Energies
·
2024
·Vol. 17
·期 23
·6092
·
IF 3
Shupei Zhao,Meilong Fu,Jun Chen,Zhaoxing Li,Jiayi Lin,Shuo Zhang,Pengju Wang
Alternating carbon dioxide and water flooding can not only seal greenhouse gases, but also combine the advantages of water flooding and carbon dioxide flooding, and can well control mobility and stabilize the displacement front, thereby greatly improving the macro-replacing efficiency. In order to further improve the development effect of water–carbon dioxide alternating flooding, this paper, based on sufficient collection of the literature, research, and analysis, pre-uses modified water instead of water, and deeply explores and studies the impact of modified water–carbon dioxide alternating flooding on the improvement of development effect and the mechanism of enhancing oil recovery in low-permeability reservoirs. The main work completed is as follows: (1) A comparative experiment of multiple groups of sand-filled tubes with different displacement media, modified water concentrations, and injection plug sizes was conducted under the conditions of simulating reservoir formation temperature of 70 °C and formation pressure of 18 MPa, and the optimal scheme and injection parameters of alternating modified water and carbon dioxide flooding were rationally selected. The results show that the alternating flooding of modified water and carbon dioxide in low-permeability reservoirs can significantly improve the development effect. The optimal injection parameters are a formulation concentration of 0.3% and an injection method of alternating a 0.1 PV slug injection of carbon dioxide and modified water. (2) Using Berea cores instead of sand-fill tubes, a comparative experiment of alternating oil displacement using carbon dioxide and modified water was carried out under the same experimental conditions. Nuclear magnetic resonance measurements were performed on five of the cores to analyze the microscopic oil displacement mechanisms of different displacement media. The results show the following: nuclear magnetic resonance testing shows that carbon dioxide displacement can greatly improve the oil recovery efficiency in tiny pores (about 47.43%); alternating injection can further improve the oil recovery efficiency in tiny pores (about 70.6%); and modified water can improve the oil recovery efficiency in larger pores (about 56.47%).
研究领域:
石油工程
·
地质学
✓ 已验证
产品关联
DOI
高影响因子
Frontiers in Chemistry
·
2025
·
IF 4.2
Jiangtao Wang,Yingxue Hu,Xiaoyue Chu,Gangzheng Sun,Tao Lu
Surfactant flooding is an effective chemical enhanced oil recovery (EOR) technique, but the quantitative roles of viscosity and interfacial tension (IFT) in residual oil mobilization remain unclear. In this study, the physicochemical properties of surfactant solutions were first characterized by systematic measurements of viscosity and IFT, and the dynamic mechanisms of water flooding and surfactant flooding were further investigated using a pore–throat model, consisting of channels with and without pore-like structures, combined with direct numerical simulations to identify viscosity and IFT thresholds under different wettability conditions. The results show that residual oil distribution is strongly influenced by wettability: in strongly water-wet and neutral-wet conditions, oil remains as droplet- or cluster-like ganglia within pore spaces, whereas in strongly oil-wet conditions it persists as continuous wall-adhered films that are more stable and difficult to mobilize. Mechanistic analysis further indicates that the controlling parameters of mobilization differ across wettability states, reflecting the interplay between pore geometry, wettability, and interfacial forces. Based on phase diagrams constructed from simulation results, distinct regulation strategies were formulated for different wettability conditions: reducing IFT is most effective in strongly water-wet systems, a combined effect of viscosity enhancement and IFT reduction is required in neutral-wet systems, and achieving ultra-low IFT is essential in strongly oil-wet systems. Collectively, this work establishes viscosity and IFT thresholds as quantitative design criteria for surfactant flooding, providing both mechanistic understanding and practical guidance for surfactant formulation and injection optimization in chemical EOR.
