Applied Sciences-Basel
·
2023
·Vol. 13
·期 9
·5248
·
IF 2.7
Hao Lai,Wei Shi,Junqi Wang,Lei Tang,Nanjun Lai
A low-permeability reservoir contains many fine pore throat structures, which result in excessive injection pressure of the water injection well and difficult water injection in the production process of a low-permeability reservoir. In this study, a new silane coupling agent was synthesized via the ring-opening reaction between dodecyl amine and KH-560 (γ-propyl trimethoxysilane). The modified KH-560 was reacted with nano-SiO2to synthesize the modified nano-SiO2as an antihypertensive additive. Fourier infrared spectroscopy, thermogravimetric analysis and laser scattering were used to characterize this modified nano-SiO2. The results show that the particle size of the modified nano-SiO2is less than 60 nm. The test results of the water contact angle show that the dispersion system can increase the rock contact angle from 37.34° to 136.36°, which makes the rock surface transform from hydrophilicity to hydrophobicity and reduce the binding effect of rock with water. The dispersion test shows that the modified nano-SiO2has good dispersion stability under alkaline conditions with TX-100 (Polyethylene glycol octylphenyl ether) as the dispersant. The antiswelling test results show that the antiswelling rate of this modified nano-SiO2is 42.9%, which can efficiently prevent the clay expansion in the formation to reduce the injection pressure. The core displacement test results show that its depressurization rate reaches 49%. The depressurization rate still maintains 46% at a 20 PV water flow rate, indicating that its depressurization effect is remarkable and it has excellent erosion resistance.Keywords:nano-SiO2;hydrophobicity;ultra-low-permeability reservoir;pressure reduction
研究领域:
石油工程
·
材料科学
·
化学工程
✓ 已验证
产品关联
DOI
高影响因子
ACS Applied Nano Materials
·
2024
·
IF 5.3
Xiaomeng Wang,Fengfan Zhang,Jian Zhang,Guang Wang,Juan Zhang,Meiqin Lin,Zhaoxia Dong,Zihao Yang
Nanomaterials have great potential as novel materials for enhancing oil recovery in low-permeability reservoirs. Spontaneous aggregation hampers their application effectiveness and may lead to irreversible reservoir damage. In this study, monodisperse crumpled SiO2 nanoparticles (C-SiO2) with central radial pore channels were synthesized by using the spherical micelle self-assembly method. After hydrophobic modification, modified C-SiO2 formed a highly stable nanodispersion with the assistance of sodium dodecyl sulfate and octadecanol. Results showed that C-SiO2 exhibited reduced external surface area, increased active sites, and excellent dispersibility. The C-SiO2 dispersion demonstrated excellent temperature tolerance (90 °C) and salt resistance (20000 mg/L, including 4000 mg/L Ca2+), outstanding enhanced oil recovery performance, and negligible reservoir damage. Injecting 0.5 pore volume of the C-SiO2 dispersion at a concentration of 0.025 wt % enhanced oil recovery by 14.25%. The C-SiO2 dispersion effectively mobilized residual oil through the combined action of multiple mechanisms. This study provides an effective approach to enhancing the development of low-permeability reservoirs. It also advances the understanding of C-SiO2 synthesis and stable nanodispersion design, which is crucial for future oil recovery applications.
