Genetic origins of marine gases in the Tazhong area of the Tarim basin, NW China: Implications from the pyrolysis of marine kerogens and crude oil

Tian, Hui; Xiao, Xia; Wilkins, R. J.; Gan, Huajun; Guo, Liguo; Liu, Yang

doi:10.1016/j.coal.2010.01.012

Cited by 49 publications

(27 citation statements)

References 34 publications

(63 reference statements)

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“…Accordingly, the gas generated by KAE in the closed system was much drier than gas generated by KO, in the high to overmature stages. These results have been well documented in mature kerogen by many previous studies (Behar et al, 1995(Behar et al, , 1997Hill et al, 2007;Tian et al, 2010). Various types of cleavage reactions may occur in the cracking of oil and mature kerogen; the former is mainly characterized by the cleavage of straight carbon links while the latter mainly involves demethylation or dealkylation reactions (Behar et al, 1999;Lorant et al, 2000).…”

Section: Gas Hydrocarbonssupporting

confidence: 54%

“…11a). Moreover, gases generated from KO exhibited similar trends to those from coal in closed systems Michels et al, 2002), and were also close to gases generated from two oils in a closed system Tian et al, 2010). In summary, the effect of oil expulsion or retention on a source rock's position within a crossplot of d 13 C 2 -d 13 C 3 versus C 2 /C 3 suggests the expulsion or retention process constrains whether the extent of how open or close the system was.…”

Section: C Values Of Gas Hydrocarbonsmentioning

confidence: 64%

“…Recent thermal simulations further show that this type of crossplot combined with two other crossplots, specifically d 13 C 2 -d 13 C 3 versus d 13 C 1 and d 13 C 1 -d 13 C 2 versus C 1 /C 2 , may differentiate gases generated by kerogen cracking from those generated by oil cracking Tian et al, 2010). Although residual bitumens were the main contributors to gas generated in KAE, as stated above, the gases generated from KAE displayed very similar characteristics to those reported from mature kerogens Tian et al, 2010) and coal in semi-open systems (Michels et al, 2002) on the d 13 C 2 -d 13 C 3 versus C 2 /C 3 crossplot (Fig. 11a).…”

Section: C Values Of Gas Hydrocarbonsmentioning

confidence: 99%

“…Lorant et al, 1998;Lorant and Behar, 2002;Hill et al, 2007;Rodriguez and Philp, 2010;Tian et al, 2010;Hao and Zou, 2013;Xia et al, 2013) occurring in many deep-burial basins may be derived from the thermal degradation of kerogen which has experienced oil expulsion. Opposite to oil expulsion, oil retention in source rock could impact the resource potential of shale oil and gas; hot exploration targets in recent years.…”

Section: Introductionmentioning

confidence: 99%

“…It is of scientific importance to characterize the hydrocarbon generation behavior of oil-expelled kerogen, because it may help us to precisely estimate conventional and unconventional oil/gas reserves and perform source to oil/gas correlation in deep-burial basins. The best approach for this study is to pyrolyze a kerogen, and characterize the oil generation and expulsion from natural or artificially mature samples (Lorant and Behar, 2002;Hill et al, 2007;Guo et al, 2009;Tian et al, 2010).…”

Section: Introductionmentioning

confidence: 99%

See 4 more Smart Citations

The effect of oil expulsion or retention on further thermal degradation of kerogen at the high maturity stage: A pyrolysis study of type II kerogen from Pingliang shale, China

Jia

Wang

Liu

et al. 2014

Organic Geochemistry

View full text Add to dashboard Cite

Section: Gas Hydrocarbonssupporting

confidence: 54%

Section: C Values Of Gas Hydrocarbonsmentioning

confidence: 64%

Section: C Values Of Gas Hydrocarbonsmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

See 3 more Smart Citations

The effect of oil expulsion or retention on further thermal degradation of kerogen at the high maturity stage: A pyrolysis study of type II kerogen from Pingliang shale, China

Jia

Wang

Liu

et al. 2014

Organic Geochemistry

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Early Palaeozoic carbonate reservoirs from the Yingshan Formation of Well block ZG-43 in Tazhong Low Rise, Central Uplift, Tarim Basin, NW China: geological features and controlling factors

Lan

Lü

et al. 2013

Geol. J.

