海陆过渡页岩储层非均质润湿性的特征和模型：来自有机质、矿物和微观结构的见解,Energy & Fuels

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海陆过渡页岩储层非均质润湿性的特征和模型：来自有机质、矿物和微观结构的见解
Energy & Fuels ( IF 5.2 ) Pub Date : 2023-04-17 , DOI: 10.1021/acs.energyfuels.2c04256
Pei Li _{1,

2,

3} , Haikuan Nie _{1,

2,

3} , Jinchuan Zhang ₄ , Wei Dang ₅ , Reza Rezaee ₆ , Jianghui Ding ₇ , Qian Chen _{1,

2,

3}

Affiliation

异质润湿性的特征在于斑点润湿或混合润湿状态。对储层评价和页岩气藏的高效开发具有重要影响。在这项研究中，研究了二叠系山西-太原地层的几个岩心塞的储层特性。这些地层是典型的海陆过渡页岩，位于华北盆地南部。为了研究储层特性对非均相润湿性的影响，我们测量了水-空气接触角，并将其与有机岩石学、有机地球化学、矿物学和微观结构特征（包括孔隙-裂缝和表面粗糙度）等其他特性进行了比较。结果表明镜质体含量与接触角呈负相关，此外，Ⅲ型干酪根中粘土含量高，极性基团残留，表明山西—太原高成熟度页岩仍具有较高的亲水性。岩心样品的接触角随着表面粗糙度的增加而减小，部分原因是孔隙-裂缝发育的影响。交会图表明页岩中存在的大多数孔隙裂缝优先倾向于亲水。因此，页岩的非均质润湿性主要由亲水和疏水组分的随机混合和排列以及微观结构的复杂性（如粗糙的孔壁）决定。进一步，在改进和检验Cassie模型的基础上，综合分析孔隙结构、矿物成分、有机质“三要素”，提出了评价页岩非均相润湿性的三角法和详细流程。测试结果表明，山西—太原组页岩以亲水（受有机因素控制）和中性湿为主，明显不同于海相龙马溪组页岩广泛分布的强亲水、弱亲水带。湿（由孔隙因子控制）和弱水湿（中性湿）。该方法可应用于页岩油气勘探过程中对页岩非均质润湿性进行快速、全面的评价和预测。测试结果表明，山西—太原组页岩以亲水（受有机因素控制）和中性湿为主，明显不同于海相龙马溪组页岩广泛分布的强亲水、弱亲水带。湿（由孔隙因子控制）和弱水湿（中性湿）。该方法可应用于页岩油气勘探过程中对页岩非均质润湿性进行快速、全面的评价和预测。测试结果表明，山西—太原组页岩以亲水（受有机因素控制）和中性湿为主，明显不同于海相龙马溪组页岩广泛分布的强亲水、弱亲水带。湿（由孔隙因子控制）和弱水湿（中性湿）。该方法可应用于页岩油气勘探过程中对页岩非均质润湿性进行快速、全面的评价和预测。

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Characteristics and Model of Heterogeneous Wettability in a Marine-Continental Transitional Shale Reservoir: Insights from Organic Matter, Minerals, and Microstructure

Heterogeneous wettability is characterized by a spotted-wet or mixed-wet state. It has a great influence on reservoir evaluation and the efficient development of shale gas reservoirs. In this study, reservoir properties of several core plugs from the Permian Shanxi–Taiyuan formations were studied. These formations are typical marine-continental transitional shale located in the Southern North China Basin. To investigate the effects of reservoir properties on heterogeneous wettability, we measured the water–air contact angle and compared it with other properties such as organic petrology, organic geochemistry, mineralogy, and microstructure features, including pore-fractures and surface roughness. The results reveal a negative correlation of vitrinite content with contact angle, in addition to the high clay content and residual polar groups within type III kerogen, indicating that the Shanxi–Taiyuan shales with a high maturity level still have a higher affinity to water. The contact angle of the core samples decreases with increasing surface roughness, partially due to the influence of pore-fracture development. The crossplots indicate that the majority of pore-fractures that exist in the shale preferentially tend to be water-wet. Therefore, the heterogeneous wettability of shale is dominated by the random mixture and arrangement of hydrophilic and hydrophobic components as well as the complexity of the microstructure, such as the rough pore wall. Furthermore, on the basis of improving and examining the Cassie model, a triangle method and a detailed workflow for evaluating the heterogeneous wettability of shale are proposed by comprehensively analyzing “three factors”, including pore structure, mineral components, and organic matter. The test results demonstrate that the Shanxi–Taiyuan shales are mainly water-wet (controlled by organic factor) and neutral-wet, which evidently differ from the marine Longmaxi shale with a wide distribution covering the zones of strongly water-wet, weakly water-wet (controlled by pore factor), and weakly water-wet (neutral-wet). The proposed approach can be applied to promptly and comprehensively evaluate and predict the heterogeneous wettability of shales during shale oil and gas exploration.

更新日期：2023-04-17

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