研究领域:
石油工程
·
提高采收率
·
界面化学
·
多孔介质流动
·
流体力学
✓ 已验证
产品关联
DOI
PubMed
高影响因子
Materia-Rio de Janeiro
·
2025
·
IF 1.2
Yu Meng,Xu Guorui,Li Liang,Zhou Jingjing,Tie Leilei,Zhang Bo,Ma Xiaofei,Feng Xuan,Yang Jinzhou,Wang Lei,Li Weizhi,Zheng Yufei,Wu Bao
VISUAL
研究领域:
石油工程
·
油田化学
·
提高采收率
·
油藏工程
✓ 已验证
产品关联
DOI
高影响因子
COLLOIDS AND SURFACES A-PHYSICOCHEMICAL AND ENGINEERING ASPECTS
·
2021
·
IF 4.539
Jie Cao,Jia Wang,Xiujun Wang,Jian Zhang,Kun Liu,Yixin Wang,Weikun Zhen,Yingpeng Chen
In this study, 3-aminopropyltriethoxysilane (APTES) and octyltriethoxysilane (OTES) reacted with nano-silica (NS), and the hydrophobicity , wettability and oil displacement performance of the modified nanoparticles (OAS) were changed by adjusting the amount of OTES. The synthesized amphiphilic silica was characterized by elemental analysis , flourier transform infrared spectrometer (FT-IR), thermogravimetric analysis (TG) and transmission electron microscopy (TEM). The results showed that the modification of silica was successful and showed different changes with the increase of the amount of modifier OTES. Besides, zeta potential , particle size measurement and transmission electron microscopy results show that OAS particles can maintain good stability. OAS-3 particles can change the core wettability from oil wet to neutral wet, and can significantly reduce the interfacial tension, which reduce the interfacial tension from 14.9 mN/m to 10.4 mN/m. In addition, the OAS particles also have a good emulsification effect, which can keep the emulsion stable for a long time. In the core flooding experiment, the modified amphiphilic silica particles can improve oil recovery. Compared with NS, OAS-3 particles have the best oil displacement effect, and the oil recovery can be increased by 10.3%. which has a certain potential in the application of enhanced oil recovery.
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
Polymers
·
2022
·Vol. 14
·期 13
·2599
·
IF 4.967
Kaili Liao,Junnan An,Lipei Fu,Houye Zhang,Meng Wei,Jinmei Bai,Yanfeng He
Welan gum is one of the most promising polymers used in polymer flooding for enhancing oil recovery, due to its excellent temperature resistance and salt-tolerance performance. However, welan gum, as a polymer with higher molecular weight, can be adsorbed and detained in the pore throat of the reservoir, which is characterized by a smaller size. Montmorillonite, a kind of clay mineral with high content in reservoir rocks, has strong adsorption capacity. Therefore, the adsorption behavior of welan gum on montmorillonite, as well as its influencing factors, are studied in this paper. The results show that the adsorption capacity is 2.07 mg/g. The adsorption capacity decreased with the increase in temperature. Both acidic and alkaline conditions reduced the adsorption capacity. The existence of inorganic salt affected the adsorption capacity. In addition, the higher the cation value, the lower the adsorption capacity. The characterization tests showed that the adsorption of welan gum on montmorillonite was characterized by physical adsorption and surface adsorption, indicating that there were no changes in the internal structure of montmorillonite. This study provides feasible methods to reduce the amount of welan gum adsorbed on montmorillonite, which is of great significance for reducing the permeability damage caused by welan gum adsorption and promoting the application of welan gum in polymer flooding for enhancing oil recovery.Keywords:welan gum;polymer flooding;enhancing oil recovery;montmorillonite;adsorption
研究领域:
石油工程
·
应用化学
✓ 已验证
DOI
PubMed
高影响因子
ACS Omega
·
2022
·
IF 4.132
Xiaoxiao Dou,Zhewen Chen,Xiaojian Cao,Chicheng Ma,Jianlin Liu
Magnetic fluid is a new type of smart material, which holds implications for highly enhancing the oil displacement efficiency. In the present study, we perform a comprehensive investigation to probe the influence of a magnetic fluid on the displacement efficiency in porous media under the action of magnetic force. First, the displacement efficiency is measured by a self-developed setup, where factors such as the magnet thicknesses, the volume of the fluid injected, the fluid injection speed, and the porosity of the sample are surveyed as controllable variables. Moreover, the experimental results are well verified by the scaling laws according to the principle of dimensional balance. Next, a numerical simulation is performed to explore the detailed displacement process. First, the magnetic force generated by the ring magnet is calculated. Then, the function curves of the displacement efficiency with respect to the controlling variables are validated by the numerical simulation. In addition, the numerical simulation also demonstrates the volume phase distribution, the pressure field, and the velocity field of the mixed fluid during the displacement process. The simulation results are in excellent agreement with the experimental data. These findings are beneficial for us to better understand the oil displacement with the aid of external fields, which also provide inspiration for the areas of microfluidics, diffusion of pollutants, microsensors, etc.
