Characteristics of microscopic pore heterogeneity and development model of Wufeng‒Longmaxi Shales in the Pengshui area of south-east Chongqing

doi:10.1007/s11707-023-1087-5

2024, Vol. 18

Issue (1) : 188-203 https://doi.org/10.1007/s11707-023-1087-5

Characteristics of microscopic pore heterogeneity and development model of Wufeng‒Longmaxi Shales in the Pengshui area of south-east Chongqing

Lu SUN¹, Zhigang WEN¹(

), Guisong HE², Peixian ZHANG², Chenjun WU¹, Liwen ZHANG¹, Yingyang XI¹, Bo LI¹

¹. College of Resources and Environment, Yangtze University, Wuhan 430100, China
². Research Institute of Exploration and Development, Sinopec East China Company, Nanjing 210011, China

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Abstract

Normal-pressure shale gas reservoirs are widely distributed in south-eastern Chongqing and show good potential for resource exploration. This paper reports the organic matter (OM), physical, and pore characteristics, mineral composition, and gas content of representative shale samples from the Upper Ordovician Wufeng Formation and Member 1 of the Lower Silurian Longmaxi Formation (Long 1 Member). Microscopic pores within different shale layers of the Long 1 Member were classified, quantitatively evaluated, and their development mechanisms were systematically studied. We found that OM characteristics, mineral composition, and pore type were the main factors affecting the enrichment and preservation of shale gas. The characteristics of the Long 1 Member are mainly controlled by changes in the sedimentary environment. There are evident differences in total organic carbon content and mineral composition vertically, leading to a variable distribution of pores across different layers. Organic matter abundance controls the degree of OM pore development, while clay minerals abundance control the development of clay mineral-related pores. Total organic carbon content generally controls the porosity of the Long 1 Member, but clay minerals also play a role in OM-poor layers. Pore connectivity and permeability are influenced by the development of pores associated with brittle minerals. We propose a microscopic pore development model for the different layers. Combining geochemical data and this pore development model, layers 1‒4 are considered to be excellent shale gas preservation and enrichment reservoirs. Poor preservation conditions in layers 5‒7 result in high levels of shale gas escape. Layers 8‒9 possess a better sealing condition compared with layers 5‒7 and are conducive to the enrichment and preservation of shale gas, and can thus be used as future potential target strata. This research provides a theoretical basis for exploring and evaluating shale gas potential in the studied region or other complex normal-pressure shale blocks.

Keywords shale gas pore characteristics Longmaxi Formation reservoir model

Corresponding Author(s): Zhigang WEN,Chenjun WU

Online First Date: 15 December 2023 Issue Date: 15 July 2024

Cite this article:

Lu SUN,Zhigang WEN,Guisong HE, et al. Characteristics of microscopic pore heterogeneity and development model of Wufeng‒Longmaxi Shales in the Pengshui area of south-east Chongqing[J]. Front. Earth Sci., 2024, 18(1): 188-203.

URL:

https://academic.hep.com.cn/fesci/EN/10.1007/s11707-023-1087-5
https://academic.hep.com.cn/fesci/EN/Y2024/V18/I1/188

Fig.1 Structural diagram of the study area (a) and histogram of the Wufeng?Longmaxi Formation (b).

Fig.2 Longitudinal distribution characteristics of geochemical parameters of Wufeng?Longmaxi Formation in Well PY?A.

Fig.3 Nitrogen adsorption-desorption isotherms and Pore diameter distribution of Long 1 Member shale samples. (a?b) Layers 1?4; (c?d) layers 5?7; (e?f) layers 8?9.

Fig.4 Organic pore types of shale simple Long 1 Member, Well PY-A. (a) Nano-organic pores in matrix kerogen, layer 9 (2842.17m), TOC (1.89%); (b) OM pores in graptolite, layer 8 (2864.01m), TOC (0.69%); (c) framboidal pyrite inter-crystalline pores, layer 3 (2923.82m), TOC (3.76%); (d) clay mineral-OM aggregates, layer 5 (2908.12m), TOC (1.26%); (e) solid bituminous OM pores, layer 3 (2923.82m), TOC (3.76%).

Fig.5 Types of inorganic pores and microfractures in the shale of Wufeng?Longmaxi Formation, Well PY-A. (a) Brittle mineral dissolution pore, layer 6 (2897.23 m), TOC (0.75%); (b) brittle mineral edge pore, layer 8 (2864.01 m), TOC (0.69%); (c) clay mineral intercrystallite pores, layer 6 (2897.23 m), TOC (0.75%); (d) OM shrinking fractures, layer 6 (2887.91 m), TOC (1.04%); (e) microfractures, layer 3 (2925.99 m), TOC (3.81%).

Fig.6 Quantitative characterization of organic and inorganic pores in different layers of the Wufeng?Longmaxi Formation. (a?c) layer 3 (2925.99 m), TOC (3.81%), porosity (5.109%), OM areal porosity (17.43%); (d?f) layers 7 (2878.32 m), TOC (0.76%), porosity (1.719%), OM areal porosity (3.52%); (g?i) layer 8 (2855.97 m), TOC (1.62%), porosity (4.715%), OM areal porosity (16.44%).

Fig.7 Percentage composition diagram of organic pores, inorganic pores, and microfractures in different shale layers of Wufeng?Longmaxi Formation, Well PY?A.

Fig.8 Correlation analysis of TOC content of shale samples with (a) pore volume and (b) the pore-specific surface area of different pore sizes.

Fig.9 Correlation analysis of organic matter pore (a), brittle mineral related pore (b), and Clay mineral inter-crystallite pores (c) percentage with TOC and mineral composition.

Fig.10 Correlation analysis of porosity with TOC (a) and clay content (b).

Fig.11 Correlation analysis of TOC with Quartz (a) and clay content (b).

Fig.12 Micro?CT scanning 3D model of Wufeng-Longmaxi Formation (same color for the same type of pore). (a) 2925.99 m, sample of layer 3; (b) 2908.12 m, sample of layer 5; (c) 2855.97 m, sample of layer 8.

Fig.13 Classification characteristics of shale lithofacies of layers 1–9. Lithofacies division scheme from Wang et al. (2016).

Fig.14 Mineral composition and pore type model of shales in layers 1–9.

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