Comparison of pore systems of clay-rich and silica-rich gas shales in the lower Silurian Longmaxi formation from the Jiaoshiba area in the eastern Sichuan Basin, China
The Jiaoshiba area in the eastern Sichuan Basin hosts the largest commercial shale gas field in China with an annual production of 1.7 BCF. The gases are primarily produced from the clay-rich siliceous marine shales in the Wufeng and Longmaxi formations. In this paper, sixteen organic-rich shale sam...
Ausführliche Beschreibung
Gespeichert in:
| Autor*in: |
Guo, Xiaowen [verfasserIn] |
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| Format: |
E-Artikel |
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| Sprache: |
Englisch |
| Erschienen: |
2019transfer abstract |
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| Schlagwörter: |
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| Umfang: |
16 |
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| Übergeordnetes Werk: |
Enthalten in: Honesty-Humility and unethical behavior in adolescents: The mediating role of moral disengagement and the moderating role of system justification - Guo, Zhen ELSEVIER, 2021, Amsterdam [u.a.] |
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| Übergeordnetes Werk: |
volume:101 ; year:2019 ; pages:265-280 ; extent:16 |
| Links: |
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| DOI / URN: |
10.1016/j.marpetgeo.2018.11.038 |
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ELV045742499 |
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| 245 | 1 | 0 | |a Comparison of pore systems of clay-rich and silica-rich gas shales in the lower Silurian Longmaxi formation from the Jiaoshiba area in the eastern Sichuan Basin, China |
| 264 | 1 | |c 2019transfer abstract | |
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| 520 | |a The Jiaoshiba area in the eastern Sichuan Basin hosts the largest commercial shale gas field in China with an annual production of 1.7 BCF. The gases are primarily produced from the clay-rich siliceous marine shales in the Wufeng and Longmaxi formations. In this paper, sixteen organic-rich shale samples from a variety of lithofacies from the Longmaxi Formation in the Jiaoshiba area were studied to evaluate the pore systems of clay-rich shales by comparison with the silica-rich gas shales. The investigation includes the assessment of porosity and pore size distribution by means of shale bulk and skeletal density measurements, low-pressure N2/CO2 gas adsorption and mercury intrusion. The shale samples with different lithofacies have porosity values ranging from 3.25% to 5.65% and display similar fractional volumes of micropores, mesopores and macropores, and corresponding specific surface areas. All three pore fractions contribute to the shales’ total pore volumes, while the total specific surface areas are mainly contributed to by micropores and mesopores. There is a positive correlation between pore volumes and TOC contents, indicating that the porosities in the shales are dominated by organic matter pores with TOC content being the main parameter controlling pore development. TOC-normalized pore volumes decrease with a further increase in the TOC content from 1.6% to 4.2%. This may be related to the fact that the TOC-rich shales are more susceptive to mechanical compaction. Clay mineral content appears to have little effect on the pore volume or specific surface area development in the shales. Shale samples with clay-rich siliceous shale lithofacies display similar TOC contents, porosities, and fractional volumes of all pore sizes and specific surface areas with those of the silica-rich argillaceous and argillaceous/siliceous mixed lithofacies. This suggests that the marine shales with silica-rich argillaceous and argillaceous/siliceous mixed lithofacies from the Longmaxi Formation in the Jiaoshiba area are capable of generating significant amount of pore spaces for shale gas storage. | ||
| 520 | |a The Jiaoshiba area in the eastern Sichuan Basin hosts the largest commercial shale gas field in China with an annual production of 1.7 BCF. The gases are primarily produced from the clay-rich siliceous marine shales in the Wufeng and Longmaxi formations. In this paper, sixteen organic-rich shale samples from a variety of lithofacies from the Longmaxi Formation in the Jiaoshiba area were studied to evaluate the pore systems of clay-rich shales by comparison with the silica-rich gas shales. The investigation includes the assessment of porosity and pore size distribution by means of shale bulk and skeletal density measurements, low-pressure N2/CO2 gas adsorption and mercury intrusion. The shale samples with different lithofacies have porosity values ranging from 3.25% to 5.65% and display similar fractional volumes of micropores, mesopores and macropores, and corresponding specific surface areas. All three pore fractions contribute to the shales’ total pore volumes, while the total specific surface areas are mainly contributed to by micropores and mesopores. There is a positive correlation between pore volumes and TOC contents, indicating that the porosities in the shales are dominated by organic matter pores with TOC content being the main parameter controlling pore development. TOC-normalized pore volumes