Reservoir heterogeneity of the Longmaxi Formation and its significance for shale gas enrichment

To better determine the sweet spot in the vertical profile of the Longmaxi Formation, the shale heterogeneity was systematically investigated. A series of experiments were conducted on 40 shale samples collected from the Lower Silurian Longmaxi Formation in the Weiyuan shale gas field. The results i...

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Bibliographic Details
Published in:Energy science & engineering 2020-12, Vol.8 (12), p.4229-4249
Main Authors: Zhang, Qin, Feng, Liang, Pang, Zhenglian, Liang, Pingping, Guo, Wei, Zhou, Shangwen, Lu, Bin
Format: Article
Language:English
Subjects:
Adsorption
Clay
Clay minerals
Composition
controlling factors
Diagenesis
Fractal geometry
Fractals
Heterogeneity
Hydrocarbons
Lithology
Methane
Mineral composition
Natural gas exploration
Oil and gas fields
Organic carbon
Petrology
Physical properties
Porosity
Quartz
Shale gas
shale gas enrichment
Shales
Silurian
the Longmaxi Formation
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Summary:To better determine the sweet spot in the vertical profile of the Longmaxi Formation, the shale heterogeneity was systematically investigated. A series of experiments were conducted on 40 shale samples collected from the Lower Silurian Longmaxi Formation in the Weiyuan shale gas field. The results indicated that total organic carbon (TOC), the mineral composition, methane adsorption capacity, and porosity of the four sub‐layers in the Longmaxi shale varied significantly. In terms of the TOC, the mid‐lower Long111 had the highest value, followed by Long113, while the TOC values of Long112 and Long114 were quite low. As for mineral composition, the mid‐lower Long111 had the highest quartz content, Long112 and Long113 had equivalent quartz, carbonate, and clay mineral contents, and Long114 had higher clay mineral and carbonate contents, but a lower quartz content. Shale porosity and methane adsorption capacity were the highest in the mid‐lower Long111, followed by Long113, Long112, Long114, and the upper Long111. The micro‐heterogeneity represented by the fractal dimension ranged from 2.590 to 2.750, with an average of 2.670. The mid‐lower Long111 had the largest fractal dimension, followed by Long113, Long112, Long114, and the upper part of Long111 had the smallest fractal dimension. The sedimentary environment controls the macro‐heterogeneity in the vertical profile. The micro‐heterogeneity depends on diagenesis, which can be investigated by the different effects of minerals on micropore development. The strong micro‐heterogeneity results in better preservation conditions for shale gas. The mid‐lower Long111 was rich in gas generation material (TOC) with enough storage space and is characterized by good preservation conditions, leading to the highest gas content of the four sub‐layers. In addition, the high brittle mineral content is conducive to fracturing and the formation of a fracture network. Thus, the middle ‐Long111 is the “sweet spot” in the vertical profile for the shale gas development. Longmaxi formation is heterogeneous both in macro‐scale and micro‐scale. The mid‐lower Long111 was rich in gas generation material (TOC) with enough storage space (large BET and porosity) and is characterized by good preservation conditions (large fractional dimension), leading to the highest gas content of the four sub‐layers.
ISSN:2050-0505
2050-0505
DOI:10.1002/ese3.807