油成分、岩石矿物学、老化时间和盐水预浸对页岩润湿性的影响,ACS Omega

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油成分、岩石矿物学、老化时间和盐水预浸对页岩润湿性的影响
ACS Omega ( IF 3.7 ) Pub Date : 2021-12-20 , DOI: 10.1021/acsomega.1c03940
I Wayan Rakananda Saputra ₁ , Oluwatobiloba Adebisi ₁ , Elsie B Ladan ₁ , Aashrit Bagareddy ₁ , Abhishek Sarmah ₁ , David S Schechter ₁

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实验和现场研究表明，表面活性剂可提高非常规油藏的采油率 (EOR)。岩石表面润湿性在确定这种 EOR 方法的有效性方面起着重要作用。在这些储层中，由于极低的孔隙率、渗透率以及由此导致的流体接近固体表面，岩石表面的初始润湿性尤为重要。本研究旨在研究油成分、岩石矿物学和盐水盐度对非常规页岩油/盐水/岩石系统中岩石表面润湿性的影响。研究了六种原油、七种储层岩石和七种储层盐水样品。这些油样来自美国的各种页岩油藏（轻质 Eagle Ford、重质 Eagle Ford、Wolfcamp、Middle Bakken 和 Three Forks）。SARA（饱和物、芳烃、对每个原油样品进行分析。此外，本研究还旨在为页岩储层样品的表面活性剂相关实验室实验提供标准化岩石样品老化协议的指南。发现包含的页岩储层系统都是油湿的。与岩石矿物学相比，油成分和盐水盐度对润湿性的影响更大。具有更多芳香族和树脂成分以及更高盐度的油使表面更加油润。还观察到具有较高石英含量的岩石样品会增加油湿性。芳香族/树脂和石英相互作用的结合产生了一个更加油湿的系统。这些观察结果由互溶性/极性概念解释。根据 Tukey 对超过 1100 次接触角测量的分析，达到统计上稳定的润湿性状态所需的最短老化时间为 35 天。观察到用其相应的盐水预润湿表面以使岩石表面更加油湿。

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The Influence of Oil Composition, Rock Mineralogy, Aging Time, and Brine Pre-soak on Shale Wettability

Experimental and field studies have indicated that surfactants enhance oil recovery (EOR) in unconventional reservoirs. Rock surface wettability plays an important role in determining the efficacy of this EOR method. In these reservoirs, the initial wettability of the rock surface is especially important due to the extremely low porosity, permeability, and resulting proximity of fluids to the solid surface. This study is designed to investigate the effect of oil components, rock mineralogy, and brine salinity on rock surface wettability in unconventional shale oil/brine/rock systems. Six crude oils, seven reservoir rocks, and seven reservoir brine samples were studied. These oil samples were obtained from various shale reservoirs (light Eagle Ford, heavy Eagle Ford, Wolfcamp, Middle Bakken, and Three Forks) in the US. SARA (saturates, aromatics, resins and asphaltenes) analysis was conducted for each of the crude oil samples. Additionally, this study also aims to provide a guideline to standardize the rock sample aging protocol for surfactant-related laboratory experiments on shale reservoir samples. The included shale reservoir systems were all found to be oil-wet. Oil composition and brine salinity showed a greater effect on wettability as compared to rock mineralogy. Oil with a greater amount of aromatic and resin components and higher salinity rendered the surface more oil-wet. Rock samples with a higher quartz content were also observed to increase the oil-wetness. The combination of aromatic/resin and the quartz interaction resulted in an even more oil-wet system. These observations are explained by a mutual solubility/polarity concept. The minimum aging time required to achieve a statistically stable wettability state was 35 days according to Tukey’s analysis performed on more than 1100 contact angle measurements. Pre-wetting the surface with its corresponding brine was observed to render the rock surface more oil-wet.

更新日期：2022-01-11

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