Formation overpressure and shale oil enrichment in the shale system of Lucaogou Formation, Malang Sag, Santanghu Basin, NW China

Liu, Bo; Lu, Yuanzheng; Zhao, Renda; Tu, Xin; Guo, Xingwei; Shen, Ying

doi:10.1016/s1876-3804(12)60099-8

Cited by 50 publications

(28 citation statements)

References 4 publications

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“…The Ro of K 2 qn 1 and K 2 qn 2 organic matter mainly ranges from 0.5% to 1.35% (Figures 11(a) and 11(b)), and the Tmax (440-460°C) suggests that K 2 qn 1 and K 2 qn organic matter was mainly in mature, which means mature enough to generate oil, especially the organic matter of K 2 qn 1 shale (Figures 11 and 14, Table 1). The S 1 values, abnormally high pressure, and gas measured peak values of the K 2 qn 1 indicate that abundant oil was generated and preserved in the K 2 qn 1 shale of the Southern Songliao Basin (Figures [16][17][18]. Therefore, the high capacity of hydrocarbon generation was crucial to the formation of shale oil.…”

Section: Capacity Of Hydrocarbon Generationmentioning

confidence: 99%

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Enrichment Factors and Resource Potential Evaluation of Qingshankou Formation Lacustrine Shale Oil in the Southern Songliao Basin, NE China

Luo¹,

Tan

Zha

et al. 2021

Geofluids

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China shale oil, which is preserved in lacustrine shale with strong heterogeneity and relatively low maturity, has been a research hotspot of unconventional resources. However, controlling factors of shale oil enrichment and resource potential evaluation restricted efficient exploration and development of lacustrine shale oil. On the basis of well logging data, TOC content, Rock-Eval pyrolysis values, thermal maturity, 100 oil saturation data, and pressure coefficient, the core observation, X-ray diffraction analysis, physical property analysis, scanning electron microscopy, CT scan, well logging interpretation, and volumetric genesis method depending on three-dimensional geological modeling were used to determine enrichment factors and evaluate the resource potential of Qingshankou Formation shale oil in the Southern Songliao Basin. Shale oil was mainly enriched in the semideep and deep lake shale of K2qn1, with the high capacity of hydrocarbon generation and favorable petrological and mineralogical characteristics, pore space characteristics, and physical properties in the low structural part of the Southern Songliao Basin. The three-dimensional geological resource model of Qingshankou Formation lacustrine shale oil was determined by the key parameters (Ro, TOC, and S 1 ) of shale oil in the favorable zone of the Southern Songliao Basin, northeast China. The geological resource of shale oil, which was calculated by two grid computing methods ( F 1 and F 2 ), was, respectively, 1.713 × 10 12 kg and 1.654 × 10 12 kg . The great shale oil resource indicates a promising future in the exploration and development of Qingshankou Formation shale oil of the Southern Songliao Basin.

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Section: Capacity Of Hydrocarbon Generationmentioning

confidence: 99%

“…Besides, the controlling factors and quantitative evaluation methods of oil content are crucial for understanding the resource potential of shale oil [6,9,[14][15][16]. However, control-ling factors and resource potential evaluation of lacustrine shale oil have not been well determined [9,[17][18][19][20][21].…”

Section: Introductionmentioning

confidence: 99%

Enrichment Factors and Resource Potential Evaluation of Qingshankou Formation Lacustrine Shale Oil in the Southern Songliao Basin, NE China

Luo¹,

Tan

Zha

et al. 2021

Geofluids

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“…Santanghu Coalfield is located at Barkol County and Yiwu County, Northeast Xinjiang Province, with a strip shape oriented NW-SE between Moqinwula and Suhaitu Mountains (Liu et al 2012a, b;Song et al 2013;Ge et al 2015;Hackleya et al 2016). Santanghu Coalfield is the largest integrated Coalfield prospecting area in Xinjiang and even in China.…”

