Source rock potential of lignite and interbedded coaly shale of the Ogwashi–Asaba Formation, Anambra basin as determined by sequential hydrous pyrolysis

Akande, Samuel O.; Lewan, Michael D.; Egenhoff, Sven; Adekeye, Olabisi A.; Ojo, Olusola J.; Peterhänsel, Arndt

doi:10.1016/j.coal.2015.09.005

Cited by 24 publications

(15 citation statements)

References 30 publications

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“…Results of HP analysis on type-I kerogen-containing source rocks in Brazil showed that oil generation reached a maximum at about 365°C, followed by a decreasing trend in oil generation, due to the thermal cracking, together with an increasing rate of gas generation (Spigolon et al, 2015). This phenomenon has been considered by other researchers, with similar findings reported (Ruble et al, 2001;Lewan and Kotarba, 2014;Akande et al, 2015;Spigolon et al, 2015).…”

Section: Introductionsupporting

confidence: 59%

“…One such process is thermal cracking whereby hydrocarbon compounds are converted to lighter gaseous compounds. This occurs at elevated test temperatures and increases the gas generation while reducing oil generation (Ruble et al, 2001;Lewan and Kotarba, 2014;Akande et al, 2015). Results of HP analysis on type-I kerogen-containing source rocks in Brazil showed that oil generation reached a maximum at about 365°C, followed by a decreasing trend in oil generation, due to the thermal cracking, together with an increasing rate of gas generation (Spigolon et al, 2015).…”

Section: Introductionmentioning

confidence: 99%

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Investigation of Hydrous Pyrolysis on Type‐II Kerogen‐bearing Source Rocks from Iran and its Application in Geochemical and Kinetic Analyses of Hydrocarbon Products

Kashi

Saberi

Hormozi

2021

Acta Geologica Sinica (Eng)

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Hydrous pyrolysis (HP) practiced on type-II kerogen-bearing oil shale samples from the Sargelu Formation in the Ghali-Kuh Area, western Iran, using a specially designed apparatus was performed at different temperatures (250-350°C), with hydrocarbon generation evaluated at each temperature. For comparison, the samples subjected to Rock-Eval pyrolysis before proceeding to HP resulted in T max = 418°C, HI = 102, and TOC = 4.33%, indicating immaturity and hence remarkable hydrocarbon (especially oil) generation potential, making them appropriate for HP. Moreover, the samples were deposited in a low-energy reductive marine environment, with maximum oil and gas generation (739 mg and 348 mg out of 50 g of rock sample, respectively) observed at 330°C and 350°C, respectively. The oil generated at 330°C was subjected to gas chromatography (GC) and isotopic analyses to assess hydrocarbon quality and composition. The hydrocarbon generation data was devised to estimate kinetic indices of the Arrhenius equation and to investigate the gas-oil ratio (GOR) and overall conversion yield. Based on the producible hydrocarbon quantity and quality, the findings contribute to the economic assessment of oil shales across the study area. The developed kinetic model indicates the history of hydrocarbon generation and organic matter (OM) maturity.

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Section: Introductionsupporting

confidence: 59%

Section: Introductionmentioning

confidence: 99%

Investigation of Hydrous Pyrolysis on Type‐II Kerogen‐bearing Source Rocks from Iran and its Application in Geochemical and Kinetic Analyses of Hydrocarbon Products

Kashi

Saberi

Hormozi

2021

Acta Geologica Sinica (Eng)

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“…Regardless of the type of oil and gas research being conducted, the evolution process is an important and difficult topic. Thermal simulation experiments are often used to simulate thermal evolution in the laboratory to discuss hydrocarbon generation and diagenesis of shales (Xie et al 2014;Akande et al 2015;Guo and Mao 2019). The thermal maturation process undoubtedly has an important influence on the pore evolution of shale.…”

Section: Edited By Jie Haomentioning

confidence: 99%

“…Based on system openness, thermal simulation experiment can be divided into three types: closed system, semi-open system and open system. In this paper, a closed system hydropyrolysis method (Xie et al 2014;Akande et al 2015) was used. Distilled water of half the sample's weight was added to the gold tube to supplement the water consumed during the pyrolysis.…”

Section: Thermal Simulation Experimentsmentioning

confidence: 99%

Porosity model and pore evolution of transitional shales: an example from the Southern North China Basin

Yang

Guo

2020

Pet. Sci.