研究领域:
石油工程
·
材料科学
·
化学工程
✓ 已验证
产品关联
DOI
高影响因子
Petroleum Science
·
2024
·
IF 6
Wei-Peng Wu,Min Yang,Dong-Chen Ma,Ji-Rui Hou,Tuo Liang,Ming Qu,Tao Tan,Biao Yang,Guo-Rui Ma
In-depth profile control is a crucial technique employed to enhance oil recovery in fractured-vuggy carbonate reservoirs. However, it is a challenge to achieve in-depth profile control. In this paper, two types of organic gel systems, namely s-MPG and MSRG, tailored for fractured-vuggy reservoirs with 140 °C and 22 × 10 4 mg/L have been developed. FTIR was used to analyze the functional groups of s-MPG and MSRG. Additionally, the quality retention rates of s-MPG and MSRG were assessed using TG-DSC, yielding results of 92.85% and 92.65%, respectively. The dilution rates of s-MPG and MSRG are found to be 18.69% and 26.69%, respectively, demonstrating excellent compatibility and adaptability. The enhancement performance depends on the synergistic effect that the anti-dilution s-MPG effectively separates bottom water, while high-strength MSRG separates the oil layer. Moreover, the EOR performances of s-MPG synergy with MSRG in various types of fractured-vuggy carbonate models were also evaluated. The highest oil recovery of 12% is achieved in fracture network model. Laboratory results indicate that the synergistic combination of s-MPG and MSRG for water plugging in fractured-vuggy carbonate reservoirs results in a more effective enhancement of oil recovery compared to using a single gel system for plugging. Finally, the s-MPG synergy with MSRG has been applied in actual fractured-vuggy carbonate reservoirs. As expected, the water cut of typical well is reduced from 100% to 30% and the increased oil production is 1142 t totally. Therefore, this study presents a novel approach to achieving in-depth profile control by leveraging the synergistic effect of s-MPG with MSRG in fractured-vuggy carbonate reservoirs.
研究领域:
石油工程
·
化学工程
✓ 已验证
DOI
高影响因子
POWDER TECHNOLOGY
·
2019
·
IF 3.413
Xuechen Tang,Wanli Kang,Bobo Zhou,Yongbo Gao,Changxiao Cao,Shujun Guo,Muhammad Wassem Iqbal,Hongbin Yang
Polymer/nano-SiO 2 composite microspheres (PNSCMs) were synthesized via inverse suspension polymerization with 3-methacryloxypropyltrimethoxysilane (MPS) modified SiO 2 as the reinforcing filler. The influences of these polymerizable nanoparticles on the swelling behavior, mechanical property, thermal stability, viscoelasticity and dispersion stability were examined in detail. Moreover, the plugging behaviors were investigated by sand pack tests. The results indicate that the introduction of these modified nanoparticles revealed a significant enhancement on the comprehensive properties of PNSCMs. By varying the content of MPS-modified SiO 2 , the environmental sensitivity of the microspheres’ swelling behavior was reduced. Besides, the mechanical property, thermal stability and viscoelasticity were greatly improved by increasing the SiO 2 loading. Compared with SiO 2 -free ones, PNSCMs exhibited better dispersion stability and plugging performance, and the maximum plugging rate reached 93.64%, which was increased by 14.69%. These PNSCMs studied can realize in-depth profile control in reservoirs and have great application prospects in the further enhanced oil recovery research.
研究领域:
石油工程
·
材料科学
✓ 已验证
产品关联
DOI
高影响因子
Geoenergy Science and Engineering
·
2024
·
IF 0
Tiantian Zhang,Mingwei Gao,Zhiwen Li,Xiaoyong Wen,Zhiping Li,Lan Wang,Caspar Daniel Adenutsi,Qianru Yang,Qing You
Nanoparticles have been proven to be potential additives for hydraulic fracturing fluid. However, the application of nanoparticle-enhanced fracturing fluid systems in offshore low-permeability reservoirs are limited, and the mechanism by which the corresponding gel breaking fluid enhances oil recovery (EOR) is unclear. In this work, a SiO 2 -enhanced seawater-based viscoelastic surfactant (VES) fracturing fluid system was initially prepared, and the imbibition influencing factors of the SiO 2 -enhanced gel breaking fluid were systematically investigated. Subsequently, the imbibition mechanism by SiO 2 -enhanced gel breaking fluid was explored through examining its synergistic effect on interface properties and the distribution laws of oil-water phases in micropores during the imbibition process. The results showed that proposed system could maintained stability for more than 6 months, and exhibited rheological performance, yielding an increase 26% in temperature/shear resistance. Moreover, the corresponding gel breaking fluid performed an exceptional capacity for imbibition oil production, the oil recovery was increased by 7.92% compared to the conventional gel breaking fluid system and the imbibition time was extended from 30 h to 70 h. The synergistic adsorption of nano-SiO 2 and surfactants on the interface was responsible for wettability alteration and interfacial tension (IFT) reduction. Imbibition primarily occurred in mesopores, nano-SiO 2 reduced the flow resistance of oil-water two phases in pores, and the residual oil within the pores was exceedingly mobilized. This work provides foundation research of application of SiO 2 -enhanced seawater-based VES fracturing fluid in offshore low permeability reservoirs.
