Hydrocarbon charge history of the Tazhong Ordovician reservoirs, Tarim Basin as revealed from an integrated fluid inclusion study

Liu, Keyu; Bourdet, Julien; Zhang, Baoshou; Nai, Zhang; Lu, Xuesong; Liu, Shaobo; Pang, Hong; Li, Zhuo; Guo, Xiaowen

doi:10.1016/s1876-3804(13)60021-x

Cited by 61 publications

(26 citation statements)

References 24 publications

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“…T h of the hydrocarbon inclusions ranges from 8°C to 145°C, with a maximum frequency located between 70°C and 85°C (Figure ). The hydrocarbon inclusions with low T h may be trapped with high‐pressure (or overpressure) (Liu et al, ). Homogenization temperature of the associated aqueous inclusions ranges from 72.5°C to 147°C, with a maximum frequency at 85–95°C and a secondary peak at 105–110°C.…”

Section: Resultsmentioning

confidence: 99%

“…Nevertheless, the primary source rock or the specific contribution of the two source rocks to the Ordovician gas condensate in the Tazhong area is still a matter of debate. Researches on timing of the hydrocarbon accumulation stages mainly depend on fluid inclusions (Han et al, , ; Yang et al, ; Zhang, Tian, Xing, & Lu, ; Liu et al, ). Actually, owing to the complex tectonic history, the accurate trapping time of hydrocarbon inclusions is hard to determine without knowing a credible thermal history.…”

Section: Introductionmentioning

confidence: 99%

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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.

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Section: Resultsmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

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

et al. 2017

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“…Paleo structure-source rocksfault systems were well matched temporally and spatially, contributing to the formation of the Mosuowan paleo oil and gas pools. Some scholars have provided evidence for the existence of paleo reservoirs at earlier studies using reservoir GOI method Xie et al 2007;Zou et al 2008), fluorescence color and intensity analysis of organic fluid inclusion (Sun 2009), since the QGF technique was introduced (Liu and Eadington 2005;Liu et al 2007) and successfully applied in many basins of China (Gong et al 2007;Lu et al 2012;Liu et al 2013). In Paleo-oil pool GOI=10% Fig.…”

Section: Geological Settingmentioning

confidence: 99%

“…Therefore, identifying paleo oil pools and restoring their destruction and adjustment process are important for predicting favorable zones. At present, the analysis of paleo oil reservoirs is mainly based on the Grain containing Oil Inclusions method (GOI) (Wang et al 2006;Cao et al 2007) and Quantitative Grain Fluorescence technique (QGF) (Liu and Eadington 2005;Liu et al 2007Liu et al , 2013. GOI method identifies or measures oil inclusions on thin sections and, thus, drill cores are indispensable.…”

Section: Introductionmentioning

confidence: 99%

A method for evaluating paleo hydrocarbon pools and predicting secondary reservoirs: a case study of the Sangonghe Formation in the Mosuowan area, Junggar Basin

Wei

Tao

2018

Pet. Sci.

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Taking the Jurassic Sangonghe Formation in the Mosuowan-Mobei area of the Junggar Basin as an example, this paper provides a method that evaluates paleo hydrocarbon pools and predicts secondary reservoirs. Through Quantitative Grain Fluorescence (QGF) experiments, well-tie seismic correlation, and paleo structure analysis, the scale and distribution of paleo hydrocarbon pools in the study area are outlined. Combining current structural features and fault characteristics, the re-migration pathways of paleo oil and gas are depicted. Based on barrier conditions on the oil re-migration pathways and current reservoir distribution, we recognize three types of secondary reservoirs. By analyzing structural evolution and sand body-fault distribution, the major control factors of secondary reservoirs are specified and, consequently, favorable zones for secondary reservoirs are predicted. The results are mainly as follows. (1) In the primary accumulation period in the Cretaceous, paleo hydrocarbon pools were formed in the Sangonghe Formation of the Mosuowan uplift and their size and distribution were extensive and the exploration potential for secondary reservoirs should not be ignored. Besides, paleo reservoirs were also formed in the Mobei uplift, but just small scale. (2) In the adjustment period in the Neogene, traps were reshaped or destroyed and so were the paleo reservoirs, resulting in oil release. The released oil migrated linearly northward along the structural highs of the Mobei uplift and the Qianshao low-relief uplift and then formed secondary reservoirs when it met new traps. In this process, a structural ridge cooperated with sand bodies and faults, applying unobstructed pathways for oil and gas re-migration. (3) The secondary hydrocarbon pools are classified into three types: low-relief anticlinal type, lithologic pinch-out type and fault block type. The distribution of the first type is controlled by a residual low uplift in the north flank of the paleo-anticline. The second type is distributed in the lithologic pinch-out zones on the periphery of the inherited paleo uplift. The third type is controlled by fault zones of which the strikes are perpendicular to the hydrocarbon re-migration pathways. (4) Four favorable zones for secondary reservoirs are predicted: the low-relief structural zone of the north flank of the Mosuowan paleo-anticline, the fault barrier zone on the western flank of the Mobei uplift, the Qianshao low-relief uplift and the north area of the Mobei uplift that parallels the fault zone. The study above effectively supports the exploration of the Qianshao low-relief uplift, with commercial oil discovered in the Qianshao1 well. Besides, the research process in this paper can also be applied to other basins to explore for secondary reservoirs.