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The evolution of shale reservoirs is mainly related to two functions: mechanical compaction controlled by ground stress and chemical compaction controlled by thermal effect. Thermal simulation experiments were conducted to simulate the chemical compaction of marine-continental transitional shale, and X-ray diffraction (XRD), CO 2 adsorption, N 2 adsorption and high-pressure mercury injection (MIP) were then used to characterize shale diagenesis and porosity. Moreover, simulations of mechanical compaction adhering to mathematical models were performed, and a shale compaction model was proposed considering clay content and kaolinite proportions. The advantage of this model is that the change in shale compressibility, which is caused by the transformation of clay minerals during thermal evolution, may be considered. The combination of the thermal simulation and compaction model may depict the interactions between chemical and mechanical compaction. Such interactions may then express the pore evolution of shale in actual conditions of formation. Accordingly, the obtained results demonstrated that shales having low kaolinite possess higher porosity at the same burial depth and clay mineral content, proving that other clay minerals such as illite-smectite mixed layers (I/S) and illite are conducive to the development of pores. Shales possessing a high clay mineral content have a higher porosity in shallow layers (< 3500 m) and a lower porosity in deep layers (> 3500 m). Both the amount and location of the increase in porosity differ at different geothermal gradients. High geothermal gradients favor the preservation of high porosity in shale at an appropriate R o. The pore evolution of the marine-continental transitional shale is divided into five stages. Stage 2 possesses an R o of 1.0%-1.6% and has high porosity along with a high specific surface area. Stage 3 has an R o of 1.6%-2.0% and contains a higher porosity with a low specific surface area. Finally, Stage 4 has an R o of 2.0%-2.9% with a low porosity and high specific surface area.

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“…The characteristics of source rock evaluation include the organic matter abundance, kerogen type, and source rock maturity. For this research, source rock maturity primarily includes indexes of vitrinite reflectance and biomarker (Akande et al., 2015; ElAtfy et al., 2014; González et al., 2013; Guo et al., 2015; Hu et al., 2015; Martínez et al., 2014; Tian et al., 2016). However, drilling wells and samples are short in the hydrocarbon-generation center and depression, because these areas have not been conventional oil and gas exploration targets.…”

Section: Introductionmentioning

confidence: 99%

Lower Cretaceous source rock evaluation and thermal maturity evolution of the Chagan depression, Inner Mongolia, Northern China

Zuo

Song

et al. 2017

Energy Exploration & Exploitation

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The Chagan depression has the greatest oil and gas exploration potential in the Yingen-Ejinaqi Basin, Inner Mongolia, northern China. In this paper, source rocks are evaluated and the thermal maturity evolution of typical wells and the primary source rocks is modeled using BasinMod 1D and Basinview software provided by Platte River Associates, Inc. The results show that the Chagan depression developed three sets of source rocks, including the Baiyingebi 1 and 2 Formations and Suhongtu 1 Formation. The Baiyingebi 2 Formation has been the most important source rock in the Chagan depression, dominated by the medium to high maturity source rocks with type II kerogen. This study also reveals that the thermal maturity evolution of source rocks is controlled by the paleogeothermal fields during the Yingen Formation depositional periods when the maximum maturity was reached. The Bayingebi 1 and 2 Formations both experienced the hydrocarbon generation peak and reached the medium to over mature stage. While the Suhongtu 1 Formation has only reached the low to medium mature stage with lower hydrocarbon generation potential. In addition, the source rocks thermal maturity evolution in the West sag is superior to that in the East sag. Therefore, the Bayingebi 2 Formation should be investigated for the oil exploration, and the Wuliji fault nose structural zone and central structural zone will remain the primary targets for the next exploration.

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Source rock potential of lignite and interbedded coaly shale of the Ogwashi–Asaba Formation, Anambra basin as determined by sequential hydrous pyrolysis

Cited by 24 publications

References 30 publications

Investigation of Hydrous Pyrolysis on Type‐II Kerogen‐bearing Source Rocks from Iran and its Application in Geochemical and Kinetic Analyses of Hydrocarbon Products

Investigation of Hydrous Pyrolysis on Type‐II Kerogen‐bearing Source Rocks from Iran and its Application in Geochemical and Kinetic Analyses of Hydrocarbon Products

Porosity model and pore evolution of transitional shales: an example from the Southern North China Basin

Lower Cretaceous source rock evaluation and thermal maturity evolution of the Chagan depression, Inner Mongolia, Northern China

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