研究领域:
石油工程
·
材料科学
·
流体力学
✓ 已验证
DOI
高影响因子
PETROLEUM SCIENCE AND TECHNOLOGY
·
2022
·
IF 1.695
Kaixiang Cui,Yufei Xia,Linlin Tian,Shuai Wang,Yongyao He
In order to enhance oil recovery, supercritical CO2 (scCO2) flooding has been applied in many oilfields to extract oil and gas post primary recovery. However, it causes serious scaling problems in the reservoir, oil well and production tubing. In this article, the produced water quality before and after scCO2 flooding in carbonate reservoirs are analyzed. The scaling trend of produced water before and after scCO2 flooding was calculated by using the Davis-stiff saturation index and Ryznar stability index methods. Static experiments and scanning electron microscope (SEM) are used to study the scale inhibition performance and mechanism of HEDP, ATMP, MA-AA, and PAA on CaCO3 in produced water before and after scCO2 flooding. The results show that after scCO2 flooding, the quality of produced water changes obviously, thus the scaling trend of produced water increases, the growth of CaCO3 crystal is affected and the scale inhibition efficiency of conventional scale inhibitors decreases.
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
ENERGY & FUELS
·
2024
·
IF 5.2
Xuening WANG,Long HE,Peng XUE,Yachao FENG,Yan HUANG,Xuefeng WANG
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 high-salinity 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+, Mg2+, Ca2+, and SO42– 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 Ca2+ exhibited a more significant effect on wettability at low concentrations. Additionally, when utilizing 2000 mg/L low-salinity water as the dispersion medium for ZrO2 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.
研究领域:
石油工程
·
材料科学
·
表面化学
✓ 已验证
产品关联
DOI
高影响因子
INDUSTRIAL & ENGINEERING CHEMISTRY RESEARCH
·
2016
·
IF 2.567
Teng Lu,Zhaomin Li,Weiyu Fan,Xinglu Zhang,Qichao Lv
The deposition of asphaltenes in porous media is one of the most difficult problems during CO2 flooding. In this paper, the adsorption of asphaltenes onto Al2O3 nanoparticles was studied through two methods: (i) by adding a certain mass of nanoparticles in a fixed volume of solution with different initial concentrations of asphaltenes and (ii) by exposing a certain amount of asphaltenes in a fixed volume of solution to different nanoparticles additions. Then, the impact of Al2O3 nanoparticles on the asphaltene precipitation was investigated using the IFT behavior of the oil–CO2 system. Coreflood tests were conducted to study the potential of nanoparticles for inhibition of asphaltenes damage during CO2 flooding, and the effect of injection parameters of nanofluid. It is found that the solid–liquid equilibrium (SLE) can well describe the isotherms of asphaltene adsorption. The trend of the IFT–pressure curve is affected by asphaltene accumulation at the oil–CO2 interface. The slopes in the high pressure region can be used to examine the intensity of asphaltene precipitation. As the addition of nanoparticles increases, the IFT slope in the high pressure range decreases. This is because the asphaltenes are absorbed at the surface of nanoparticles. As a result, the nanoparticles prevent asphaltene precipitation from accumulating at the CO2–oil interface, hence causing asphaltene to remain within the bulk of oil. The higher the mass fraction of Al2O3 nanoparticles is, the lower the intensity of the asphaltene precipitation would be. The coreflood results show that the injection of Al2O3 nanofluid can lessen the oil permeability reduction because the nanoparticles can inhibit the deposition of asphaltenes onto the sand surfaces in the porous media. The 0.5 wt % nanoparticles and the 0.1 nanofluid/CO2 slug volume ratio are considered as the optimum for inhibiting asphaltenes damage during CO2 flooding. Continuous CO2 and nanofluid injection could be more effective compared with the cyclic injection pattern.
