Li Baiqiang, Wu Zhenzhen, Wang Gang, Wang Qicong, Zhou Taofa, Zhang Xiaoli, Ju Yinjuan, Ketchaya Yanick Blaise, Quaye Jonathan Atuquaye, Xu Hongjie
School of Earth and Environment, Anhui University of Science and Technology, Huainan 232001, China.
Shaanxi Key Laboratory of Petroleum Accumulation Geology, Xi'an Shiyou University, Xi'an 710065, China.
ACS Omega. 2025 Apr 19;10(16):16506-16516. doi: 10.1021/acsomega.4c11157. eCollection 2025 Apr 29.
Recently, in addition to petrophysical properties, the present-day in situ stress (PDIS) is also considered as one of the controlling factors for the highly heterogeneous deep and ultradeep carbonate reservoirs. However, the specific relationship between PDIS and the distribution of carbonate reservoirs remains unclear. This situation restricts our understanding of the distribution law of deep carbonate reservoirs and the accurate prediction of favorable distribution areas. This paper focuses on unraveling the orientation, magnitude, and distribution law of PDIS and its influence on the distribution of deep carbonate reservoirs in the Upper Member of the Yingshan Formation within the S region of the Tahe Oilfield. By leveraging image logging, conventional logging, the combined spring model, and data dissection from a variety of geological experiments, drilling operations, and reservoir engineering undertakings, it is endeavored to shed light on these aspects. The results demonstrate that the maximum horizontal primary stress ( ), minimum horizontal primary stress ( ), and stress difference ( ) are the key factors controlling the distribution of deep carbonate reservoirs in the Upper Member of the Yingshan Formation in the study area. Specifically, the reservoir thickness, showing a negative correlation with and , is generally high with a value more than 14 m in the areas where and are less than 157 and 61 MPa, respectively. Reservoir porosity displays a positive correlation with but a negative correlation with and . It is commonly high with a value more than 5% in the areas where is larger than 96 MPa and and are less than 157 and 61 MPa, respectively. The thickness of strata with fracture development exhibits a positive correlation with and and a relatively strong negative correlation with . It is commonly high with a value more than 5 m in the areas where and are greater than 157 and 62 MPa, respectively, and is less than 95 MPa. Regions where is less than 157 MPa, is less than 61 MPa, and is greater than 96 MPa should be the primary choices for selecting favorable areas of deep carbonate reservoir distribution in the study area. The research results can not only benefit the exploration for the distribution law of deep and ultradeep marine carbonate reservoirs but also provide technical support for the prediction and optimization of favorable areas for deep oil and gas exploration.
近年来，除岩石物理性质外，现今原地应力（PDIS）也被视为高度非均质的深层和超深层碳酸盐岩储层的控制因素之一。然而，PDIS与碳酸盐岩储层分布之间的具体关系仍不明确。这种情况限制了我们对深层碳酸盐岩储层分布规律的认识以及对有利分布区的准确预测。本文重点揭示塔河油田S区鹰山组上段PDIS的方向、大小和分布规律及其对深层碳酸盐岩储层分布的影响。通过利用成像测井、常规测井、组合弹簧模型以及来自各种地质实验、钻井作业和油藏工程工作的数据剖析，努力阐明这些方面。结果表明，最大水平主应力（ ）、最小水平主应力（ ）和应力差（ ）是控制研究区鹰山组上段深层碳酸盐岩储层分布的关键因素。具体而言，储层厚度与 和 呈负相关，在 和 分别小于157MPa和61MPa的区域，储层厚度通常较高，值大于14m。储层孔隙度与 呈正相关，但与 和 呈负相关。在 大于96MPa且 和 分别小于157MPa和61MPa的区域，孔隙度通常较高，值大于5%。裂缝发育地层的厚度与 和 呈正相关，与 呈相对较强的负相关。在 和 分别大于157MPa和62MPa且 小于95MPa的区域，裂缝发育地层厚度通常较高，值大于5m。 小于157MPa、 小于61MPa且 大于96MPa的区域应是研究区深层碳酸盐岩储层有利分布区优选的主要区域。研究成果不仅有利于深层和超深层海相碳酸盐岩储层分布规律的勘探，也可为深层油气勘探有利区的预测和优化提供技术支持。
