Continuous unconventional natural gas accumulations of Carboniferous-Permian coal-bearing strata in the Linxing area, northeastern Ordos basin, China

Li, Yong; Tang, Dazhen; Wu, Peng; Niu, Xinlei; Wang, Kai; Qiao, Peng; Wang, Zhuangsen

doi:10.1016/j.jngse.2016.10.037

Cited by 125 publications

(96 citation statements)

References 25 publications

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“…Therefore, in the third stage of gas field formation, the natural gas in the C 2 b, P 1 t, P 1 s, and P 2 x formations migrated upwards when meeting the faults or fractures and the self‐expansion of natural gas due to the continuous gas charging. Thick mudstones are quite well developed in the P 2 s and P 3 s formations (Li et al, ; Liu et al, ) and can act as cap rock to prevent the gas from dissipation. The third stage occurred at the same time as the second stage and could last a long time, as the long‐distance migration did not cease even if the basin was uplifted and the hydrocarbon generation stopped.…”

Section: Discussionmentioning

confidence: 99%

“…The burial history and thermal evolution history of two wells (L10 and S5 wells) were modelled using the one‐dimensional (1D) modelling section of Schlumberger's PetroMod modelling software. The input data used for the construction of the model, such as heat flow and thermal gradient, were derived from previous studies (Li et al, ; Liu et al, ). The model was calibrated using measured maturity parameters.…”

Section: Methodsmentioning

confidence: 99%

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Genesis and accumulation of natural gas in the Upper Palaeozoic strata of north‐eastern Ordos Basin, China

et al. 2018

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The north‐eastern Ordos Basin in Central China has become an exploration target in recent years due to the potential of natural gas resources in the Upper Palaeozoic strata. In this study, by analysing the geochemical characteristics of the source rocks and the natural gas, the genesis of the Upper Palaeozoic natural gas was identified. In addition, the accumulation process was discussed by combining studies of hydrocarbon generation and burial/thermal history. The results reveal three sets of source rocks developed in the study area—Carboniferous Benxi (C2b), Permian Taiyuan (P1t), and Shanxi (P1s) formations—consisting of mudstones, carbonaceous mudstones, and coals. The source rocks contain abundant Type III organic matter and have entered mature to high‐mature stage, while source rocks in the south‐eastern part of the study area have entered the overmature stage due to the activity of Zijinshan magmatic rocks. The natural gas has a high content of methane (average 93.99%). The stable carbon isotope of methane (δ13C1) value (average −37.05‰) and that of ethane (δ13C2) value (average −26.4‰) and the composition of the light hydrocarbons reflect the idea that the natural gas is organic in origin, thermogenic, and mainly terrigenous‐sourced. The evolution of a transitional to continental depositional environment of the source rocks results in the variation in the geochemical characteristics of the Upper Palaeozoic gas in the study area. Analysis of fluid inclusions indicates a long and continuous period of natural gas charging in the study area from 165 to 65 Ma. Sandstone bodies close to or interbedded with the source rocks made the gas charging from the source rocks to the reservoirs over a short distance with high efficiency, while faults and fractures provided paths for the gas migrating to reservoirs vertically far from the source rocks. The huge gas generation potential of the source rocks and continuous distribution pattern of sandstone bodies provides favourable conditions for the development of a large‐scale natural gas reservoir.

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Section: Discussionmentioning

confidence: 99%

Section: Methodsmentioning

confidence: 99%

Genesis and accumulation of natural gas in the Upper Palaeozoic strata of north‐eastern Ordos Basin, China

et al. 2018

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“…Lower Permian sediments comprise marine‐continental transitional facies and can be divided into the Taiyuan and Shanxi formations from the bottom to the top (Jiang et al, ; Li et al, ; Figure ). The Shanxi Formation was deposited in a fluvial‐deltaic environment (Li et al, ). The sandstone deposits are laterally interconnecting and vertically overlapping distributary channels and are the main gas‐producing targets in the study area.…”

Section: Geological Settingmentioning

confidence: 99%

“…The study area is at the north-eastern margin of the Ordos Basin and is a monocline dipping 3-5°westward. The south-eastern part of the study area shows an anticlinal configuration because Zijinshan magmatic rocks uplifted the strata, which also induced faults with ring-radial distribution (Xie et al, 2016;Yang, Chao, Volkova, Zheng, & Yao, 2009 (Jiang et al, 2016;Li et al, 2016; Figure 2). The Shanxi Formation was deposited in a fluvial-deltaic environment .…”

