The assessment of shale gas potential for the Ordovician Pingliang Formation and Carboniferous–Permian Taiyuan and Shanxi formations in the northwest margin of Ordos Basin, China provides insight into how fluctuation in depositional environments has a significant role on lithofacies and shale gas potential. To investigate the shale gas potential, a series of measurements (i.e. Rock-Eval pyrolysis, maceral composition analyses and X-ray powder diffraction, etc.) on representative outcrop samples were conducted to characterise shale properties. The organic matter from marine Pingliang shale is predominantly type I with a strong predominance of sapropelinite, whereas the transitional Taiyuan-Shanxi shales are dominated by types II to III kerogen. Furthermore, the Pingliang shale is characterised as a 'poor' source rock mainly owing to the lower total organic carbon (TOC) content (average 0.79 wt%) and higher maturity [average 1.78% in vitrinite reflectance (Ro)], while the transitional Taiyuan-Shanxi shales are mostly characterised as 'fair' source rocks, and some samples with high TOC content (more than 2.0 wt%) present good source rocks. It is also found that the sedimentary environment, as a key factor determining the organic matter and TOC content, inevitably influences the type and content of minerals in shale, and controls the shale gas potential. For example, the transitional argillaceous Taiyuan-Shanxi shales are significantly different from the siliceous Pingliang shales, specifically, total clay content for the former is more than 50 wt%, while the latter is rich in quartz content (more than 70 wt%). Additionally, the quartz and clay contents of the Taiyuan shale range widely, especially the smectite content of I–S ML. The barrier coastal facies in the Taiyuan Formation are more conducive to the enrichment and preservation of organic matter because the Shanxi shale was deposited in shallow delta facies with a greater terrestrial influence. Conclusively, the Taiyuan and Shanxi formations have relatively good exploitation potential for shale gas, especially the relatively high TOC content (average 2.45 wt%) and moderate Ro value (average 1.25%). For future exploration, selecting areas with relatively large shale thickness, high brittle mineral content, stable tectonics and better preservation conditions are key to optimising favourable exploration areas for shale gas.KEY POINTSThe shale gas potentials of the argillaceous Taiyuan-Shanxi shales and siliceous Pingliang shale are compared.The influence of sedimentary facies on reservoir parameters of marine and transitional shales is established.This is a first detailed comparison of the marine and transitional shale gas potential in the northwest margin of Ordos Basin, China.
Organic matter (OM) pores are crucial to porosity in many shale gas reservoirs, but the origin and types of OM pores remain controversial. In this paper, the OM types are systematically identified and analyzed in the Wufeng–Longmaxi Formations from wells JY 1 and JY 2 in the Jiaoshiba gas field, Sichuan Basin. The results indicate that the OM comprises several hydrocarbon-generating organisms, such as various algae (multi- and unicellular algae, colonial algae, acritarch, etc.), graptolite, sponge spicule, and other fossil fragments, as well as several amorphous OM types, such as solid bitumen and strongly compacted algae. The OM pores have inherited the morphology and structure of multicellular algae and are commonly hundreds of nanometers, some of which even reach micrometer size, exhibiting irregular, bubble-like, spherical, and/or elliptical shapes. In the unicellular algae, only a small amount of OM pores are observed, which are isolated and distributed randomly. The OM pores, either irregular or oval, are tens to more than 100 nm, which are developed by the arrangement gap between the unicellular algae, and some are generated inside the unicellular algae by hydrocarbon generation and expulsion. Two types of OM pores developed in solid bitumen, including bitumen–spherulite pores and vesicular pores. The bitumen–spherulite pores are formed by the arrangement of nanoscale bitumen–spherulite with a pore diameter of nanometer scale. The vesicular pores are formed by gas generation and expulsion after oil cracking, and the shape is mostly sporadic, isolated with various sizes ranging from 500 nm to 3 μm. The OM pores in graptolite, sponge spicule, radiolarian, and other fossil fragments are much fewer in quantity and smaller in size. The OM pores may have only developed on the surface of graptolite. The pores are commonly developed in the walls of the fossil fragments and in the solid bitumen by filling in the biological cavity of the sponge spicule. Therefore, it is concluded that the OM types are the pivotal causes of different OM pore types and properties. Multicellular algae are most beneficial to OM pore development, serving as the major producer of OM pores. In the profile of the Wufeng–Longmaxi shales, the vertical variation of OM types and OM pores are diverse in different graptolitic zones. The dominant hydrocarbon-generating organisms in the WF2–LM4 graptolitic zone are multicellular algae and graptolite, followed by a small number of unicellular algae, sponge spicule, radiolarian, and other fossil fragments. The OM pores are mainly developed in multicellular algae and graptolite, with only a few developed in solid bitumen and unicellular algae. In the LM5–LM8 graptolitic zone, however, the hydrocarbon-generating organisms are primarily unicellular algae, with little multicellular algae, graptolite, sponge spicule, and other fossil fragments. The OM pores are mainly developed in unicellular algae and solid bitumen. The new findings provide evidence to support the proposal that multicellular algae are the main hydrocarbon-generating organisms controlling the OM pore development. Moreover, the WF2–LM4 graptolitic zone is the target interval for shale gas exploration and development in the Upper Ordovician and Lower Silurian Formations in the Sichuan Basin and its surrounding areas.
