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In light of significant advancements in shale oil exploration within China’s principal oil and gas bearing basins, small to medium-sized basins such as the Subei Basin have also demonstrated considerable potential. However, the complex geological conditions within the Subei Basin present substantial challenges for the identification of favorable strata, thereby hindering large-scale shale oil development. This study utilizes practical exploration data from wells H1 and H3 within the Gaoyou Sag of the Subei Basin, integrating core observations with a suite of sophisticated analytical techniques, including X-ray diffraction, organic geochemistry analysis, argon ion polishing-scanning electron microscopy, nitrogen adsorption-mercury injection capillary pressure, and laser confocal analysis. The primary objective is to elucidate the geological characteristics and controlling factors influencing shale oil enrichment in the second member of the Funing Formation (E1f2) shale. The E1f2 member shale in the Gaoyou Sag exhibits an average total organic carbon content of 1.24% and a mean hydrocarbon generation potential of 5.38 mg/g, with a strong positive correlation observed between these parameters. The mineral composition is markedly heterogeneous, predominantly comprising mixed shale, followed by felsic shale and calcareous/dolomitic shale. The identified pore types include intergranular pores in clay minerals, carbonate intragranular dissolution pores, and a minor proportion of organic matter pores. The shale demonstrates significant vertical variability in oil enrichment, characterized by three source-reservoir couplings: “self-generating and self-reserving”, “mud generating and felsic reserving”, and “mud generating and carbonate reserving”. Formations enriched in carbonates and felsic materials exhibit superior reservoir properties, identified as “sweet spots” due to their enhanced hydrocarbon saturation and mobility. Despite the segmentation resulting from tectonic activities, the impact on preservation conditions remains limited, primarily influencing areas adjacent to sag-controlling faults. Effective preservation conditions are critical for shale oil accumulation and retention. Consequently, the deep sag regions of major depressions in the Subei Basin emerge as prime targets for shale oil exploration, which is pivotal for the efficient development of the E1f2 member shale. This study provides valuable insights into the exploration and development of shale oil within lacustrine faulted basins.
In light of significant advancements in shale oil exploration within China’s principal oil and gas bearing basins, small to medium-sized basins such as the Subei Basin have also demonstrated considerable potential. However, the complex geological conditions within the Subei Basin present substantial challenges for the identification of favorable strata, thereby hindering large-scale shale oil development. This study utilizes practical exploration data from wells H1 and H3 within the Gaoyou Sag of the Subei Basin, integrating core observations with a suite of sophisticated analytical techniques, including X-ray diffraction, organic geochemistry analysis, argon ion polishing-scanning electron microscopy, nitrogen adsorption-mercury injection capillary pressure, and laser confocal analysis. The primary objective is to elucidate the geological characteristics and controlling factors influencing shale oil enrichment in the second member of the Funing Formation (E1f2) shale. The E1f2 member shale in the Gaoyou Sag exhibits an average total organic carbon content of 1.24% and a mean hydrocarbon generation potential of 5.38 mg/g, with a strong positive correlation observed between these parameters. The mineral composition is markedly heterogeneous, predominantly comprising mixed shale, followed by felsic shale and calcareous/dolomitic shale. The identified pore types include intergranular pores in clay minerals, carbonate intragranular dissolution pores, and a minor proportion of organic matter pores. The shale demonstrates significant vertical variability in oil enrichment, characterized by three source-reservoir couplings: “self-generating and self-reserving”, “mud generating and felsic reserving”, and “mud generating and carbonate reserving”. Formations enriched in carbonates and felsic materials exhibit superior reservoir properties, identified as “sweet spots” due to their enhanced hydrocarbon saturation and mobility. Despite the segmentation resulting from tectonic activities, the impact on preservation conditions remains limited, primarily influencing areas adjacent to sag-controlling faults. Effective preservation conditions are critical for shale oil accumulation and retention. Consequently, the deep sag regions of major depressions in the Subei Basin emerge as prime targets for shale oil exploration, which is pivotal for the efficient development of the E1f2 member shale. This study provides valuable insights into the exploration and development of shale oil within lacustrine faulted basins.
Yingxiongling shale oil is considered a critical area for future crude oil production in the Qaidam Basin. However, the unique features of the Yingxiongling area, such as extraordinary thickness, hybrid sedimentary, and extensive reformation, are faced with several challenges, including an unclear understanding of the main controlling factors for hydraulic fracturing propagation, difficulties in selecting engineering sweet layers, and difficulties in optimizing the corresponding fracturing schemes, which restrict the effective development of production. This study focuses on mixed fine-grained sedimentary rocks, employing a high-resolution integrated three-dimensional geological-geomechanical model to simulate fracture propagation. By combining laboratory core experiments, a holistic investigation of the controlling factors was conducted, revealing that hydraulic fracture propagation in mixed fine-grained sedimentary rocks is mainly influenced by rock brittleness, natural fractures, stress, varying lithologies, and fracturing parameters. A comprehensive compressibility evaluation standard was established, considering brittleness, stress contrast, and natural fracture density, with weights of 0.3, 0.23, and 0.47. In light of the high brittleness, substantial interlayer stress differences, and localized developing natural microfractures in the Yingxiongling mixed fine-grained sedimentary rock reservoir, this study examined the influence of various construction parameters on the propagation of hydraulic fractures and optimized these parameters accordingly. Based on the practical application in the field, a “three-stage” stimulation strategy was proposed, which involves using high-viscosity fluid in the front to create the main fracture, low-viscosity fluid with sand-laden slugs to create volume fractures, and continuous high-viscosity fluid carried sand to maintain the conductivity of the fracture network. The resulting oil and gas seepage area corresponding to the stimulated reservoir volume (SRV) matched the actual well spacing of 500 m, achieving the effect of full utilization. The understanding of the controlling factors for fracture expansion, the compressibility evaluation standard, and the main process technology developed in this study effectively guide the optimization of transformation programs for mixed fine-grained sedimentary rocks.
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