Genetic type and source of natural gas in the southern margin of Junggar Basin, NW China

Chen, Jianping; Wang, Xulong; Ni, Yunyan; Xiang, Baoli; Liao, Fengrong; Liao, Jiande; Zhao, Chunhong

doi:10.1016/s1876-3804(19)60029-7

Cited by 29 publications

(32 citation statements)

References 19 publications

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“…Compared with the study area, the thickness of the Jurassic source rocks can exceed 300 m in the sedimentary center. The TOC contents indicate these two basins all have a set of good Jurassic source rocks, and the Jurassic kerogen type is dominantly type II and type III (Chen et al, 2019;Du et al, 2019;Gao et al, 2013;Qiu et al, 2008;Qian et al, 2018). Moreover, tight reservoirs are widely distributed in the Jurassic of these two areas, and fractures are generally developed, the source rocks are largely in contact with the overlying tight reservoirs or alternate with reservoirs in the vertical direction, which are conducive to the enrichment of tight oil and gas (Du et al, 2019;Luo et al, 2019;.…”

Section: Discussionmentioning

confidence: 98%

“…Jurassic coal-measure strata are widely developed in the Tarim Basin, in the Junggar Basin, and in the Turpan-Hami Basin. The Jurassic strata in the Junggar basin comprise a set of coal bearing sedimentary formations of braided river delta-limnetic facies (Chen et al, 2016;Chen et al, 2019). The main Jurassic sedimentary facies types in the Tarim Basin include fan delta facies, fluvial facies, and lacustrine facies, and the Jurassic strata can be divided into upper and lower parts.…”

Section: Discussionmentioning

confidence: 99%

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Hydrocarbon generation and expulsion of Middle Jurassic lacustrine source rocks in the Turpan–Hami Basin, NW China: Implications for tight oil accumulation

Yuan

Huang

et al. 2020

Energy Exploration & Exploitation

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In recent years, new oil reservoirs have been discovered in the middle Jurassic tight mixed rocks of the Turpan–Hami Basin. However, the generation potential of the J2q2 source rocks remains poorly understood. Petrographic, petrological, and geochemical analyses were carried out to assess the quality of the J2q2 source and reservoir rocks. The hydrocarbon generation potential method was utilized to evaluate the hydrocarbon generation and expulsion potentials. The results indicated that the rocks can be classified as high-quality source rocks with a relative lower degree of maturity. The hydrocarbon bearing zones are classified as tight reservoirs (average porosity of 5.90% and permeability of 0.18 mD) with an average pore throat radius >150 nm, which is higher than the cut-off pore-throat radius. The source rocks start to expel hydrocarbons when Ro% is 0.56%. Bulk hydrocarbon generation and expulsion intensities in the center of the study area were calculated with the values of 900 × 104 t/km2 and 400 × 104 t/km2, while the weights of these hydrocarbons were 48.8 × 108 t and 27.3 × 108 t, respectively. The tight oil reservoir-forming conditions are superior, and the hydrocarbon generation and expulsion intensities are more remarkable in controlling the tight oil distribution. This study provides an important example for the Jurassic source rocks in Western China, and indicates that middle Jurassic lacustrine source rocks deserve attention in future exploration.

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Section: Discussionmentioning

confidence: 98%

Section: Discussionmentioning

confidence: 99%

Hydrocarbon generation and expulsion of Middle Jurassic lacustrine source rocks in the Turpan–Hami Basin, NW China: Implications for tight oil accumulation

Yuan

Huang

et al. 2020

Energy Exploration & Exploitation

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“…In these gas fields or gas-bearing structures, the natural gas reservoirs in the Hutubi, Tugulu, Manas, Horgos, and Anjihai anticlines in the central part are mainly located in the Paleogene Ziniquanzi and Anjihaihe formations, and minor in the Neogene Recently, high-product oil and gas flow was discovered in Well GT1 in the Gaoquan anticline of the Sikeshu sag (Figure 1), west part of the southern margin in the Junggar Basin (Chen et al, 2019;Du et al, 2019), and the oil and gas reservoirs are located in the Toutunhe Formation of Middle Jurassic (Figures 3, 4). Although it is difficult at moment to determine the boundary and scale of oil and gas reservoirs, it was predicted that the structural high trap area of the Gaoquan anticline is about 69 km 2 with the closure height is 450 m, and the Cretaceous structural high trap area where Well GT1 was drilled is about 28 km 2 .…”