研究领域:
石油工程
·
材料科学
✓ 已验证
DOI
Petroleum Science
·
2020
·Vol. 17
·期 6
·1717-1725
·
IF 2.096
Wu Yi-Ning,Li Yuan,Cao Meng-Jiao,Dai Cai-Li,He Long,Yang Yu-Ping
During the development of low or ultra-low permeability oil resources, the alternative energy supply becomes a prominent issue. In recent years, carbon dots (CDs) have drawn much attention owing to their application potential in oil fields for reducing injection pressure and augmenting oil recovery. However, carbon dots characterized of small size, high surface energy are faced with several challenges, such as self-aggregation and settling. The preparation of stably dispersed carbon dots nanofluids is the key factor to guarantee its application performance in formation. In this work, we investigated the stability of hydrophilic carbon dots (HICDs) and hydrophobic carbon dots–Tween 80 (HOCDs) nanofluids. The influences of carbon dots concentration, sorts and concentration of salt ions as well as temperature on the stability of CDs were studied. The results showed that HICDs are more sensitive to sort and concentration of salt ions, while HOCDs are more sensitive to temperature. In addition, the core flooding experiments demonstrated that the pressure reduction rate of HICDs and HOCDs nanofluids can be as high as 17.88% and 26.14%, respectively. Hence, the HICDs and HOCDs nanofluids show a good application potential in the reduction of injection pressure during the development of low and ultra-low permeability oil resources.
研究领域:
石油工程
·
材料科学
✓ 已验证
DOI
高影响因子
JOURNAL OF COLLOID AND INTERFACE SCIENCE
·
2025
·
IF 9.7
Junjie Fan,Jianpeng Cui,Tinglei He,Tianhao Zhang,Xinyu Yuan,Jianwen Hu,Haotian Gao,Hong Zhang,Chunling Li,Songqing Hu,Shuangqing Sun
Carbon dots (CDs), a class of fluorescent nanomaterials distinguished by their unique properties such as tunable surface chemistry and nanoscale dimensions, have garnered significant attention. In this study, we synthesize CDs-based emulsifiers through a combination of hydrothermal synthesis and hydrophobic modification utilizing dynamic covalent imine bonds, imparting them with amphiphilicity and pH-responsiveness. These carbon dot-based emulsifiers stabilize the oil–water interface to form Pickering emulsions and enable the reversible regulation of amphiphilicity through pH-induced cleavage and reformation of imine bonds, thereby facilitating transitions between emulsification and demulsification. Furthermore, the amphiphilic CDs effectively reduce oil–water interfacial tension and exhibit potential application in mobilizing heavy oil in ultra-low permeability reservoirs. Consequently, we observed a 28.78 % decrease in injection pressure and an 18.65 % increase in recovery rates. Experimental and theoretical results reveal that the CDs adsorb onto both solid and oil phase surfaces, modulating the interfacial properties and enabling the oil film attached to the rock wall to be more easily stripped off during water flushing. Additionally, the small size of the CDs allowed them to enter finer pore throats and effectively displace the residual oil film. This unique characteristic holds significant promise for future advancements in the fields of smart-response Pickering emulsions and enhanced oil recovery in ultra-low permeability reservoirs.
