Discovery of Sinian source rocks in proterozoic in the Tarim Basin, NW China

Wu, Nan; Wang, Jian; Cai, Zhongxian; Luo, Zhendong; Lu, Xuesong; Ma, Xingzhi; Liu, Xianfeng

doi:10.1016/j.petrol.2020.107450

Cited by 9 publications

(5 citation statements)

References 45 publications

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“…The tight limestone around the fault zones and the thick cap rock represented by the regional mudstone of the upper Ordovician Sangtamu Formation provide reliable conditions for the preservation of oil and gas accumulated in the reservoirs. 34 …”

Section: Geological Settingmentioning

confidence: 99%

“…Therefore, these faults established connections with the main hydrocarbon source and created essential conditions for vertical migration and accumulation of hydrocarbons. The tight limestone around the fault zones and the thick cap rock represented by the regional mudstone of the upper Ordovician Sangtamu Formation provide reliable conditions for the preservation of oil and gas accumulated in the reservoirs …”

Section: Geological Settingmentioning

confidence: 99%

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Diagenesis Sequence and Hydrocarbon Accumulation Period of the Ordovician Reservoir in Well Tashen-6, Tahe Oilfield, Tarim Basin, NW China

Feng

Tang

et al. 2022

ACS Omega

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The main types of diagenesis, diagenetic minerals and their formation time sequence in the Ordovician ultradeep (>7000 m total depth) carbonate reservoir represented by the Yingshan and Penglaiba Formations (well Tashen-6, Tahe Oilfied, Tarim Basin), are determined by applying microscopic observations, microscopic fluorescence detection, and cathodic luminescence analysis in petrographic thin sections. The distinct periods of reservoir diagenesis and hydrocarbon-related events are determined by analyzing the development characteristics of hydrocarbon inclusions and their relationship with the host minerals. The charging periods of hydrocarbon inclusions are identified by constraining the homogenization temperatures of inclusions. The obtained results indicate that the Ordovician Yingshan and Penglaiba formations have experienced at least three periods of hydrocarbon charging and one period of structural transformation. Their relative time sequence relationship with diagenesis processes is as follows: The limestone dissolution of the Yingshan Formation developed initially, and the first period of hydrocarbon charging occurred (during the late Caledonian). The second period of hydrocarbon charging occurred due to the continuous modification influence of dissolution (late Hercynian–early Yanshanian). The limestones of the Penglaiba Formation were exposed to strong tectonism during the second period of hydrocarbon charging in the Yingshan Formation; thus, intralayer microfractures were formed. Additionally, the first period of hydrocarbon charging in the Penglaiba Formation occurred together with the dolomite reservoir (late Hercynian–early Yanshanian). During the subsequent period, dissolution occurred again due to the continuous increase in burial depth. The third period of hydrocarbon charging developed concurrently with the early fractures (late Himalayan). Finally, the unceasing deepening of the strata accompanied by tectonic activity led to the early intergranular dissolution pores to be cut by late microfractures, which caused the crude oil to convert into bitumen through secondary modifications.

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Section: Geological Settingmentioning

confidence: 99%

Section: Geological Settingmentioning

confidence: 99%

Diagenesis Sequence and Hydrocarbon Accumulation Period of the Ordovician Reservoir in Well Tashen-6, Tahe Oilfield, Tarim Basin, NW China

Feng

Tang

et al. 2022

ACS Omega

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“…To the north-west of the Yaregskaya area at the Vodniy Promysel field, the drilling of wells from the Upper Riphean shales yielded commercial flows of dry gas (10,000-15,000 m 3 /day) containing 95.80% methane. Abroad, Precambrian accumulations and intensive HC manifestations were recorded in Australia (McArthur [30,31] and Amadeus [32] Basins), China (North China [33,34], Sichuan [35][36][37] and Tirim [38] Basins), Oman (Persian Gulf Basin [39]), India (Bikaner-Nagaur Basin [40]), as well as on the African continent (Taoudeni and Voltaian Basins [41]).…”

Section: Introductionmentioning

confidence: 99%

Assessment of Oil and Gas Potential in Vychegda Trough in Connection with the Identification of Potential Petroleum Systems

Krivoshchekov,

Botalov

2024

Geosciences

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At present, the study of the oil and gas potential of poorly explored areas of oil and gas basins in the Russian Federation is of great importance due to the possibility of discovering large hydrocarbon accumulations in them. The Vychegda Trough in the north of the Volga–Ural basin is considered to be one of such areas. The research is devoted to the assessment of the oil and gas potential of the Vychegda Trough based on the concept of “petroleum systems”, which is widely used in oil and gas geology. A comprehensive analysis of geological and geophysical, petrophysical and geochemical data was carried out, and modern technologies for studying the oil and gas potential of sedimentary basins were applied: paleotectonic, paleogeographic reconstructions and basin modeling. The results of the research allowed us to determine a sufficiently high potential for the discovery of hydrocarbon accumulations and to identify three potential petroleum systems in the basin section: Riphean, Vendian and Devonian–Permian.