decrease with a further increase in the TOC content from 1.6% to 4.2%. This may be related to the fact that the TOC-rich shales are more susceptive to mechanical compaction. Clay mineral content appears to have little effect on the pore volume or specific surface area development in the shales. Shale samples with clay-rich siliceous shale lithofacies display similar TOC contents, porosities, and fractional volumes of all pore sizes and specific surface areas with those of the silica-rich argillaceous and argillaceous/siliceous mixed lithofacies. This suggests that the marine shales with silica-rich argillaceous and argillaceous/siliceous mixed lithofacies from the Longmaxi Formation in the Jiaoshiba area are capable of generating significant amount of pore spaces for shale gas storage. | ||
| 650 | 7 | |a Sichuan basin |2 Elsevier | |
| 650 | 7 | |a Pore structures |2 Elsevier | |
| 650 | 7 | |a Longmaxi formation |2 Elsevier | |
| 650 | 7 | |a Organic-rich marine shale |2 Elsevier | |
| 650 | 7 | |a Shale lithofacies |2 Elsevier | |
| 700 | 1 | |a Qin, Zhejian |4 oth | |
| 700 | 1 | |a Yang, Rui |4 oth | |
| 700 | 1 | |a Dong, Tian |4 oth | |
| 700 | 1 | |a He, Sheng |4 oth | |
| 700 | 1 | |a Hao, Fang |4 oth | |
| 700 | 1 | |a Yi, Jizheng |4 oth | |
| 700 | 1 | |a Shu, Zhiguo |4 oth | |
| 700 | 1 | |a Bao, Hanyong |4 oth | |
| 700 | 1 | |a Liu, Keyu |4 oth | |
| 773 | 0 | 8 | |i Enthalten in |n Elsevier Science |a Guo, Zhen ELSEVIER |t Honesty-Humility and unethical behavior in adolescents: The mediating role of moral disengagement and the moderating role of system justification |d 2021 |g Amsterdam [u.a.] |w (DE-627)ELV006295584 |
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10.1016/j.marpetgeo.2018.11.038 doi GBV00000000000516.pica (DE-627)ELV045742499 (ELSEVIER)S0264-8172(18)30516-6 DE-627 ger DE-627 rakwb eng 610 VZ 44.67 bkl Guo, Xiaowen verfasserin aut Comparison of pore systems of clay-rich and silica-rich gas shales in the lower Silurian Longmaxi formation from the Jiaoshiba area in the eastern Sichuan Basin, China 2019transfer abstract 16 nicht spezifiziert zzz rdacontent nicht spezifiziert z rdamedia nicht spezifiziert zu rdacarrier The Jiaoshiba area in the eastern Sichuan Basin hosts the largest commercial shale gas field in China with an annual production of 1.7 BCF. The gases are primarily produced from the clay-rich siliceous marine shales in the Wufeng and Longmaxi formations. In this paper, sixteen organic-rich shale samples from a variety of lithofacies from the Longmaxi Formation in the Jiaoshiba area were studied to evaluate the pore systems of clay-rich shales by comparison with the silica-rich gas shales. The investigation includes the assessment of porosity and pore size distribution by means of shale bulk and skeletal density measurements, low-pressure N2/CO2 gas adsorption and mercury intrusion. The shale samples with different lithofacies have porosity values ranging from 3.25% to 5.65% and display similar fractional volumes of micropores, mesopores and macropores, and corresponding specific surface areas. All three pore fractions contribute to the shales’ total pore volumes, while the total specific surface areas are mainly contributed to by micropores and mesopores. There is a positive correlation between pore volumes and TOC contents, indicating that the porosities in the shales are dominated by organic matter pores with TOC content being the main parameter controlling pore development. TOC-normalized pore volumes decrease with a further increase in the TOC content from 1.6% to 4.2%. This may be related to the fact that the TOC-rich shales are more susceptive to mechanical compaction. Clay mineral content appears to have little effect on the pore volume or specific surface area development in the shales. Shale samples with clay-rich siliceous shale lithofacies display similar TOC contents, porosities, and fractional volumes of all pore sizes and specific surface areas with those of the silica-rich argillaceous and argillaceous/siliceous mixed lithofacies. This suggests that the marine shales with silica-rich argillaceous and argillaceous/siliceous mixed lithofacies from the Longmaxi Formation in the Jiaoshiba area are capable of generating significant amount of pore spaces for shale gas storage. The Jiaoshiba area in the eastern Sichuan Basin hosts the largest commercial shale gas field in China with an annual production of 1.7 BCF. The gases are primarily produced from the clay-rich siliceous marine shales in the Wufeng and Longmaxi formations. In this paper, sixteen organic-rich shale samples from a variety of lithofacies from the Longmaxi Formation in the Jiaoshiba area were studied to evaluate the pore systems of clay-rich shales by comparison with the silica-rich gas shales. The investigation includes the assessment of porosity and pore size distribution by means of shale bulk and skeletal density measurements, low-pressure N2/CO2 gas adsorption and mercury intrusion. The shale samples with different lithofacies have porosity values ranging from 3.25% to 5.65% and display similar fractional volumes of micropores, mesopores and macropores, and corresponding specific surface areas. All three pore fractions contribute to the shales’ total pore volumes, while