研究领域:
材料科学
·
石油工程
·
界面化学
✓ 已验证
产品关联
DOI
PubMed
高影响因子
ACS Omega
·
2024
·
IF 3.7
Pingtian Fan,Yuetian Liu,Yuting He,Yuanping Hu,Leihui Chao,Yapeng Wang,Lang Liu,Jingpeng Li
Currently, research surrounding low-salinity water flooding predominantly focuses on medium- to high-permeability sandstone reservoirs. Nevertheless, further investigation is necessary to implement this technique with regard to tight sandstone reservoirs. The present study comprises a series of experiments conducted on the crude oil and core of the Ordos Chang 6 reservoir to investigate the influence of ionic composition on low-salinity water flooding in tight oil reservoirs. The change in wettability on the rock surface was analyzed by using the contact angle experiment. The change in recovery rate was analyzed using a core displacement experiment. The reaction between rock fluids was analyzed using an ion chromatography experiment. Additionally, a nuclear magnetic resonance (NMR) experiment was used to analyze the mobilization law of crude oil and the change in wettability on the scale of the rock core. This led to a comprehensive discussion of the law and mechanism of enhancing the recovery rate via low-salinity water flooding from various perspectives. Experiments show that low-salinity water flooding is an effective technique for enhancing recovery in tight sandstone reservoirs. Altering the ionic composition of injected water can improve the water wettability of the rock surface and enhance recovery. Decreasing the mass concentration of Ca2+ or increasing the mass concentration of SO42– can prompt the ion-exchange reaction on the rock surface and detachment of polar components from the surface. Consequently, the wettability of the rock surface strengthens, augmenting the recovery process. Nuclear magnetic resonance experiments evidence that low-salinity water injection, with ion adjustment, significantly alters the interactions between the rock and fluid in tight sandstone reservoirs. As a result, the T2 signal amplitude decreases significantly, residual oil saturation reduces considerably, and the hydrophilic nature of the rock surface increases.
研究领域:
石油工程
·
地质学
✓ 已验证
产品关联
DOI
PubMed
高影响因子
RSC Advances
·
2024
·Vol. 14
·期 42
·31183-31192
·
IF 3.9
Zhang Yong-wei,Yang Chang-hua
With high water cuts and high permeability reservoirs entering the middle and late stage, many old oil fields in China are facing the dilemma of oil and gas resource exhaustion, while low-permeability reservoir resources remain very rich. As an oil recovery technology, imbibition displacement plays an important role in the exploitation of low-permeability reservoirs and prolongs the production cycle of old oil fields. Based on the imbibition kinetic equation, the mechanism and process of oil displacement in imbibition recovery are explained in this paper. Based on the characteristics of small particle size and high activity, the influence of temperature, viscosity, permeability, and salinity on the degree of imbibition recovery was studied. The results show that the imbibition production of low-permeability reservoirs mainly depends on capillary force, which firstly drains oil from small pores to large pores, and then drains it by buoyancy. Using nanofluids for imbibition oil recovery, a higher recovery effect of up to 45.59% can be achieved. The change in different external conditions will affect the imbibition recovery effect. The imbibition recovery efficiency increases with the increase in temperature, decreases with the increase in oil viscosity, and increases with the increase in core permeability. The increase in salinity has an inhibiting effect on the imbibition recovery efficiency. Based on the multivariate analysis of variance, the change in permeability has the greatest influence on the degree of imbibition recovery, and the change in viscosity has the least influence on the degree of imbibition recovery.
研究领域:
石油工程
·
地质学
✓ 已验证
产品关联
DOI
PubMed
高影响因子
Journal of Cleaner Production
·
2024
·
IF 9.7
Teng Lu,Zhaomin Li,Liping Du
Within the broader strategy of deep decarbonization, hydrogen stands out as an emerging energy vector poised to influence various sectors. Recognizing that its role is in development and not yet fully realized, our research focuses on the transitional use of depleted oil reservoirs for hydrogen storage and enhanced oil recovery (EOR). While these reservoirs are not geologically superior for hydrogen storage, their established containment capabilities and existing infrastructure offer dual benefits and economic incentives through the valorization of residual oil. To circumvent the limitations of conventional hydrogen injection, such as poor sweep efficiency and premature breakthrough, we propose the use of high-viscosity hydrogen foam. Our experimental data reveals that such foam can significantly enhance oil recovery by 17.95% and increase storage efficiency to 36.2%. These improvements underscore the foam's ability to control hydrogen mobility and optimize sweep efficiency within heterogeneous geological formations. These findings suggest that high-viscosity hydrogen foam could significantly improve the effectiveness of depleted reservoirs for both energy storage and the recovery of residual oil. Looking forward, it is crucial to investigate the long-term integrity of subsurface hydrogen storage, the transition from laboratory to field-scale applications, and the environmental consequences to ensure that this approach is sustainable. Our study serves as an incremental step in recognizing the integral role hydrogen could play in achieving a decarbonized energy future.
