Exploration breakthroughs and geological characteristics of continental shale oil: A case study of the Kongdian Formation in the Cangdong Sag, China

Zhao, Xianzheng; Zhou, Lihong; Pu, Xipeng; Han, Wenzhong; Jin, Fu; Xiao, Di; Shi, Zheming; Deng, Yuan; Zhang, Wei; Jiang, Wenya

doi:10.1016/j.marpetgeo.2018.12.020

Cited by 66 publications

(28 citation statements)

References 17 publications

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“…In general, the TOC value was positively correlated with S 1 . When TOC is between 1 and 3 wt %, 2 Geofluids the high-value part of S 1 increases rapidly with the increase in TOC. When TOC is greater than 3 wt %, the high-value part of S 1 changes or disappears in a horizontal shape, and there is an obvious upper envelope.…”

Section: Toc and S *mentioning

confidence: 99%

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Quantitative Method for Evaluating Shale Oil Resources Based on Movable Oil Content

Zhao¹,

Pu²,

Jin³

et al. 2021

Geofluids

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The light hydrocarbon content ( S 1 ) of shale oil is lost in aboveground experimental measurements, which do not accurately reflect actual underground light hydrocarbon content and cannot meet the demands of resource quantity calculation. Based on field and laboratory experimental data from the second member of the Kongdian Formation in the Cangdong Sag, Bohai Bay Basin, the retained oil and movable oil contents in shale were calculated using a mathematical formula, and the total resources were quantified. The correction coefficient of S 1 from pyrolysis and the adsorption of oil by the total organic carbon (TOC) were determined to be 1.25 and 100 mg/g, respectively. The calculated parameter movable oil content ( S movable ) and the corresponding calculation formula of S 1 are proposed. The lower limit of S 1 is 100 mg HC/g rock, the TOC content is 4 wt % and 6 wt %, and the corrected movable oil content of 3 mg/g and 6 mg/g, respectively, will be of great significance in shale oil geology and engineering. The optimal geological and engineering settings are divided into three categories and eight subcategories on the basis of these findings. Methods for evaluating total, movable, and recoverable oil resources from shale are discussed, which elucidate a new method for quantitative evaluation and ranking of shale oil resources. This approach is suitable for application in other shale oil exploration and development areas globally.

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Section: Toc and S *mentioning

confidence: 99%

“…Compared with North American shale oil, China's lacustrine oil shales are quite different in terms of reservoir and fluid properties and reservoir transformation characteristics [1,2]. Lacustrine shales in China are mainly grayish and argillaceous shales [3].…”

Section: Introductionmentioning

confidence: 99%

Quantitative Method for Evaluating Shale Oil Resources Based on Movable Oil Content

Zhao¹,

Pu²,

Jin³

et al. 2021

Geofluids

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“…In particular, for the Kongdian Formation in Cangdong Sag, the natural daily yields of two horizontal shale oil wells GD-1701H and GD1702H achieved 20-30 m 3 for more than 300 days by now. Besides, the well G1608 obtained a peak daily oil yield of 60 m 3 after fracturing, producing for 105 days and reaching a cumulative oil production of more than 1704 m 3 (Zhao et al 2019). These discoveries suggest promising shale oil exploration prospects in lacustrine shale oil (Li et al 2014;Wang et al 2019).…”

Section: Introductionmentioning

confidence: 96%

“…China is rich in lacustrine shale oil resources with a recoverable amount of 43.5×10 8 t, ranking the third in the world (EIA 2008). which were found in the Dongying Depression (Wang et al 2015a), Dongpu Depression (DD) (Wang et al , 2015a, Cangdong Sag (Zhao et al 2019), and Zhanhua Depression (Li et al 2017) in Bohai Bay Basin, the Bohai Sea area (Jiang et al 2016), and the Qingshankou Formation in Songliao Edited by Jie Hao and Chun-Yan Tang Basin (Liu et al 2017). In particular, for the Kongdian Formation in Cangdong Sag, the natural daily yields of two horizontal shale oil wells GD-1701H and GD1702H achieved 20-30 m 3 for more than 300 days by now.…”

Section: Introductionmentioning

confidence: 99%

Key factors controlling shale oil enrichment in saline lacustrine rift basin: implications from two shale oil wells in Dongpu Depression, Bohai Bay Basin

Pang

Jiang

et al. 2021

Pet. Sci.

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Comparative analyses of petroleum generation potential, reservoir volume, frackability, and oil mobility were conducted on 102 shale cores from the Dongpu Depression. Results show the shale has high organic matter contents composed of oil-prone type I and type II kerogens within the oil window. Various types of pores and fractures exist in the shale, with a porosity of up to 14.9%. The shale has high brittle mineral contents, extensive fractures, and high potential for oil mobility due to high seepage capacity and overpressure. Although the petroleum generation potential of the shale at Well PS18-8 is relatively greater than that at Well PS18-1, oil content of the latter is greater due to the greater TOC. The porosity and fracture density observed in Well PS18-1 are greater and more conducive to shale oil enrichment. Although the shales in Wells PS18-1 and PS18-8 have similar brittle mineral contents, the former is more favorable for anthropogenic fracturing due to a higher preexisting fracture density. Besides, the shale at Well PS18-1 has a higher seepage capacity and overpressure and therefore a higher oil mobility. The fracture density and overpressure play key roles in shale oil enrichment.

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“…Shutting-in zones providing poor production performance, remotely back and monitoring the production of wells are some of the capabilities of these smart technologies (Jovanov, 2016). The heterogeneous na-ture of reservoirs causes several production-related problems, including viscous fingering of reservoir fluid movements and production of unwanted fluids, such as water and gas, especially in long horizontal wells (Chengzao, 2017;Zhao et al, 2019;Cheng et al, 2020). Advanced well completions utilize downhole flow control technology like interval control valves, inflow control devices (ICD) and autonomous inflow control devices (AICD) to provide practical solutions to the production problems and constraints (Gimre, 2012;Eltaher, 2017).…”

Section: Introductionmentioning

confidence: 99%

Application of mathematical and machine learning models to predict differential pressure of autonomous downhole inﬂow control devices

Yavari

Khosravanian

Wood

et al. 2021

Adv. Geo-Energy Res.

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Exploration breakthroughs and geological characteristics of continental shale oil: A case study of the Kongdian Formation in the Cangdong Sag, China

Cited by 66 publications

References 17 publications

Quantitative Method for Evaluating Shale Oil Resources Based on Movable Oil Content

Quantitative Method for Evaluating Shale Oil Resources Based on Movable Oil Content

Key factors controlling shale oil enrichment in saline lacustrine rift basin: implications from two shale oil wells in Dongpu Depression, Bohai Bay Basin

Application of mathematical and machine learning models to predict differential pressure of autonomous downhole inﬂow control devices

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