Characteristics and origin of lacustrine source rocks in the Lower Cretaceous, Erlian Basin, northern China

Ding, Xiujian; Liu, Guangdi; Zhang, Ming; Huang, Zhilong; Gao, Changhai; Wang, Pangen; Qu, Jin; Lu, Xuejun; Chen, Zhelong

doi:10.1016/j.marpetgeo.2015.08.002

Cited by 53 publications

(28 citation statements)

References 42 publications

Supporting

Mentioning

Contrasting

Order By: Relevance

“…More 12 C would be removed from the water by the phytoplankton through photosynthesis with increased productivity, then the δ 13 C value of carbonates formed in the water enriches. So the δ 13 C value of carbonate precipitated in situ could be used as the proxy of productivity in a lacustrine basin (Ding et al, ; Oana & Deevey, ). The positive correlation between δ 13 C carb and TOC of the samples demonstrate the effects of productivity on OM accumulation (Figure ).…”

Section: Discussionmentioning

confidence: 99%

“…Therefore, to clarify the organic matter accumulation mechanism in a lacustrine rift basin, it is important to characterize organic matter sources, depositional paleoenvironment, and water column properties. Organic geochemical parameters and elemental geochemistry are effective methods because they can provide vast information about organic matter source, climate condition, primary productivity, and redox conditions (Cao, Liu, et al, ; Ding et al, ; Fu, Wang, Zeng, Tan, & Feng, ; Hao et al, ; Harris, Freeman, Pancost, White, & Mitchell, ; Jia, Bechtel, et al, ; Ma, Wang, Lv, Li, & Yi, ; Makeen, Hakimi, & Abdullah, ; Quan et al, ; Sarki Yandoka, Abdullah, Abubakar, Hakimi, & Adegoke, ).…”

Section: Introductionmentioning

confidence: 99%

See 1 more Smart Citation

Geochemical characteristics, depositional environment, and controlling factors of Lower Cretaceous shales in Chagan Sag, Yingen‐Ejinaqi Basin

et al. 2017

Self Cite

View full text Add to dashboard Cite

The Lower Cretaceous shales of Chagan Sag, Yingen‐Ejinaqi Basin, are considered as the source rocks of hydrocarbons discovered in the sag. Borehole shales from the Lower Cretaceous were subjected to comprehensive geochemical study to evaluate the quality of source rock, to reconstruct the paleodepositional environment and to determine the controlling factors of organic matter enrichment. Content of present‐day total organic carbon, and hydrogen index, averaging 1.4% and 259.2 mg hydrocarbon/g total organic carbon, respectively reveal poor to fair quality of organic matter. Average value of vitrinite reflectance (Ro) of 1.0% indicates mature organic matter. Maceral composition and biomarker analysis provide evidence for a mixed aquatic and terrigeous organic matter input. Based on Sr/Cu, Sr/Ba, and gammacerane index, we propose that organic matter was deposited in closed hypersaline under hot and arid climate conditions. The ratios of V/(V + Ni), and pristane/phytane (Pr/Ph), as well as the presence of β‐carotene suggest a stratified water column with anoxic bottom water condition. Low to moderate productivity as a result of deficient nutrient supply, the excellent organic matter preservation condition under stratified anoxic water column and high sedimentary rate controlled the quality of source rock. In addition, influence of factors such as content of clay minerals on organic matter enrichment cannot be ignored.

show abstract

Section: Discussionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Geochemical characteristics, depositional environment, and controlling factors of Lower Cretaceous shales in Chagan Sag, Yingen‐Ejinaqi Basin

et al. 2017

Self Cite

View full text Add to dashboard Cite

show abstract

“…A Rock-Eval instrument is used to perform the pyrolysis analysis, which provides the parameters of T max , S 1 , and S 2 . The temperature was set as 300 °C for 3 min and then heating at 25 °C/min to 650 °C (Ding et al 2015 ). T max is the temperature which corresponds to the maximum generation rate of hydrocarbons from kerogen cracking.…”

Section: Methodsmentioning

confidence: 99%

Geochemical characterization of Lucaogou Formation and its correlation of tight oil accumulation in Jimsar Sag of Junggar Basin, Northwestern China