研究领域:
石油工程
·
能源科学
·
环境科学
✓ 已验证
产品关联
DOI
高影响因子
Processes
·
2020
·Vol. 8
·期 9
·1021
·
IF 2.753
Daiyin Yin,Shuang Song,Qi Xu,Kai Liu
The matrix/fracture conductivity of a fractured low-permeability reservoir is variable, and its heterogeneity is serious. When carrying out deep profile control measures, it is difficult to inject under the premise of ensuring the plugging effect. According to the characteristics of the fractured low-permeability reservoir in Chaoyanggou Oilfield, the polymer/chromium ion deep profile control system was optimized via a viscosity evaluation experiment, liquidity experiment and oil displacement experiment. The experimental results show that the high molecular weight main agent/low concentration system and low molecular weight main agent/high concentration system can meet the gel strength requirement. The evaluation results of the injection ability and plugging performance of the fractured low-permeability core show that a high molecular weight profile control system is difficult to inject, while a low molecular weight profile control system has a poor plugging performance and high cost after simulated shear. Therefore, the formulation of the profile control system was determined to be a polymer with a molecular weight of 16 million g·mol−1as the main agent with a concentration of 1000–1500 mg·L−1. As assisting agents, the concentrations of thiourea, NaCl and NaHCO3were 900 mg·L−1, 800 mg·L−1and 700 mg·L−1, respectively. The plugging rate of the system was 87.6%, and the resistance coefficient was 19.2. Finally, a fractured low-permeability core model with parallel long cores was designed, and the optimal profile control system was used for the core oil-displacement experiment. Compared with the water-flooding experiment, the plugging rate can be increased by 6.9–8.0%.Keywords:fractured low-permeability reservoirs;polymer/chromium-ion;deep profile control system
研究领域:
石油工程
·
化学工程
✓ 已验证
产品关联
DOI
高影响因子
CHEMICAL ENGINEERING JOURNAL
·
2022
·
IF 16.744
Zhongzheng Xu,Mingwei Zhao,Yiming Zhang,Pan Wang,Yining Wu,Lin Li,Xin Cui,Ning Sun,Caili Dai
Superhydrophobic wettability inspired by the “lotus effect” is an intriguing property in nature, but it is rarely applied in oilfield development. Superhydrophobic nanomaterials can effectively solve the problem of “high injection pressure and insufficient water injection” in low permeability oilfields by changing the properties of the core surface, which is of great significance to the development of low permeability oilfields. Herein, we report a novel type of superhydrophobic nanoparticle (SHNP) simply modified by fluorinated long chains, and a stable nanofluid is successfully prepared by compounding surfactant. The prepared SHNP nanofluid has an excellent core drag reduction effect, and the drag reduction rate is 1.35 times that of conventional NPs under the same conditions. The SHNPs assemble on the core surface to form a large number of micro/nanorough structures, which can effectively reduce the surface roughness of the core. The PIV experimental results show that compared with the injection of pure water, the center flow velocity in the subsequent water flooding center increases by 98.27% after the injection of SHNPs nanofluid (the flow velocity decreases by 53.45% after the injection of NPs). Moreover, bubble probe AFM technology has successfully shown that bubbles can be captured through the SHNPs superhydrophobic interface to form a gaseous film. By using the barrier effect of the gaseous film, the liquid–solid interface is converted to a liquid–gas-solid interface, thereby reducing the large resistance caused by the direct contact between the liquid and solid. Such SHNPs with simple modification and low cost have broad application potential in oilfield development.
研究领域:
石油工程
·
材料科学
·
界面化学
✓ 已验证
产品关联
DOI
高影响因子
危险品化学品经营许可证（带存储）