Geological controls of shale gas accumulation and enrichment mechanism in Lower Cambrian Niutitang Formation of western Hubei, Middle Yangtze, China

doi:10.1007/s11707-021-0892-y

Front. Earth Sci.

2021, Vol. 15

Issue (2) : 310-331 https://doi.org/10.1007/s11707-021-0892-y

RESEARCH ARTICLE

Geological controls of shale gas accumulation and enrichment mechanism in Lower Cambrian Niutitang Formation of western Hubei, Middle Yangtze, China

Lulu XU¹, Saipeng HUANG^2,³(

), Zaoxue LIU¹, Yaru WEN¹, Xianghui ZHOU¹, Yanlin ZHANG¹, Xiongwei LI¹, Deng WANG¹, Fan LUO¹, Cheng CHEN⁴

¹. Hubei Geological Survey, Wuhan, Hubei 430034, China
². Key Laboratory of Continental shale Accumulation and Development of Ministry of Education, Northeast Petroleum University, Daqing 163318, China
³. Coal Reservoir Laboratory of National Engineering Research Center of CBM Development & Utilization, School of Energy Resources, China University of Geosciences, Beijing 100083, China
⁴. The Seventh Geological Brigade of Hubei Geological Bureau, Yichang 443000, China

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Abstract

The lower Cambrian Niutitang Formation is of crucial importance for shale gas target reservoirs in western Hubei, China; however, little work has been done in this field, and its shale gas accumulation and enrichment mechanism are still unclear. Based on survey wells, outcrop data, and large numbers of tests, the geological conditions of shale gas accumulation were studied; moreover, the factors that influence the gas content were thoroughly discussed. The results show that the Niutitang Formation ( $Є$ ₁n) can be divided into three sections: the first section ( $Є$ ₁n¹), the second section ( $Є$ ₁n²), and the third section ( $Є$ ₁n³). The $Є$ ₁n² is the main shale gas reservoir. The deep shelf facies is the main sedimentary facies and can be divided into three main lithofacies: argillaceous siltstone, carbonaceous shale and carbonaceous siliceous rock. The total organic carbon (TOC) content shows gentle growth trends until bottom of the $Є$ ₁n² and then decreases rapidly within the $Є$ ₁n¹, and the TOC content mainly ranges from 2% to 4% horizontally. The calcite and dolomite dissolution pores, clay intergranular pores and organic pores are the main pore types and the micropore types are clearly related to the mineral compositions and the TOC content. Vertically, the gas content is mainly affected by the TOC content. Horizontally, wells with high gas contents are distributed only southeast of the Huangling anticline, and the combination of structural styles, fault and fracture development, and the distribution of the regional unconformity boundary between the upper Sinian Dengying Formation (Z₂d) and the $Є$ ₁n² are the three most important factors affecting the gas content. The favorable areas must meet the following conditions: a deep shelf environment, the presence of the $Є$ ₁n¹, wide and gentle folds, far from large normal faults that are more than 5 km, moderate thermal evolution, and greater than 500 m burial depth; this includes the block with the YD2–ZD2 wells, and the block with the Y1 and YD4 wells, which are distributed in the southern portion of the Huangling anticline and northern portion of the Xiannvshan fault.

Keywords shale gas Niutitang Formation accumulation conditions factors influencing the gas content sedimentary facies

Corresponding Author(s): Saipeng HUANG

Online First Date: 19 July 2021 Issue Date: 26 October 2021

Cite this article:

Lulu XU,Saipeng HUANG,Zaoxue LIU, et al. Geological controls of shale gas accumulation and enrichment mechanism in Lower Cambrian Niutitang Formation of western Hubei, Middle Yangtze, China[J]. Front. Earth Sci., 2021, 15(2): 310-331.

URL:

https://academic.hep.com.cn/fesci/EN/10.1007/s11707-021-0892-y
https://academic.hep.com.cn/fesci/EN/Y2021/V15/I2/310

Fig.1 Location, tectonic setting of lower Cambrian Niutitang shale in western Hubei, Middle Yangtze Region. Notation: F1-Qiyueshan Fault; F2-Jianshi Fault; F3-Enshi Fault; F4-Daqingshan Fault; F5-Xianfeng Fault; F6-Xiangguang Fault; F7-Yangri Fault; F8-Xinhua Fault; F9-Xiannvshan Fault; F10-Tianyangping Fault; F11-Wuduhe Fault; F12-Tongchenghe Fault; B1-Shizhu syncline; B2-Qiyueshan anticline; B3-Lichuan syncline; B4-Zhongyang anticline; B5-Huaguoping syncline; B6-Xianfeng anticline; B7-Shengnongjia anticline; B8-Huangling anticline; B9-Zhigui syncline; B10-Changyang anticline; B11-Yidu-Hefeng anticline.

Fig.2 Composite stratigraphic column compiled from representative well ZD2 for the lower Cambrian Є₁n in western Hubei.

Fig.3 Lithofacies paleo-geographic of the Є₁n² and its influence on the thicknesses, TOC, and gas content of organic-rich shale in western Hubei. (a) Lithofacies paleo-geographic of the Є₁n² and its influence on gas content; (b) the influence of sedimentary facies on the thicknesses of organic-rich shale; (c) the influence of sedimentary facies on TOC of organic-rich shale.