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Marine carbonate reservoirs, as a focus of petroleum exploration and development in China, are involved with high exploration risk and prediction difficulty owing to high heterogeneity and diversity of reservoir beds. In the Tarim Basin, NW China, carbonate reservoirs host about 38% of the whole basin's hydrocarbon resources in a large prospecting area mainly distributed in the Cambrian and Ordovician rocks in central (Tazhong) and northern (Tabei) Tarim. Recently, a better understanding has been made of the karsted weathering crust at the top of the Lower Ordovician Yingshan Formation in the northern slope area of the Tazhong Low Rise, Central Uplift, Tarim Basin. As a new frontier of exploration, oil/gas distribution and controlling factors of carbonate reservoirs in the Yingshan Formation are not clearly understood. In this work, we investigated the reservoir beds and oil/gas properties in 13 wells in Well block ZG‐43 on the No. 10 structural belt in the Tazhong Low Rise, and studied hydrocarbon accumulation characteristics with seismic and geochemical data. The Yingshan Formation in Well block ZG‐43 is mainly composed of calcarenite, dolomitic limestone, dolomite, cryptite, as low porosity and low permeability reservoir beds, with fracture‐void porosity constituting the main reservoir pore space. Oil/gas is quasi‐layer distributed beneath the unconformity between the Yingshan and Lianglitag formations to a depth of 140 m. The oil in Well block ZG‐43 is condensate with low density, low viscosity, low sulphur, low resin, low asphaltene, and high wax. The gas is 87.3% methane, generally containing H2S. The oil/gas distribution pattern is oil in the east and gas in the west, and H2S content in the west is lower than that in the east. The controlling factors for hydrocarbon are multi‐source supply and multi‐phase charging, interstratal karstification, hydrothermal activity, structural location and sealing condition. A structural–lithological trap is the main type of oil/gas accumulation. Oil/gas distribution was clearly affected by strike–slip faults. Oil/gas with multi‐source supply and multi‐phase charging was controlled by favourable local palaeo‐highs, and affected by later karsting and hydrothermal activity, as well as gas invasion in the Himalayan (Cenozoic) period. Under the caprock of compact limestone in the third to fifth members of the Lianglitag Formation, oil/gas migrated up along the strike–slip fault planes, and moved laterally to both sides in a ‘T’ shape, and formed large‐scale quasi‐layer condensate gas reservoirs controlled by reservoir bed quality. Copyright © 2013 John Wiley & Sons, Ltd.

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Origins and accumulation processes of the Ordovician gas condensate in the Tazhong area, Tarim Basin, northwest China

et al. 2017

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Abundant gas condensates have been proven in the Ordovician carbonate reservoirs in the Tazhong area, the centre of the Tarim Basin, where complicated geological evolution and multiple hydrocarbon accumulations have occurred. Property, geochemistry, and stable carbon isotopes of the Ordovician condensate are characterized to identify the oil and gas origins in the Tazhong area. Fluid inclusion data, combined with numerical modelling methods was used to determine petroleum accumulation processes. Our results suggest that oils are characterized by mixed sources, with 64% of contributions from the Middle‐Upper Ordovician (O2+3) source rocks and 36% of contributions from the Lower‐Middle Cambrian (Є1+2) source rocks. Gases are primarily generated from the thermal cracking of pre‐existing oils in the underlying strata, with a small amount derived from kerogen cracking accompanied with oil generation. Three petroleum filling stages are determined, including the filling of the Є1+2‐derived oils during the Late Hercynian period, filling of the O2+3‐derived oils during the Yanshan period and oil‐cracking‐gas charge during the Himalayan period. The accumulation processes and relative contribution ratios of the two source rocks vary among the reservoirs and are mainly related to the transport system. Due to the lack of faults in the regions away from the No. 1 Fault Belt, the Є1+2‐derived oils are difficult to fill into the Ordovician reservoirs through the gypsolyte, and thus the accumulated oils are mainly from the O2+3 source rocks. The percentage of the O2+3‐derived oils is high in the southeast and northwest segments of the No. 1 Fault Belt, but relatively low in the middle segment and the vicinity of the No. 10 Structure Belt. Likewise, the late gas charge intensity is controlled by regionally varying conduit systems. Gas condensate formed in reservoirs with high gas/oil ratios. Otherwise, light oil retains with respect to low gas/oil ratios.

show abstract

Genetic origins of marine gases in the Tazhong area of the Tarim basin, NW China: Implications from the pyrolysis of marine kerogens and crude oil

Cited by 49 publications

References 34 publications

The effect of oil expulsion or retention on further thermal degradation of kerogen at the high maturity stage: A pyrolysis study of type II kerogen from Pingliang shale, China

The effect of oil expulsion or retention on further thermal degradation of kerogen at the high maturity stage: A pyrolysis study of type II kerogen from Pingliang shale, China

Early Palaeozoic carbonate reservoirs from the Yingshan Formation of Well block ZG-43 in Tazhong Low Rise, Central Uplift, Tarim Basin, NW China: geological features and controlling factors

Origins and accumulation processes of the Ordovician gas condensate in the Tazhong area, Tarim Basin, northwest China

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