Origin and formation of deep and superdeep strata gas from Gucheng-Shunnan block of the Tarim Basin, NW China

Zhou, Xiaofeng; Lü, Xiuxiang; Zhu, Guangyou; Cao, Yinghui; Liu, Yan; Zhang, Zhiyao

doi:10.1016/j.petrol.2019.02.059

Cited by 28 publications

(5 citation statements)

References 28 publications

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“…The Cambrian oil-gas migration process in the Tarim Basin is an important basis for evaluating the deep oil-gas resources [17,33,52]. However, it is extremely difficult to study the migration in the Cambrian deep petroleum system in the Tarim Basin, and there are few reports on the regularity of the oil-gas accumulation due to the low degree of exploration [3].…”

Section: Discussionmentioning

confidence: 99%

Secondary Migration Trend Based on Basin Modeling: A Case Study of the Cambrian Petroleum System in the Tarim Basin

Yue

Wei

et al. 2023

Geofluids

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Secondary hydrocarbon migration is an important aspect of oil-gas accumulation research. While previous studies have relied on geological and fluid geochemical characteristics to predict migration direction, these results are often limited by the number of samples. In recent years, basin simulation has emerged as a valuable tool in hydrocarbon migration research due to its extensive algorithms and adaptable modeling capabilities. It has obvious technical advantages especially for resource evaluation in areas with a lower exploration degree and scarce data. The deep oil and gas in the Cambrian petroleum system in the Tarim Basin is a deep hydrocarbon challenging area in China. There has been no breakthrough in exploration due to the large burial depth ( generally > 6000 m ) and the long accumulation and transformation processes. Therefore, predicting the secondary migration of Cambrian oil and gas has become the key to solving this problem. In this study, first, the thermal evolution of the Lower Cambrian source rocks in the Tarim Basin was recovered, and the three thermal evolution models were developed. The secondary migration process of the Cambrian petroleum system was restored using the geologic model of the source rocks and paleotectonic evolution and the latest fluid potential information. By comparing the simulation results, four secondary migration models of the ultradeep oil-gas migration and accumulation were developed: multisource, multiphase, multidirectional accumulation; multisource, multiphase, single-directional accumulation; single-source, multiphase, multidirectional accumulation; and single-source, multiphase, single-directional accumulation. The fluid potential simulation results indicate that the Cambrian oil and gas have salient inheritance characteristics. The dominant migration channels in the uplift and slope are beneficial to oil-gas migration and accumulation, and the Katake uplift and the west Bachu uplift have multisource charging accumulation. The east Bachu uplift and the Tabei uplift are oil-gas accumulation zones that are beneficial to the lower petroleum system due to the continuous charging of a single petroleum system. This fluid potential simulation provides a new solution for studying the secondary migration of deep oil and gas. It provides an important reference for studying hydrocarbon accumulation in deep and ultradeep areas.

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Section: Discussionmentioning

confidence: 99%

Secondary Migration Trend Based on Basin Modeling: A Case Study of the Cambrian Petroleum System in the Tarim Basin

Yue

Wei

et al. 2023

Geofluids

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“…The secondary alterations of petroleum lead to the change of physical properties and phase states. Under relatively high thermal stress, oil cracks to form an oil cracking gas, which can form large-scale natural gas accumulation, and/or invade the shallow layer to change the reservoir fluid properties. , The effect of TSR reduces the critical temperature of oil cracking by 30–60 °C and accelerates the cracking reaction of crude oil or heavy hydrocarbons. , However, severe TSR alteration may largely increase the sour gas (H 2 S and CO 2 ) contents in natural gas and lead to increasing sulfur contents, the decreasing saturated/aromatic ratio, and the enrichment of nonhydrocarbons and asphaltenes in oil as well, thus consequentially affecting the chemical composition of oil and gas.…”

Section: Discussionmentioning

confidence: 99%

Geochemical Characteristics and the Origin of Superdeep Condensates in Tarim Basin, China