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“…Since 1990s, many new methods such as fluid inclusion studies, reservoir bitumen analysis and diagenetic mineral dating have been widely used. In recent years, the fluid inclusion method has been widely used and has achieved good results (Zhao et al 2013;Guo et al 2012;Yang et al 2014;Xiao et al 2012Xiao et al , 2016Jiang et al 2015a, b, c;Liu et al 2007aLiu et al , b, 2013Gui et al 2015;Wu et al 2013;Wang et al 2015a, b). Fluid inclusions can provide valuable information on the reservoir pressure and temperature at the time of the fluid migration and entrapment as well as on the compositions of the fluids involved in diagenesis and may thus provide important insight into the mineral diagenesis and fluid dynamics within sedimentary basins (Dolníček et al 2012;Shan et al 2015;Wang et al 2015a, b;Guo et al 2014;Lü et al 2015;Li 2016).…”

Section: Introductionmentioning

confidence: 99%

Hydrocarbon charge history of the Paleogene reservoir in the northern Dongpu Depression, Bohai Bay Basin, China

Jiang

Fang²,

Liu

et al. 2016

Pet. Sci.

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The hydrocarbon charge history of the Paleogene in the northern Dongpu Depression was analyzed in detail based on a comprehensive analysis of the generation and expulsion history of the major hydrocarbon source rocks, fluorescence microscopic features and fluid inclusion petrography. There were two main stages of hydrocarbon generation and expulsion of oil from the major hydrocarbon source rocks. The first stage was the main hydrocarbon expulsion stage. The fluorescence microscopic features also indicated two stages of hydrocarbon accumulation. Carbonaceous bitumen, asphaltene bitumen and colloidal bitumen reflected an early hydrocarbon charge, whereas the oil bitumen reflected a second hydrocarbon charge. Hydrocarbon inclusions also indicate two distinct charges according to the diagenetic evolution sequence, inclusion petrography features combined with the homogenization temperature and reservoir burial history analysis. According to these comprehensive analysis results, the hydrocarbon charge history of the Paleogene reservoir in the northern Dongpu Depression was divided into two phases. The first phase was from the late Dongying depositional period of the Oligocene to the early uplift stages of the late Paleogene. The second phase was from the late Minghuazhen period of the Pliocene to the Quaternary. Reservoirs formed during the first period were widely distributed covering the entire area. In contrast, reservoirs formed during the second period were mainly distributed near the hydrocarbon generation sags. Vertically, it was characterized by a single phase in the upper layers and two phases in the lower layers of the Paleogene.

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Hydrocarbon charge history of the Tazhong Ordovician reservoirs, Tarim Basin as revealed from an integrated fluid inclusion study

Cited by 61 publications

References 24 publications

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

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

A method for evaluating paleo hydrocarbon pools and predicting secondary reservoirs: a case study of the Sangonghe Formation in the Mosuowan area, Junggar Basin

Hydrocarbon charge history of the Paleogene reservoir in the northern Dongpu Depression, Bohai Bay Basin, China

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