Petroleum generation kinetics for Permian lacustrine source rocks in the Junggar Basin, NW China

2016 ◽  
Vol 98 ◽  
pp. 1-17 ◽  
Author(s):  
Baoli Xiang ◽  
Erting Li ◽  
Xiuwei Gao ◽  
Ming Wang ◽  
Yi Wang ◽  
...  
Keyword(s):  
Junggar Basin ◽  
Source Rocks ◽  
Nw China ◽  
Petroleum Generation

scholarly journals Carboniferous source rocks in the Ludong-Wucaiwan area, Junggar Basin, NW China

2010 ◽  
Vol 37 (5) ◽  
pp. 523-530 ◽  
Author(s):  
Wang Xulong ◽  
Zhao Mengjun ◽  
Xiang Baoli ◽  
Da Jiang ◽  
Jiang Yiqin ◽  
...  
Keyword(s):  
Junggar Basin ◽  
Source Rocks ◽  
Nw China

Petroleum generation and expulsion characteristics of Lower and Middle Jurassic source rocks on the southern margin of Junggar Basin, northwest China: implications for unconventional gas potential

2014 ◽  
Vol 51 (6) ◽  
pp. 537-557 ◽  
Author(s):  
Jigang Guo ◽  
Xiongqi Pang ◽  
Fengtao Guo ◽  
Xulong Wang ◽  
Caifu Xiang ◽  
...  
Keyword(s):  
Source Rock ◽  
Shale Gas ◽  
Middle Jurassic ◽  
Junggar Basin ◽  
Northwest China ◽  
Source Rocks ◽  
Coal Bed ◽  
Southern Margin ◽  
Petroleum Generation ◽  
Gas Potential

Jurassic strata along the southern margin of Junggar Basin are important petroleum system elements for exploration in northwest China. The Lower and Middle Jurassic source rock effectiveness has been questioned as exploration progresses deeper into the basin. These source rocks are very thick and are distributed widely. They contain a high total organic carbon composed predominantly of Type III kerogen, with some Type II kerogen. Our evaluation of source rock petroleum generation characteristics and expulsion history, including one-dimensional basin modeling, indicates that Jurassic source rocks are gas prone at deeper depths. They reached peak oil generation during the Early Cretaceous and began to generate gas in the Late Cretaceous. Gas generation peaked in the Paleogene–Neogene. Source rock shales and coals reached petroleum expulsion thresholds at thermal maturities of 0.8% and 0.75% vitrinite reflectance, respectively, when the petroleum expulsion efficiency was ∼40%. The petroleum generated and expelled from these source rocks are 3788.75 × 108 and 1507.55 × 108 t, respectively, with a residual 2281.20 × 108 t retained in the source rocks. In these tight reservoirs, a favorable stratigraphic relationship (where tight sandstone reservoirs directly overlie the source rocks) indicates short vertical and horizontal migration distances. This indicates the potential for a large, continuous, tight-sand gas resource in the Lower and Middle Jurassic strata. The in-place natural gas resources in the Jurassic reservoirs are up to 5.68 × 1012 − 15.14 × 1012 m3. Jurassic Badaowan and Xishanyao coals have geological characteristics that are favorable for coal-bed methane resources, which have an in-place resource potential between 3.60 × 1012 and 11.67 × 1012 m3. These Lower and Middle Jurassic strata have good shale gas potential compared with active US shale gas, and the inferred in-place shale gas resources in Junggar Basin are between 20.73 × 1012 and 113.89 × 1012 m3. This rich inferred conventional and unconventional petroleum resource in tight-sand, coal-bed, and shale gas reservoirs makes the deeper Jurassic strata along the southern margin of Junggar Basin a prospective target for future exploration.

scholarly journals Deep-Buried Triassic Oil-Source Correlation in the Central Junggar Basin, NW China

Geofluids ◽  
2017 ◽  
Vol 2017 ◽  
pp. 1-17 ◽  
Author(s):  
Ming Wu ◽  
Jun Jin ◽  
Wanyun Ma ◽  
Baoli Xiang ◽  
Ni Zhou ◽  
...  
Keyword(s):  
Higher Plants ◽  
Linear Regression Analysis ◽  
Stable Carbon Isotope ◽  
Junggar Basin ◽  
Type A ◽  
Source Rocks ◽  
Central Basin ◽  
Nw China ◽  
Source Correlation ◽  
Oil Source