Zhang

Zhu

et al. 2021

ACS Omega

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A series of trace compounds (diamondoids, ethanodiamondoids, and thiadiamondoids) were detected through two-dimensional gas chromatography/time-of-flight mass spectrometry (GC × GC-TOFMS) analysis of Ordovician condensate samples from the Tazhong area. Gas chromatography-mass spectrometry (GC-MS) analysis showed that the biomarker parameters are less effective for high-maturity oils. Carbon isotope and geochemical features suggested that the gas is a high-temperature cracking gas when its temperature is higher than 170 °C. The H2S content is 8.27%, suggesting that it is affected by thermochemical sulfate reduction (TSR). However, the geological analysis indicated that the Ordovician reservoirs do not satisfy the conditions for TSR. The high-maturity oil in the Ordovician reservoirs may generate diamondoids and ethanodiamondoids when cracking, while TSR and severe cracking occur in deep Cambrian source rocks and produce a large number of diamondoids, ethanodiamondoids, organic sulfur compounds (OSCs), etc. The secondary geochemical products that are carried up by the dry gas and migrate upward through faults and are enriched in Ordovician crude oil reservoirs. On this basis, we proposed that the condensate presented was formed by the mixing of dry gas from Cambrian oil that was altered by cracking and TSR into Ordovician in situ slightly cracked oil, therefore speculating that the favorable reservoir–seal assemblages in this area may contain abundant oil and gas resources. Consequently, improved knowledge of secondary alteration effects on the reservoir and underground fluids is vital for oil and gas prediction and exploration development in the next step.

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“…Fluid inclusions, as important tools for fluid tracing, have been widely used in the study of hydrocarbon reservoir formation and evolution (Zhou et al, 2019;Huang et al, 2023). When studying fluid inclusions, petrographic observations are crucial.…”

Section: Fluid Inclusion Petrographymentioning

confidence: 99%

Hydrocarbon fluid evolution and accumulation process in ultradeep reservoirs of the northern Fuman Oilfield, Tarim Basin

Wang,

Zhang,

Chen

et al. 2024

Front. Earth Sci.

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Marine deep Ordovician reservoirs are significantly controlled by strike-slip fault zones, which govern reservoir fluid evolution during various activity periods. Such fluid evolution elucidates the process underpinning ultra-deep oil and gas accumulation and delineates the pivotal role of strike-slip fault zones in hydrocarbon aggregation. This method can improve the understanding of the mechanism of hydrocarbon accumulation in deep to ultradeep carbonate rocks. The findings indicate that the Ordovician reservoirs in the northern thrust fault zone of the Fuman Oilfield predominantly exhibit two stages of calcite vein formation. The distribution patterns of rare earth elements and Sr isotope characteristics suggest that both stages of vein formation were sourced from Middle to Lower Ordovician marine strata, with no evidence of oxidizing fluid infiltration. This indicates that late-stage oil and gas charging in deep-ultradeep formations has good sealing properties. In these calcite veins, early-, middle-, and late-stage fluid inclusions were primarily entrapped. By examining the development of primary oil inclusions and combining the U‒Pb isotope data of host minerals, this study confirms the occurrence of three stages of oil and gas charging in the deep Ordovician strata of the northern thrust fault zone in the Fuman Oilfield. These stages correspond to approximately 459 ± 7.2 Ma (mid-Caledonian), 348 ± 18 Ma (early Permian), and 268 Ma (late Permian). The key accumulation period of oil and gas reservoirs in the study area is the middle and late Caledonian, and there is a good correspondence between oil and gas charging and fault activity.

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Origin and formation of deep and superdeep strata gas from Gucheng-Shunnan block of the Tarim Basin, NW China

Cited by 28 publications

References 28 publications

Secondary Migration Trend Based on Basin Modeling: A Case Study of the Cambrian Petroleum System in the Tarim Basin

Secondary Migration Trend Based on Basin Modeling: A Case Study of the Cambrian Petroleum System in the Tarim Basin

Geochemical Characteristics and the Origin of Superdeep Condensates in Tarim Basin, China

Hydrocarbon fluid evolution and accumulation process in ultradeep reservoirs of the northern Fuman Oilfield, Tarim Basin

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