Geochemical Characteristics and Process of Hydrocarbon Generation Evolution of the Lucaogou Formation Shale, Jimsar Depression, Junggar Basin

Wenjun He, Yin Liu, Dongxue Wang, Dewen Lei, Guangdi Liu, Gang Gao, Liliang Huang and Yanping Qi
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Wenjun He: College of Geosciences, China University of Petroleum (Beijing), Beijing 102249, China
Yin Liu: Key Laboratory of Deep Oil and Gas, School of Geosciences, China University of Petroleum (East China), Qingdao 266580, China
Dongxue Wang: Research Institute of Exploration and Development, Xinjiang Oilfield Company, PetroChina, Urumqi 830013, China
Dewen Lei: College of Geosciences, China University of Petroleum (Beijing), Beijing 102249, China
Guangdi Liu: College of Geosciences, China University of Petroleum (Beijing), Beijing 102249, China
Gang Gao: College of Geosciences, China University of Petroleum (Beijing), Beijing 102249, China
Liliang Huang: College of Geosciences, China University of Petroleum (Beijing), Beijing 102249, China
Yanping Qi: Research Institute of Exploration and Development, Xinjiang Oilfield Company, PetroChina, Urumqi 830013, China

Energies, 2022, vol. 15, issue 7, 1-19

Abstract: Lacustrine shale, represented by the Middle Permian Lucaogou Formation in the Jimsar Depression in the eastern Junggar Basin, has become one of the main areas of shale oil exploration in China. In this study, we used 137 samples of shale from the Lucaogou Formation, drawn from 14 wells in the Jimsar Depression, to investigate their characteristics of pyrolysis, organic carbon and soluble organic matter content, biomarkers, organic microscopic composition, and vitrinite reflectance. Basin simulation and hydrocarbon generation thermal simulation experiments were also conducted in a closed system. The results of this study indicate that the input of an algae source was dominant in the source rocks of the Lucaogou Formation, that the water in which the rocks were deposited had high salinity and strong reducibility, and that the source rocks were oil-prone. The Lucaogou source rocks generally had good hydrocarbon generation capability, but showed significant heterogeneity. At the end of the Cretaceous period, the shales in the Lucaogou Formation entered the oil-generation window as a whole. Currently, the shales of the Lucaogou Formation are generally in the high-maturity stage in the deep part of the depression, producing a large amount of high-maturity oil and condensate gas, while those in the shallow part have relatively low maturity and can only produce a large amount of conventional crude oil. The maximum crude oil generation rate of the Lucaogou Formation shale obtained from the thermal simulation results was 220.2 mg/g of the total organic carbon (TOC), and the maximum hydrocarbon expulsion efficiency was estimated to be 59.3–76.4%.

Keywords: Junggar Basin; Jimsar Depression; shale oil; thermal simulation; source rock evaluation; hydrocarbon generation evolution (search for similar items in EconPapers)
JEL-codes: Q Q0 Q4 Q40 Q41 Q42 Q43 Q47 Q48 Q49 (search for similar items in EconPapers)
Date: 2022
References: View references in EconPapers View complete reference list from CitEc
Citations: View citations in EconPapers (1)

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