表面活性剂-纳米颗粒组合在提高采收率过程中在碳酸盐岩储层表面吸附过程实验研究

Abbas Shahrabadi , Allahyar Daghbandan , Mohsen Arabiyoun
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引用次数: 0

摘要

目前,表面活性剂和纳米颗粒等材料在提高采收率工程中的应用得到了广泛的研究。因此,这些物质的吸附过程是提高碳酸盐岩油藏采收率的重要方法之一。然而,对于表面活性剂-纳米颗粒组合如何通过吸附过程在碳酸盐岩储层表面相互作用的理解尚未得到很好的讨论。本文研究了天然非离子表面活性剂(GG表面活性剂)光甘草皂苷与亲水性二氧化钛纳米颗粒(HITNPs)在碳酸盐岩储层(吸附剂)表面的吸附过程,以调动原油剩余物,提高原油采收率。因此,本研究强调了化学提高采收率方案中这些材料在水溶液中的平衡吸附速率和吸附动力学。同时,利用x射线衍射(XRD)、扫描电镜(SEM)和傅里叶变换红外(FTIR)光谱分析,证实和确定了材料的理化变化和性能。为考察表面活性剂浓度与纳米颗粒的存在及吸附密度在水相中吸附剂表面的吸附速率及关系,采用常压条件下不同浓度、不同时间的间歇吸附试验,了解吸附剂剂量对吸附效率的影响。因此,采用电导率(EC)技术测定表面活性剂在水相中存在HITNPs时在吸附剂表面的吸附速率。在实验室温度(25°C)下,通过监测溶液在吸附剂表面的吸收作为时间的函数,实验研究了吸附动力学过程。用不同的吸附平衡模型和动力学模型对实验数据进行了检验。因此,确定了每个模型的吸附参数。Langmuir等温线是最佳的模型,因为GG表面活性剂和表面活性剂纳米流体溶液在吸附剂表面的相关系数(R2)较高。伪二级动力学模型能较好地估计表面活性剂GG和表面活性剂纳米流体溶液在吸附剂表面的吸附动力学。结果表明,GG表面活性剂和表面活性剂纳米流体溶液在吸附剂表面的吸附过程表现为短时间的快速吸附,随后是长时间的缓慢吸附。此外,这些材料的IFT实验结果表明,GG表面活性剂和表面活性剂纳米流体溶液可以显著降低油水体系之间的IFT值。最后,研究结果可以为提高采收率项目的设计,特别是碳酸盐岩油藏的油藏模拟方案和化学驱工艺的设计,提供合适的表面活性剂和金属氧化物纳米颗粒的选择。
本文章由计算机程序翻译,如有差异,请以英文原文为准。

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Experimental investigation of the adsorption process of the surfactant-nanoparticle combination onto the carbonate reservoir rock surface in the enhanced oil recovery (EOR) process

Nowadays, the application of materials, such as surfactants and nanoparticles in enhanced oil recovery (EOR) projects has been widely studied. So, the adsorption process of these substances is one of the important methods to increase the oil recovery factor from carbonate oil reservoirs. However, understanding how the surfactant-nanoparticle combination interacts through the adsorption process onto the carbonate reservoir rocks surface is not well discussed. In this paper, the adsorption process of saponin extracted from the Glycyrrhiza glabra plant as a natural non-ionic surfactant (GG surfactant) with the presence of hydrophilic titanium dioxide nanoparticles (HITNPs) onto the carbonate reservoir rock (adsorbent) surface has been investigated for mobilizing the crude oil remaining to increase the oil recovery factor. Hence, this study highlights the equilibrium adsorption rate and the adsorption kinetics of these materials in aqueous solutions for chemical EOR schemes. Also, analyses of X-ray diffraction (XRD) spectrometry, scanning electron microscopy (SEM), and Fourier transform infrared (FTIR) spectroscopy have been applied to confirm and determine the physicochemical changes and properties of materials. To evaluate the adsorption rate and the relationship between surfactant concentration with the presence of nanoparticles and adsorption density on the adsorbent surface in the aqueous phase, batch adsorption tests under atmospheric conditions at different concentrations and times have been used to comprehend the impact of adsorbate dose on the sorption efficiency. Therefore, the electrical conductivity (EC) technique was used for measuring the adsorption rate of surfactant with the presence of HITNPs in the aqueous phase on the adsorbent surface. The adsorption kinetics process was experimentally investigated at laboratory temperature (25 °C) by monitoring the uptake of solutions on the adsorbent surface as a function of time. The experimental adsorption data were also examined by different equilibrium and kinetic models of adsorption. Hence, the adsorption parameters were determined for each model. Langmuir isotherm was the best model according to the higher values of the correlation coefficient (R2) for GG surfactant and surfactant nanofluid solutions on the adsorbent surface. Furthermore, the pseudo-second-order kinetic model could satisfactorily estimate the adsorption kinetics of GG surfactant and surfactant nanofluid solutions on the adsorbent surface. Results indicated that the adsorption process of GG surfactant and surfactant nanofluid solutions on the adsorbent surface is characterized by a short period of rapid adsorption, followed by a long period of slower adsorption. Moreover, the results of the IFT experiment of these materials showed that GG surfactant and surfactant nanofluid solutions could significantly reduce the IFT value between oil and water system. Finally, the results obtained from this study can help in selecting appropriate surfactants and metal oxide nanoparticles for the design of EOR projects, especially reservoir simulation schemes and chemical flooding processes for carbonate oil reservoirs.

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