Ding

Zhang

et al. 2017

J Petrol Explor Prod Technol

Self Cite

View full text Add to dashboard Cite

With the constant consumption of conventional oil and gas resources, unconventional oil and gas resources with great resource potential such as tight oil have gradually been valued and become the new exploration area. Jimsar Sag is the key tight oil exploration and development block in Junggar Basin of Northwestern China. Based on the data sets of geology, oil production test, logging, rock thin section, and geochemistry of Permian Lucaogou Formation (LCG), we studied the geochemical characteristics of hydrocarbon source rocks and their relation to the tight oil accumulation. Organic matter abundance of source rocks is high, the types of organic matter are mainly type I and type II, and the organic matter maturation is in the low mature stage to mature stage. Results of oil source correlation showed that the crude oil of sweet spots was mainly derived from the source rocks in the interior of the sweet spots. The LCG tight oil is mainly distributed in the plane where the source rocks have great thickness and the TOC is higher than 3.5%. It shows that the source rocks have obvious controlling on the occurrence and accumulation of tight oil.

show abstract

“…The petroleum potentials of lacustrine source rocks from the Gulf of Thailand will be extremely useful for other petroleum systems with lacustrine sources (e.g. Ding et al, 2015, Wei et al, 2017. The knowledge gained from this kind of analysis of hydrocarbon potentials of multipetroleum systems will serve as a guide in exploring sedimentary basins with more than one petroleum systems.…”

Section: Significance and Wider Implicationsmentioning

confidence: 99%

Hydrocarbon Generation Potentials of Cenozoic Lacustrine Source Rocks: Gulf of Thailand, Southeast Asia

Akinlotan¹,

Jolly²,

Anyiam³

2018

International Journal of Geology and Earth Sciences

View full text Add to dashboard Cite

Several hydrocarbon-rich Cenozoic basins are scattered across Southeast Asia and they present excellent opportunity to examine these rich but under-explored basins. These near-shore basins have petroleum potentials that are associated with the Oligocene-Miocene fluvio-lacustrine multipetroleum systems but are largely underexplored. This study evaluates the petroleum source potentials of some selected Cenozoic basins via maturation modelling analysis, burial and heat flow histories. ZetaWare's Genesis modelling software was used for the study with burial history and thermal history parameters (vitrinite, TOC and HI). The maximum transformation of kerogen to hydrocarbon for source rocks in these basins may be as high as 80-100%. Analyses showed that threshold maturity for maximum hydrocarbon expulsion is around 1.0% vitrinite reflectance (Ro). Thermal maturation is accentuated with depth-especially southward and offshore. Source rocks in the Western (central) and Hua Hin (north) Basins are the most prolific (with up to 400 mgHC/gtoc); least prolific sources are in the Western (north and south) Basin with 96-120 mgHC/gtoc and 40-50 mgHC/gtoc respectively. These sources have expelled only secondary amount of gas (11-80mg/gtoc) because they are oil prone sources. Oil to gas expulsion ratio of 7:1 is estimated. Hydrocarbon expulsion started in the Late Miocene after the emplacement of all necessary traps. Deeply buried sources show good prospects for possible residual hydrocarbon generation. Moreover, all the modelled wells displayed source rocks that expelled significant quantity of hydrocarbon. All these basins show strong correlation with Pattani Basin, the most prolific hydrocarbon-bearing basin in the Gulf of Thailand.

show abstract

Characteristics and origin of lacustrine source rocks in the Lower Cretaceous, Erlian Basin, northern China

Cited by 53 publications

References 42 publications

Geochemical characteristics, depositional environment, and controlling factors of Lower Cretaceous shales in Chagan Sag, Yingen‐Ejinaqi Basin

Geochemical characteristics, depositional environment, and controlling factors of Lower Cretaceous shales in Chagan Sag, Yingen‐Ejinaqi Basin

Geochemical characterization of Lucaogou Formation and its correlation of tight oil accumulation in Jimsar Sag of Junggar Basin, Northwestern China

Hydrocarbon Generation Potentials of Cenozoic Lacustrine Source Rocks: Gulf of Thailand, Southeast Asia

Contact Info

Product

Resources

About