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
COLLOIDS AND SURFACES A-PHYSICOCHEMICAL AND ENGINEERING ASPECTS
·
2025
·
IF 5.4
Xiaolong Yan,Yongmin Shi,Yu Tian,Haoxuan Zheng,Junyao Chen,Yangyang Tian,Quansheng Chen
Surfactant oil recovery is an effective method to enhance oil recovery. A series of anionic-nonionic surfactants, known as MNDEAS, were synthesized using dimethyl maleate, long-chain amines (C12, C14, C16, C18), diethanolamine, and sodium bisulfite to address the issues of unsuitable surfactants under harsh reservoir conditions and reduced efficiency due to excessive adsorption in the reservoir. The structure was analyzed by Fourier transform infrared spectroscopy (FTIR) and nuclear magnetic resonance hydrogen spectroscopy ( 1 HNMR). The surface tension, interfacial tension, wettability, emulsification, Zeta potential, adsorption, temperature and salt resistance, as well as oil recovery efficiency of surfactants were studied. The results showed that MNDEAS surfactants were successfully synthesized. Among them, MNDEAS-12 has the best surface-active performance, which can still reduce the oil-water interfacial tension to 10 −3 mN/m under 100,000 mg/g salinity and 120°C high temperature, its adsorption on minerals is only 1/4 of that of ionic surfactants, and it can improve the oil recovery degree by more than 15 %. This study provides a new idea for the synthetic design of surfactants for oil recovery and can promote the industrial application of anionic-nonionic surfactants.
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
COLLOIDS AND SURFACES A-PHYSICOCHEMICAL AND ENGINEERING ASPECTS
·
2024
·
IF 4.9
Mingwei Zhao,Ying Li,Caili Dai,Yingpeng Chen,Xin Sun,Xinyu Ge,Shixu Ma
In this work, a novel three-step method was used to modify the surface of silicon quantum dots to synthesize amphiphilic silicon quantum dots (A-SiQDs) with higher interfacial activity. The particle size of A-SiQDs was only 3.5 nm. By adding a small amount of dodecyl dimethyl betaine (BS-12), the performance of A-SiQDs was further improved. Through particle size and zeta potential testing, it can be seen that the mixed system of A-SiQDs and BS-12 had good temperature and salinity resistance, and can be stable at 120 °C and 50,000 mg/L NaCl. Meanwhile, the mixed system exhibited superior interfacial activity compared with individual A-SiQDs and BS-12. The mixed system can lower the interfacial tension from 32.15 mN/m to 1.82 mN/m and transform the rock surface from an oil-wet to a strong water-wet state. This ensured the excellent imbibition ability of the mixed system, which can increase the oil recovery to 35.7 %. Finally, from the perspective of force, the influence of nanofluids on oil stripping and migration was analyzed to reveal the imbibition mechanism. This paper proposes a facile three-step method for synthesizing A-SiQDs, and also provides a novel nanomaterial for high efficiency imbibition in low-permeability reservoirs.
研究领域:
材料科学
·
石油工程
·
纳米技术
✓ 已验证
产品关联
DOI
高影响因子
Processes
·
2025
·Vol. 13
·期 2
·457
·
IF 2.8
Li Wang,Hong He,Hua Wu,Zhi Luo,Zhongchen Gao,Jun Peng,Haixia Yin,Hao Lei
Water flooding is one of the most widely used secondary oil recovery methods for enhanced oil recovery (EOR). However, as a reservoir matures, excessive water production often accompanies oil production. To address this issue, the injection–production coupling technique (IPCT) has been proposed to control water production and improve oil recovery. Despite its practical application, the underlying mechanisms governing the injection–production process remain unclear. To investigate this, a transparent heterogeneous sand pack model and a visualization micro-model were employed to examine the impact of the injection–production mode on oil recovery and to uncover the mechanisms of enhanced oil recovery. The results indicate that, compared to the conventional continuous injection–production mode, both the fluid flow swept area and incremental oil recovery are significantly higher in the IPCT. Sweep efficiency improves by adjusting the injection–production streamlines and displacement directions. Notably, the oil displacement effect in the “stop injection” mode is more effective than in the “reduce injection” mode. These findings suggest that the coupling injection–production mode can efficiently recover residual oil in low permeability zones, thereby enhancing overall oil recovery.
研究领域:
石油工程
·
流体力学
✓ 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）