Whether there is an effective deep-buried lacustrine Triassic petroleum system in the Junggar Basin, NW China, has been enigmatic and debated for a long time. Here we conduct an oil-source correlation to address this issue. Results show that the extracted bitumens from the Triassic mudstones in the central basin have distinctive stable carbon isotope and biomarker compositions compared to the Permian-sourced and Jurassic-sourced hydrocarbons, the other two recognized sources in the study area. These characteristics include δ13C value of -30.46~-26.30‰, β-carotane/maximum n-alkane of 0.22–0.41, Pr/Ph of 1.00–1.51, C24 tetracyclic terpane/C26 tricyclic terpane of 0.43–0.96, Ts/Tm of 0.34–0.64, gammacerane/C30 hopane of 0.10–0.14, and regular steranes C27 > C28 < C29 with C29 sterane in dominance (40–50%). These suggest that the Triassic mudstones in the study area host fresh lacustrine organic matters with high input of higher plants. The Triassic-reservoired crude oils and extracts can be divided into two types. Through oil-source correlation, we infer that both type A and type B oils are derived from mixed Permian and Triassic source rocks. Linear regression analysis shows that the contribution from Triassic mudstones to type A and B oils is 67% and 31%, respectively. This implies that the deep-buried Triassic lacustrine mudstones in the Junggar Basin may have some oil-generation potential and thus might represent a new case of Triassic petroleum systems in China and deserves a more detailed and thorough study in future exploration and exploitation.

scholarly journals Geochemical characteristics of coal-measure source rocks and coal-derived gas in Junggar Basin, NW China

2009 ◽  
Vol 36 (3) ◽  
pp. 365-374 ◽  
Author(s):  
Li Jian ◽  
Jiang Zhenglong ◽  
Luo Xia ◽  
Wang Dongliang ◽  
Han Zhongxi
Keyword(s):  
Junggar Basin ◽  
Geochemical Characteristics ◽  
Source Rocks ◽  
Coal Measure ◽  
Nw China

scholarly journals Origin of deep heavy oils in the northwestern Junggar Basin (NW China) and implications for gas migration

2020 ◽  
Vol 38 (4) ◽  
pp. 819-840 ◽  
Author(s):  
Aiguo Wang ◽  
Liping Yi ◽  
Baoli Xiang ◽  
Ji Li ◽  
Changyu Fan ◽  
...  
Keyword(s):  
Junggar Basin ◽  
Source Rocks ◽  
Heavy Oils ◽  
Gas Migration ◽  
Mixed Gas ◽  
Hydrocarbon Gases ◽  
Nw China ◽  
Genetic Types ◽  
Gas Washing ◽  
Migration Pathways

Whether the northwestern Junggar Basin (NW China) has natural gas potential is an urgent but unresolved question. In this study, we discuss the origin of deep heavy oils (>2900 m) and its implication for gas migration and accumulation, based on a comprehensive investigation into physicochemical and geological properties of hydrocarbons in the northern Zhongguai High. Our results indicate that multiple-episode migration of hydrocarbons created four genetic types of oils and three genetic types of hydrocarbon gases and induced widespread gas washing. Relatively low maturity and gas washing are both responsible for the formation of the deep heavy oils. In detail, the migrating late-stage humic-type gases washed the encountered early stage low-maturity oils. The oil reservoirs lost their light fraction and evolved into heavy oils, which are preserved in the deep layer to the present, while the light-end components continued to migrate upward and accumulated as mixed gas pools or vented out of the system. The spatial distributions pattern of source rocks, heavy oils, and mixed gas clearly indicates the migration pathways of humic-type gases, which otherwise are difficult to define in the study area. Because the gases finally migrate into fault belts, their poor preservation condition likely results in the rare discoveries of gas fields. The favorable exploration targets for gas in the area are expected to be fault traps in fault belts, stratigraphic traps along the pinch-out boundary of the Upper Wuerhe Formation, and, particularly, the deep traps in the Mahu Sag.

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