Moreover, nanoparticles exhibit enhanced stability in low-salinity water, leading to synergistic effects that can significantly improve the recovery rates. Studies have shown that this combination results in a more stable water film on the rock surfaces, thereby increasing the water-wet nature of the rock surface and enhancing wave efficiency. − Nanoparticles play a crucial role in alleviating colloidal particle transport associated with low-salinity waterflooding. They mitigate the migration of fine particles, increase nanoparticle stability in water, facilitate adsorption on rock surfaces, and reduce capillary forces. , Additionally, nanoparticles can change the surface properties of monovalent and divalent ions in low-salinity water, thereby altering wettability more effectively .…”

Section: Introductionmentioning

confidence: 99%

Study of Interfacial Phenomena of High Asphaltene Crude Oil with Different Salinity Water and ZrO₂ Nanoparticles

WANG,

HE,

XUE

et al. 2024

Energy Fuels

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In recent years, low-salinity waterflooding and nanofluid flooding have been regarded as the new technologies for enhanced oil recovery and research (EOR). Research on the mechanisms behind the improvement in the recovery rate has garnered significant attention. However, little attention has been given to the mechanism of low-salinity water within the highsalinity range and the synergistic mechanism between low-salinity water and nanoparticles. In the salinity range of 0−22,0,000 mg/L, the interfacial properties of different concentrations of Na + , Mg 2+ , Ca 2+ , and SO 4 2− were investigated. The following conclusions were drawn: interfacial tension (IFT) gradually decreased at elevated temperatures, reaching a minimum value of 14.9 mN/m for 2000 mg/L low-salinity water at 60 °C. The contact angle decreased significantly at increased temperatures, reaching a minimum value of 64.8°for the contact angle of 2000 mg/L low-salinity water at 60 °C, indicating water-wet wettability. Electrostatic repulsion was the highest for 5000 mg/L low-salinity water, with a zeta potential value of −12.56 mV. Furthermore, Na + significantly affected IFT and zeta potential values at low concentrations, while Ca 2+ exhibited a more significant effect on wettability at low concentrations. Additionally, when utilizing 2000 mg/L low-salinity water as the dispersion medium for ZrO 2 nanoparticles, increasing the particle concentration negatively impacted the stability of the nanofluid. As the temperature increased, IFT decreased, reaching a minimum value of 14.27 mN/m at a concentration of 0.01 wt % at 60 °C. Similarly, as the temperature increased, the contact angle decreased, with nanofluids at a concentration of 0.014 wt %, exhibiting the lowest contact angle of 51°at 60 °C, indicating increased water-wet wettability of the rock surface. This study offered a fundamental understanding of interfacial phenomena involving low-salinity water and nanoparticles, indicating their potential for EOR technology.

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“…When the concentration of amphiphilic molybdenum disulfide (KH550-MoS 2 ) nanosheets was 0.005%, the interfacial tension with crude oil decreased to 2.6 mN/m, and the contact angle decreased from 131.2 to 51.7°. Zhu et al 24 proposed a composite oil displacement system of BN and low-mineralization water (LSW) based on BNs. BN-LSW can give full play to the synergistic effect of the two.…”

Section: Introductionmentioning

confidence: 99%

Dispersion Stability and Oil Displacement Effect of Modified Black Nanosheet

Zhu,

Qin,

Gao

et al. 2024

Energy Fuels

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Combined imbibition system with black nanosheet and low-salinity water for improving oil recovery in tight sandstone reservoirs

Cited by 10 publications

References 36 publications

Study on the Effects of Wettability and Pressure in Shale Matrix Nanopore Imbibition during Shut-in Process by Molecular Dynamics Simulations

Study on the Effects of Wettability and Pressure in Shale Matrix Nanopore Imbibition during Shut-in Process by Molecular Dynamics Simulations

Study of Interfacial Phenomena of High Asphaltene Crude Oil with Different Salinity Water and ZrO₂ Nanoparticles

Dispersion Stability and Oil Displacement Effect of Modified Black Nanosheet

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Combined imbibition system with black nanosheet and low-salinity water for improving oil recovery in tight sandstone reservoirs

Cited by 10 publications

References 36 publications

Study on the Effects of Wettability and Pressure in Shale Matrix Nanopore Imbibition during Shut-in Process by Molecular Dynamics Simulations

Study on the Effects of Wettability and Pressure in Shale Matrix Nanopore Imbibition during Shut-in Process by Molecular Dynamics Simulations

Study of Interfacial Phenomena of High Asphaltene Crude Oil with Different Salinity Water and ZrO2 Nanoparticles

Dispersion Stability and Oil Displacement Effect of Modified Black Nanosheet

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Product

Resources

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Study of Interfacial Phenomena of High Asphaltene Crude Oil with Different Salinity Water and ZrO₂ Nanoparticles