Genetic origin of gas condensate in Permian and Triassic strata in the southern Sichuan Basin, SW China

Huang, Shipeng; Liú, Dan; Wang, Zecheng; Feng, Ziqi; Huang, Tongfei

doi:10.1016/j.orggeochem.2015.05.003

Cited by 17 publications

(3 citation statements)

References 32 publications

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“…A large amount of natural gas filling leads to a reduction in the molar content of liquid hydrocarbon components, the critical point temperature and critical condensate temperature in the phase envelope decrease, and the gas–liquid two-phase area increases. The crude oil gradually dissolves into the natural gas, and the phase state changes obviously. , …”

Section: Discussionmentioning

confidence: 99%

“…The crude oil gradually dissolves into the natural gas, and the phase state changes obviously. 74,75 On the basis of understanding the hydrocarbon charging periods, the main factors influencing condensate gas reservoir formation and the evolution of hydrocarbon phase states in the P 3 w reservoir of Well Zheng 10, a formation model for condensate gas reservoirs is proposed (Figure 12).…”

Section: Formation Model For Condensate Gas Reservoirsmentioning

confidence: 99%

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Hydrocarbon Phase State Evolution and Accumulation Process of Ultradeep Permian Reservoirs in Shawan Sag, Junggar Basin, NW China

Xu,

Lei,

Zhang

et al. 2023

Energy Fuels

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A large amount of oil and gas has been discovered in the ultradeep reservoirs in the Shawan Sag, Junggar Basin. However, the hydrocarbon phases in ultradeep reservoirs are complex, and the controlling factors and evolution have not been studied, which are important for exploration and development. This study determined the hydrocarbon phase states of the reservoirs in the Upper Wuerhe Formation (P3w) of Well Zheng 10 in the Shawan Sag via hydrocarbon components and a pressure–volume–temperature (PVT) phase diagram. We used 1D basin modeling to simulate the thermal maturity of the Lower Wuerhe (P2w) source rock, components of generated hydrocarbons, reservoir temperature and pressure, and hydrocarbon phase. The results show that the hydrocarbons in the P3w reservoir are secondary condensate gas. The source rock began to enter the threshold of hydrocarbon generation at the end of the Late Triassic, and the thermal maturity (Easy Ro%) of the P2w source rock in the P3w reservoir fetch area is approximately 1.5% at present. The reservoir experienced multiple periods of hydrocarbon charging and phase evolution. During the Late Triassic to the early Late Jurassic and the late Early Cretaceous to the Late Cretaceous, the hydrocarbons in the P3w reservoir were liquid. Since the Miocene, a large amount of gas has migrated to the P3w reservoir, leading to gas invasion, which is the key to the formation of a condensate gas reservoir. The hydrocarbons changed from liquid to condensate gas due to the increasing gas–oil ratio and reservoir temperature. This study provides a quantitative method to reconstruct the phase evolution process and establishes an accumulation model of condensate gas reservoirs.

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Section: Discussionmentioning

confidence: 99%

Section: Formation Model For Condensate Gas Reservoirsmentioning

confidence: 99%

Hydrocarbon Phase State Evolution and Accumulation Process of Ultradeep Permian Reservoirs in Shawan Sag, Junggar Basin, NW China

Xu,

Lei,

Zhang

et al. 2023

Energy Fuels

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“…Methyl cyclohexane, as a good parameter to reflect terrigenous parent material types, is mainly sourced from higher plant cellulose, sugars, and lignin, and its extensive presence is the prominent features of the light hydrocarbons in coal-derived gas (Dai et al, 1992;Hu, Ge, Chang, & Liu, 1990). The dimethyl cyclopentane with various structures is mainly sourced from the lipid compounds of aquatic organisms, whereas n-heptane is primarily sourced from algae and bacteria (Dai et al, 1992;Hu et al, 1990;Hu et al, 2008;Huang, Liu, Wang, Feng, & Huang, 2015;Odden, Patience, & Van, 1998). The extensive presence of both is a feature for the light hydrocarbons of oil-associated gas (Dai et al, 1992;Hu et al, 2008;Odden, 1999Odden, , 2000.…”

Section: Genetic Types Of Natural Gasmentioning

confidence: 99%

Geochemical characteristics of light hydrocarbons and their influencing factors in natural gases of the Kuqa Depression, Tarim Basin, NW China

Peng

Wang

et al. 2018

Geological Journal

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In order to determine the source of the light hydrocarbons in the Kuqa Depression of the Tarim Basin, Northwest China, their geochemical characteristics are documented, and possible influencing factors are discussed in a broad context on the basis of geochemical analyses of natural gas samples from 19 wells in combination with previously reported natural gas components and carbon isotope values from the same depression. The biomarker analytical results show that (a) methyl cyclohexane (37.5–60.3%) of natural gas predominates the C7 light hydrocarbon series (methyl cyclohexane, heptanes, and dimethyl cyclopentane), and (b) the heptane content (25.0–54.8%) is also relatively high. The C6–7 light hydrocarbon series (aromatics, normal alkanes, and cycloalkanes) have abnormally high aromatics (benzene and toluene) content (26.2–83.8%). Heptane value (13.31–37.77%) and isoheptane value (2.10–7.64%) indicate that the Kuqa natural gases are of high maturity and typical of coal‐derived gas (gas generated by sapropelic source rock). Their light hydrocarbons, however, appear to have some characteristics of mixed‐source organic matter. Specifically, the light hydrocarbons in the Dina 2 gas field show characteristics of the coal‐derived gas; those in the Dabei gas field show some features of the oil‐associated gas (gas generated by humic source rock), whereas those in the Kela 2 and Keshen 2 gas fields and Well Yangtake‐101 display characteristics of the mixed source organic matter. The abnormally high content of the aromatics in the Kuqa Depression may have resulted mainly from their high productivity during the thermal maturity of humic type organic matters and the gases accumulation of late stage. The different relative contents of the aromatics in various oil and gas fields may have been accounted by different organic matter types, maturity, and distribution patterns of source rocks.

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Machine Learning of Mineralization-Related Geochemical Anomalies: A Review of Potential Methods

Zuo

2017

Nat Resour Res

158

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Genetic origin of gas condensate in Permian and Triassic strata in the southern Sichuan Basin, SW China

Cited by 17 publications

References 32 publications

Hydrocarbon Phase State Evolution and Accumulation Process of Ultradeep Permian Reservoirs in Shawan Sag, Junggar Basin, NW China

Hydrocarbon Phase State Evolution and Accumulation Process of Ultradeep Permian Reservoirs in Shawan Sag, Junggar Basin, NW China

Geochemical characteristics of light hydrocarbons and their influencing factors in natural gases of the Kuqa Depression, Tarim Basin, NW China

Machine Learning of Mineralization-Related Geochemical Anomalies: A Review of Potential Methods

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