Section: Geological Settingmentioning

confidence: 99%

“…Xie et al () suggested that the sandbodies develop extensively in the study area and the reservoir quality is controlled by a variety of factors. Some studies investigated the pore structure of the Shanxi Formation sandstones using nuclear magnetic resonance and pressure‐controlled mercury injection and found that the reservoir is tight and heterogeneous (Li et al, ; Shao, Pang, Jiang, et al, ; Shao, Pang, Li, & Zhang, ). Drilling results have shown that the Shanxi Formation tight sandstones in the north‐eastern Ordos Basin have more complex mineral compositions and diagenetic characteristics than those in the central part of the basin, leading to variable reservoir quality (porosity and permeability).…”

Section: Introductionmentioning

confidence: 99%

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Diagenetic characteristics and reservoir quality in tight gas sandstones: A case study of the Shanxi Formation in the north‐eastern Ordos Basin, China

et al. 2018

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Reservoir quality is critical in tight gas exploration. A systematic study of the petrological, petrophysical, and diagenetic characteristics of the Shanxi Formation sandstones in the north‐eastern Ordos Basin (China) was undertaken to characterize the pore system of these tight sandstones and recognize the distribution of reservoirs favourable for hydrocarbon accumulation. The results suggest that the Shanxi Formation sandstone has low compositional and moderate textural maturity, with its porosity ranging from 0.7% to 11.8% (average 5.97%) and permeability ranging from 0.001 to 2.77 mD (average 0.36 mD). In addition, thin section and SEM observations suggest that the sandstone is dominated by secondary dissolution pores, primary intergranular pores as well as microfractures, and has undergone compaction, cementation, and dissolution. Diagenetic minerals, such as carbonate cements, authigenic quartz, clay minerals, and dissolved feldspar, are identified. Fluid inclusions are observed in healed microfractures of quartz grains and in quartz overgrowths, while the homogenization temperatures of fluid inclusions in healed microfractures and in quartz overgrowth are in the ranges of 92.8–179.1°C (average 134.8°C) and 104.7–169.1°C (average 145.7°C), respectively. Authigenic kaolinite is sourced from the process of K‐feldspar dissolution, authigenic illite is sourced from transformation of smectite and kaolinite, while sources for quartz cements include mineral alteration and pressure dissolution. Selective dissolution of K‐feldspar in the presence of carbonate minerals is observed in the Shanxi Formation tight sandstones due to the different equilibrium constants of carbonate minerals and K‐feldspar leaching, resulting in dissolution pores associated with K‐feldspar. Reservoir quality in the Shanxi Formation tight sandstones is greatly influenced by diagenesis, as compaction and cementation are responsible for the loss of porosity while dissolution accounts for the enhancement of secondary porosity.

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Evaluation and analysis of methane adsorption capacity in deep‐buried coal seams

et al. 2022

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In this work, the high‐pressure methane adsorption/desorption tests were conducted in four coal samples (from low‐rank bituminous coal to anthracite) under different temperature and pressure conditions to reveal the mechanism of desorption hysteresis effect in the deep‐buried coal seams. The experimental and fitting results show that the presence of free methane molecules in the adsorption phase results in an obvious difference between the measured methane adsorption amount with the actual adsorption capacity. The Langmuir, Langmuir–Freundlich (L–F) and Dubinin–Astakhov (D–A) models have their own advantages and disadvantages in fitting the experimental adsorption/desorption data. As residual adsorption capacity C fitted by the D–A model would be negative at high temperatures and lose the meaning of the constant, the Langmuir model is more suitable to describe methane desorption process. The residual adsorption capacity fitted by Langmuir model tended to decrease as the temperature increased until it is almost completely desorbed at 373 K. Meanwhile, because the adsorption sites with lower energy are gradually occupied by methane molecules in the high‐pressure stage, intermolecular forces increased and methane molecules are more easily desorbed. Therefore, the desorption hysteresis coefficient trends to increase exponentially with the decrease of pressure and temperature, which indicated that the original gas content of the coal seams may decrease with the increase of the burial depth, but the risk of coal and gas outburst accidents may increase. © 2022 Society of Chemical Industry and John Wiley & Sons, Ltd.

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Continuous unconventional natural gas accumulations of Carboniferous-Permian coal-bearing strata in the Linxing area, northeastern Ordos basin, China

Cited by 125 publications

References 25 publications

Genesis and accumulation of natural gas in the Upper Palaeozoic strata of north‐eastern Ordos Basin, China

Genesis and accumulation of natural gas in the Upper Palaeozoic strata of north‐eastern Ordos Basin, China

Diagenetic characteristics and reservoir quality in tight gas sandstones: A case study of the Shanxi Formation in the north‐eastern Ordos Basin, China

Evaluation and analysis of methane adsorption capacity in deep‐buried coal seams

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