Section: Geological Settingmentioning

confidence: 99%

The characteristic and evolution of coal-forming swamp in Hanshuiquan district, Santanghu Coalfield, Xinjiang, NW China, during the Middle Jurassic: evidence from coal petrography, coal facies and sporopollen

Feng¹,

He²,

Tian³

et al. 2019

Int J Coal Sci Technol

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“…The high stratigraphic heterogeneity, high oil density, and low oil fluidity pose significant challenges in the exploration and production of such shale oil. Therefore, it is extremely important to obtain a comprehensive, in-depth understanding of the movability of the retained oil in shale (Liu et al, 2012;Tao et al, 2012;Li et al, 2015;Xie et al, 2015). In this study, core samples of different lithologies were collected from the different strata in well J174 in the Jimsar Sag, Junggar Basin, and then, the samples were subjected to different extraction treatments with n-hexane (nC 6 ) and chloroform (CHCl 3 ), followed by porosity measurements to explore how the extract composition of the component and the rock porosity vary with the extraction treatments and rock types.…”

Section: Introductionmentioning

confidence: 99%

Experimental Methods for the Quantitative Assessment of the Volume Fraction of Movable Shale Oil: A Case Study in the Jimsar Sag, Junggar Basin, China

Zhao

Hou

et al. 2021

Front. Earth Sci.

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Deep insights into the movability of the retained shale oil are of great significance to shale oil. Rock and crude oil samples were collected from well J174 in the Jimsar Sag, Junggar Basin. Rock samples were subjected to different extraction followed by analysis of the component in the extracts, and measurement of porosity in conjunction with nuclear magnetic resonance and high-pressure mercury injection analysis. The results of these analyses were used to establish an experimental method for quantitative assessment of movable shale oil. The extract content of the component varied among different extraction and between mud shale and non-mud shale samples. The saturated hydrocarbon in the extracts of the mud shale was similar to those of the non-mud shale after extraction with CHCl3 alone or after sequential extraction with nC6 + CHCl3. The aromatic hydrocarbon in the extract were significantly lower for the mud shale than for the non-mud shale after extraction with nC6, but the opposite was observed after sequential extraction with nC6 + CHCl3. The contents of the non-hydrocarbon in the extract were significantly lower for the mud shale than for the non-mud shale after extraction with nC6, but the opposite was observed after extraction with CHCl3 or nC6 + CHCl3. The contents of the asphaltene in the extract were not significantly different for the mud shale and non-mud shale after extraction with nC6, but the contents were higher for the mud shale than for the non-mud shale after extraction with nC6 + CHCl3 or CHCl3. The viscosity of the crude oil was negatively correlated with the saturated hydrocarbon, was positively correlated with the aromatic hydrocarbon and non-hydrocarbon, and was not correlated with the asphaltene. For the mud shale and non-mud shale, their porosity after extraction with nC6 or CHCl3 was higher than their original porosity. Moreover, their porosity after extraction with CHCl3 was higher than after extraction with nC6. The movable oil was significantly correlated with the lithology, with sandstone allowing for a higher fluid movability than mud shale and dolomite allowing for a higher fluid movability than siliceous rocks.

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Formation overpressure and shale oil enrichment in the shale system of Lucaogou Formation, Malang Sag, Santanghu Basin, NW China

Cited by 50 publications

References 4 publications

Enrichment Factors and Resource Potential Evaluation of Qingshankou Formation Lacustrine Shale Oil in the Southern Songliao Basin, NE China

Enrichment Factors and Resource Potential Evaluation of Qingshankou Formation Lacustrine Shale Oil in the Southern Songliao Basin, NE China

The characteristic and evolution of coal-forming swamp in Hanshuiquan district, Santanghu Coalfield, Xinjiang, NW China, during the Middle Jurassic: evidence from coal petrography, coal facies and sporopollen

Experimental Methods for the Quantitative Assessment of the Volume Fraction of Movable Shale Oil: A Case Study in the Jimsar Sag, Junggar Basin, China

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