ABSTRACT This study examines the oil storage capacity and controlling factors of organic‐rich Chang 7 shale in the Ordos Basin, using multistep Rock‐Eval pyrolysis (MREP) and liquid hydrocarbon vapour adsorption (LHVA) techniques. The research evaluates the effectiveness of these techniques in determining oil content and identifies key geological and geochemical factors impacting free and adsorbed oil. Analyses of geochemical, mineralogical, and pore structure characteristics reveal that Chang 7 shale, with high total organic carbon (TOC) content and oil‐prone kerogen, along with moderate thermal maturity, is a high‐quality hydrocarbon source rock. A strong linear correlation between MREP and LHVA results demonstrate the reliability of both methods for assessing adsorbed oil content, though discrepancies emphasise the impact of hydrocarbon loss during sample preparation. Statistical analysis indicates TOC content (> 2%, with > 4% especially favourable) and thermal maturity ( R o = 0.7%–1.0%) as the critical factors for shale oil accumulation and key indicators for identifying sweet spots. These findings improve the understanding of oil occurrence processes in shale and offer practical insights for optimising shale oil exploration and development.
According to data of gas wells and typical sections of Wufeng Formation and Longmaxi Formation in Sichuan Basin, shale of various graptolite zones were analyzed to determine depositional environment, lithology and thickness characteristics of the graptolite shale interval of WF2-WF3 in the lower part of Wufeng Formation, the graptolite shale interval of WF4 in Guanyinqiao Member of Wufeng Formation and the graptolite shale interval of LM1-LM4 in the bottom of Longmaxi Formation, and characteristics of shale horizontal distribution were also investigated. During the depositional period of the graptolite shale interval of WF2-WF3, the study area was less affected by the Guangxi movement, the depositional environment was the deep water of open sea, where black shale was mainly deposited; the sedimentation center was developed in northeast Guizhou-northeast Sichuan and south Sichuan, the maximum thickness was from 4 to 6 m in the sedimentation center. During the depositional period of the graptolite shale interval of WF4, the depositional environment in the study area changed greatly due to global sea level fall and enhanced Guangxi movement; the central Sichuan paleouplift, the central Guizhou paleouplift and the Jiangnan-Xuefeng palaeouplift were further expanded, and the area of the sedimentary basin decreased; the depositional environment was mainly carbonate bioclastic shoal of shallow sea, and partially deep sea which only was distributed in the Shizhu-Fuling-Wuxi area in east and northeast Sichuan and the Gongxian-Yongchuan area in south Sichuan; sediments of shallow water were dominated by limestone and argillaceous limestone with abundant Hirnantia, sediments of deep water were dominated by calcareous mudstone and shale with Hirnantia. During the depositional period of the graptolite shale interval of LM1-LM4, due to rise of global sea level and Guangxi movement, the sedimentary area was larger than that in the depositional period of Guanyinqiao Member, and the sedimentary environment mainly was stagnant deepwater; thickness of black shale in the graptolite shale interval of LM1-LM4 was large, and the maximum thickness was over 20 m. Furthermore, control of the central Sichuan paleouplift, the central Guizhou paleouplift and the Jiangnan-Xuefeng paleouplift on black shale was discussed, and control of the Zhiliujing underwater highland/uplift, Huayingshan highland and Dingshan highland as well as western Hubei-Hunan underwater highland/uplift on shale deposition and preservation was also investigated.
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.
Shale gas release in canister can significantly enrich our understanding in gas-in-place characteristics. However, studies on shale gas release characteristics and its controlling factors are rare. In this study, gas release curves of 52 shale samples and 3 coal samples were measured using wellsite canister testing technique. According to curve shape, three curve patterns including L-shaped, S-shaped, and M-shaped are identified, and the difference among three curve patterns mainly lies in the fractional gas volume released in surface temperature stage. To evaluate the dependence of released gas content on shale properties, the variation in released gas content with organic matter, minerals, porosity, permeability, specific surface area, and pore volume is analyzed and found that the released gas content shows a strong dependence on the properties that control or could increase gas adsorption and diffusion capacity, such as TOC content, specific surface area, and permeability, while showing no dependence on the properties that control free gas storage capacity, such as minerals, porosity, and pore volume. Additionally, correlations of released gas content with adsorbed/free gas show that the released gas during canister testing is the gas that was in the adsorbed state in reservoir, and the free gas has been lost during coring, as well as a fraction of adsorbed gas. Above findings provide insightful information not only on gas-in-place evaluations but also on the dynamic behavior of adsorbed/free gas from producing well.
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