Section: Distribution Of Natural Gasmentioning

confidence: 99%

“…In January 2019, high-product oil and gas flow were obtained from Well GT1 in the Gaoquan anticline of the Sikeshu sag, west part of the southern margin in the Junggar Basin, with 1,213 m 3 /d oil and 321.7 × 10 3 m 3 /d natural gas from the deep Cretaceous strata (Chen et al, 2019;Du et al, 2019;Zhang et al, 2020). The daily oil and gas production from this well is the highest in the Junggar Basin so far.…”

Section: Introductionmentioning

confidence: 99%

“…In this study, based on our previous results about the genetic type of natural gas and its sources in the southern margin of Junggar Basin (Chen et al, 2019), we investigated the geological and geochemical conditions for natural gas generation and accumulation in the southern margin of Junggar Basin, and conducted a comparative study between the southern margin of Junggar Basin and the Kuqa Depression of Tarim Basin in terms of factors controlling the natural gas accumulation. Also, the favorable natural gas exploration areas and targets were discussed for strategy-making reference.…”

Section: Introductionmentioning

confidence: 99%

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Factors Controlling Natural Gas Accumulation in the Southern Margin of Junggar Basin and Potential Exploration Targets

et al. 2021

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In this paper, factors controlling natural gas accumulation in the southern margin of Junggar Basin were mainly discussed by a comparison with natural gas generation and accumulation in the Kuqa Depression of Tarim Basin. The southern margin of Junggar Basin and the Kuqa Depression of Tarim Basin are located on the north and south sides of the Tianshan Mountains respectively, and they share the similar sedimentary stratigraphy and tectonic evolution history. In recent several decades, many large gas fields have been found in the Kuqa Depression of Tarim Basin, but no great breakthrough in the southern margin of Junggar Basin. Our results suggest that natural gas in the southern margin of Junggar Basin is mainly thermogenic wet gas, and can be divided into three types as coal-derived gas, mixed gas and oil-associated gas, of which the former two types are dominated. The Jurassic coal measures are the main source rocks of natural gas, and the main gas generation time from this set of source rocks matched well with the formation time of the anticline structures, resulting in favorable conditions for natural gas accumulation. In the western part of the southern margin in the Junggar Basin, the Permian lacustrine and the Upper Triassic lacustrine-swamp source rocks could be important sources of natural gas, and the main gas generation time also matched well with the formation time of traps. Compared with the Kuqa Depression of Tarim Basin, natural gas sources are better in the southern margin of Junggar Basin, and the geologic conditions are favorable for the formation of large oil and gas fields in the southern margin of Junggar Basin. The deep Permian-Jurassic-Cretaceous petroleum system is the most favorable petroleum system for natural gas exploration in the southern margin of Junggar Basin. The western part and the central part of the southern margin in the Junggar Basin could be the first targets for the discovery of the Jurassic coal-derived oil and gas reservoirs. The shallow Cretaceous-Neogene petroleum system is the second target for natural gas exploration.

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Sedimentary environment and a development model for source rocks rich in the green alga Pediastrum: a case study of the paleogene anjihaihe formation in the junggar basin, northwest china

Yu,

Gao,

Zhao

et al. 2024

Int J Earth Sci (Geol Rundsch)

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Genetic type and source of natural gas in the southern margin of Junggar Basin, NW China

Cited by 29 publications

References 19 publications

Hydrocarbon generation and expulsion of Middle Jurassic lacustrine source rocks in the Turpan–Hami Basin, NW China: Implications for tight oil accumulation

Hydrocarbon generation and expulsion of Middle Jurassic lacustrine source rocks in the Turpan–Hami Basin, NW China: Implications for tight oil accumulation

Factors Controlling Natural Gas Accumulation in the Southern Margin of Junggar Basin and Potential Exploration Targets

Sedimentary environment and a development model for source rocks rich in the green alga Pediastrum: a case study of the paleogene anjihaihe formation in the junggar basin, northwest china

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