Fig.4 Organic-rich shale thickness contour map of the Є₁n² in western Hubei.

Tab.1 Classification criteria of shale gas evaluation parameters (DZ/T0254-2014)

Fig.5 TOC and R_o distribution characteristics of organic-rich shale of the Є₁n² in study area. (a) The proportion of different TOC intervals; (b) The proportion of different R_o value intervals; (c) TOC contour map of organic-rich shale of the Є₁n².

Fig.6 Statistical characteristics of mineral content, porosity and permeability of organic-rich Shale of theЄ₁n² in western Hubei. (a) Mineral composition in organic-rich Shale of the Є₁n²; (b) Mineral composition of well SD1 in deep shelf environment with argillaceous siltstone; (c) Mineral composition of well ZD2 in deep shelf environment with carbonaceous shale; (d) Mineral composition of GC stratigraphic outcrop of Hefeng county in deep shelf environment with carbonaceous siliceous; (e) Porosity classification of organic-rich shale of the Є₁n² in western Hubei; (f) Permeability classification of organic-rich shale of Є₁n² in western Hubei.

Fig.7 Microscopic pores structure characteristic of the samples from well ZD2 of the Є₁n² obtained by argon ion polishing scanning electron microscopy. (A1) Calcite dissolution pores of Sample A; (A2) pyrite in Sample A; (A3) quartz in Sample A; (A4) clay intergranular pores in Sample A; (A5) organic band in Sample A; (A6) organic pores: the partial enlarged image of A5; (B1) calcite in Sample B; (B2) calcite dissolution pores: the partial enlarged image of B1; (B3) dolomite in Sample B; (B4) dolomite dissolution pores: the partial enlarged image of B3; (B5) clay intergranular pores of Sample B; (B6) pyrite intergranular pores of Sample B; (B7) quartz in Sample B; (B8) organic band in Sample B; (B9) microfractures: the partial enlarged image of B8; (B10) microfractures in calcite.

Tab.2 Comprehensive data table of gas content of organic–rich shale of the Є₁n² in western Hubei

Fig.8 Factors influencing the shale gas content vertically of the Є₁n² in ZD2 well. (a) The correlation between gas content and TOC; (b) The correlation between gas content and clay content; (c) the correlation between gas content and quartz content; (d) the correlation between gas content and carbonate content; (e) the correlation between gas content and porosity; (f) the correlation between gas content and permeability.

Fig.9 The correlation between specific surface areas, and pore volume with TOC of the samples of the Є₁n² from the wells ZD1 and ZD2. (a) The correlation between specific surface areas and TOC; (b) the correlation between total pore volume and TOC.

Fig.10 The correlation between mineral composition and TOC of the samples of the Є₁n² from the wells ZD1 and ZD2.

Fig.11 The horizontal correlation between gas content with TOC, and Quartz content of the Є₁n² in western Hubei. (a) The horizontal correlation between gas content with TOC of the Є₁n²; (b) the horizontal correlation between gas content with quartz content of the Є₁n².

Fig.12 Tectonic position of 14 wells in western Hubei. (a) tectonic position of the EY1 and X1 wells; (b) tectonic position of the CD1 well; (c) tectonic position of the Y1 well; (d) tectonic position of the WD1 well; (e) tectonic position of the ND1 well; (f) tectonic position of the YD1 well; (g) tectonic position of the YD4 well; (h) tectonic position of the ZD1 well; (i) tectonic position of the YY1, YD2, and ZD2 wells; (j) tectonic position of the HD1 and SD1 wells.

Fig.13 The correlation between the fracture characteristics and gas-bearing strata of the Є₁n in wells EY1, X1, and ZD2. (a) The hidden faults in seismic profile of the EY1 well; (b) high Angle calcite vein in the X1 well; (c) the fractures locally developed in the ZD1 well; (d) the fractures barely developed in the ZD2 well.

Fig.14 The correlation between the V_D and the distance from Xiannvshan Fault (F9) to the nine wells in western Hubei.

Fig.15 The correlation between gas content and Ro of the Є₁n². (a) The correlation between V_D and Ro; (b) Comparison of clay mineral types between the wells ZD2 and SD1. Notation: “C” is chlorite; “I” is illite; “S” is smectite.

Fig.16 Influences of the roof and floor sealing capacity on the shale gas preservation; (a) The average thicknesses of the Є₁sp, the Є₁n, and the Z₂d formation; (b) The brittle mineral content of the Є₁n¹, the Є₁n², and the Є₁n³; (c) The thickness distribution of the Є₁n¹, the Є₁n² and the Є₁n³ in western Hubei; (d) The Є₁n¹ conformably contacts the Z₂d of the ZD2 well; (e) The Є₁n² unconformably contacts the Z₂d of the ND1 well; (f) The Є₁n² unconformably contacts the Z₂d of BG stratigraphic section.

Fig.17 Influences of the burial depth on the shale gas content and compositions. (a) The correlation between the V_D and burial depth; (b) the correlation between the gas compositions and burial depth of the ZD1 well; (c) the correlation between the gas compositions and burial depth of the ZD2 well.

Fig.18 Comprehensive evaluation of shale gas favorable block of the Є₁n² in western Hubei.

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