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“… 17 , 18 However, a growing availability of simulations and reservoir bitumen studies has shown that many highly over-mature solid bitumens retain effective biomarker information. 19 , 20 For example, solid bitumen with a high thermal maturity has been found in the Neoproterozoic–Palaeogene reservoirs of the Tarim Basin, and biomarkers, such as terpenes, steranes, and polycyclic aromatic hydrocarbons, extracted from these samples have been identifying oil sources. 21 , 22 In addition, recent studies have shown that some of the compounds in solid bitumen are bonded.…”

Section: Introductionmentioning

confidence: 99%

“…In previous studies, the validity of biomarkers in bitumen was controversial, owing to the high thermal maturity of the Sinian bitumen in the Sichuan Basin. , However, a growing availability of simulations and reservoir bitumen studies has shown that many highly over-mature solid bitumens retain effective biomarker information. , For example, solid bitumen with a high thermal maturity has been found in the Neoproterozoic–Palaeogene reservoirs of the Tarim Basin, and biomarkers, such as terpenes, steranes, and polycyclic aromatic hydrocarbons, extracted from these samples have been identifying oil sources. , In addition, recent studies have shown that some of the compounds in solid bitumen are bonded. This enables the preservation of certain highly stable and unstable biomarkers, and these bonded compounds contain early primary information from the parent source rock …”

Section: Introductionmentioning

confidence: 99%

Origin and Genesis of Solid Bitumen from the Sinian Dengying Reservoir in the Deyang–Anyue Rift within the Sichuan Basin (SW China): Evidence from Biomarkers and Microscopic Features

Dai

et al. 2021

ACS Omega

Self Cite

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Deep-carbonate gas reservoirs are a significant field for conventional gas exploration in the Sichuan Basin, and industrial-grade gas reservoirs have recently been discovered in the second member of the Dengying Formation in the Deyang–Anyue rift. Drilling results have indicated that the large amount of solid bitumen that is commonly found in pores and fractures in the reservoir of the second member of the Dengying Formation. However, systematic studies have not yet been conducted on the solid bitumen of the second member of the Dengying Formation and its genesis and parent source remain unclear. This study is based on the systematic analysis of solid bitumen samples collected from new exploratory wells, with the aid of optical microscopy, scanning electron microscopy, and gas chromatography–mass spectrometry to clarify the genesis, thermal maturity, and parent source deposition environment of the solid bitumen. Electron microscopy and biomarker results indicate that bitumen is in a high-maturity stage and is a product of the thermal cracking of crude oil. Energy dispersive spectrometer results and the continuous distribution of n -alkanes indicate that the bitumen is not subjected to strong thermochemical sulfate reduction and biodegradation. Isoprenoids and terpenes suggest that the palaeoreserves associated with the bitumen of the second member of the Dengying Formation originate in reductive marine carbonate sediments. The combination of regional stratigraphic contact relationships, lithology, and biomarker characteristics implies that the Maidiping Formation muddy dolomite and the Dengying Formation algal dolomite are the potential parent sources of solid bitumen in the second member of the Dengying Formation.

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Discovery of Sinian source rocks in proterozoic in the Tarim Basin, NW China

Cited by 9 publications

References 45 publications

Diagenesis Sequence and Hydrocarbon Accumulation Period of the Ordovician Reservoir in Well Tashen-6, Tahe Oilfield, Tarim Basin, NW China

Diagenesis Sequence and Hydrocarbon Accumulation Period of the Ordovician Reservoir in Well Tashen-6, Tahe Oilfield, Tarim Basin, NW China

Assessment of Oil and Gas Potential in Vychegda Trough in Connection with the Identification of Potential Petroleum Systems

Origin and Genesis of Solid Bitumen from the Sinian Dengying Reservoir in the Deyang–Anyue Rift within the Sichuan Basin (SW China): Evidence from Biomarkers and Microscopic Features

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