the total specific surface areas are mainly contributed to by micropores and mesopores. There is a positive correlation between pore volumes and TOC contents, indicating that the porosities in the shales are dominated by organic matter pores with TOC content being the main parameter controlling pore development. TOC-normalized pore volumes decrease with a further increase in the TOC content from 1.6% to 4.2%. This may be related to the fact that the TOC-rich shales are more susceptive to mechanical compaction. Clay mineral content appears to have little effect on the pore volume or specific surface area development in the shales. Shale samples with clay-rich siliceous shale lithofacies display similar TOC contents, porosities, and fractional volumes of all pore sizes and specific surface areas with those of the silica-rich argillaceous and argillaceous/siliceous mixed lithofacies. This suggests that the marine shales with silica-rich argillaceous and argillaceous/siliceous mixed lithofacies from the Longmaxi Formation in the Jiaoshiba area are capable of generating significant amount of pore spaces for shale gas storage. Sichuan basin Elsevier Pore structures Elsevier Longmaxi formation Elsevier Organic-rich marine shale Elsevier Shale lithofacies Elsevier Qin, Zhejian oth Yang, Rui oth Dong, Tian oth He, Sheng oth Hao, Fang oth Yi, Jizheng oth Shu, Zhiguo oth Bao, Hanyong oth Liu, Keyu oth Enthalten in Elsevier Science Guo, Zhen ELSEVIER Honesty-Humility and unethical behavior in adolescents: The mediating role of moral disengagement and the moderating role of system justification 2021 Amsterdam [u.a.] (DE-627)ELV006295584 volume:101 year:2019 pages:265-280 extent:16 https://doi.org/10.1016/j.marpetgeo.2018.11.038 Volltext GBV_USEFLAG_U GBV_ELV SYSFLAG_U 44.67 Kinderheilkunde VZ AR 101 2019 265-280 16 |
| spelling |
10.1016/j.marpetgeo.2018.11.038 doi GBV00000000000516.pica (DE-627)ELV045742499 (ELSEVIER)S0264-8172(18)30516-6 DE-627 ger DE-627 rakwb eng 610 VZ 44.67 bkl Guo, Xiaowen verfasserin aut Comparison of pore systems of clay-rich and silica-rich gas shales in the lower Silurian Longmaxi formation from the Jiaoshiba area in the eastern Sichuan Basin, China 2019transfer abstract 16 nicht spezifiziert zzz rdacontent nicht spezifiziert z rdamedia nicht spezifiziert zu rdacarrier The Jiaoshiba area in the eastern Sichuan Basin hosts the largest commercial shale gas field in China with an annual production of 1.7 BCF. The gases are primarily produced from the clay-rich siliceous marine shales in the Wufeng and Longmaxi formations. In this paper, sixteen organic-rich shale samples from a variety of lithofacies from the Longmaxi Formation in the Jiaoshiba area were studied to evaluate the pore systems of clay-rich shales by comparison with the silica-rich gas shales. The investigation includes the assessment of porosity and pore size distribution by means of shale bulk and skeletal density measurements, low-pressure N2/CO2 gas adsorption and mercury intrusion. The shale samples with different lithofacies have porosity values ranging from 3.25% to 5.65% and display similar fractional volumes of micropores, mesopores and macropores, and corresponding specific surface areas. All three pore fractions contribute to the shales’ total pore volumes, while the total specific surface areas are mainly contributed to by micropores and mesopores. There is a positive correlation between pore volumes and TOC contents, indicating that the porosities in the shales are dominated by organic matter pores with TOC content being the main parameter controlling pore development. TOC-normalized pore volumes decrease with a further increase in the TOC content from 1.6% to 4.2%. This may be related to the fact that the TOC-rich shales are more susceptive to mechanical compaction. Clay mineral content appears to have little effect on the pore volume or specific surface area development in the shales. Shale samples with clay-rich siliceous shale lithofacies display similar TOC contents, porosities, and fractional volumes of all pore sizes and specific surface areas with those of the silica-rich argillaceous and argillaceous/siliceous mixed lithofacies. This suggests that the marine shales with silica-rich argillaceous and argillaceous/siliceous mixed lithofacies from the Longmaxi Formation in the Jiaoshiba area are capable of generating significant amount of pore spaces for shale gas storage. The Jiaoshiba area in the eastern Sichuan Basin hosts the largest commercial shale gas field in China with an annual production of 1.7 BCF. The gases are primarily produced from the clay-rich siliceous marine shales in the Wufeng and Longmaxi formations. In this paper, sixteen organic-rich shale samples from a variety of lithofacies from the Longmaxi Formation in the Jiaoshiba area were studied to evaluate the pore systems of clay-rich shales by comparison with the silica-rich gas shales. The investigation includes the assessment of porosity and pore size distribution by means of shale bulk and skeletal density measurements, low-pressure N2/CO2 gas adsorption and mercury intrusion. The shale samples with different lithofacies have porosity values ranging from 3.25% to 5.65% and display similar fractional volumes of micropores, mesopores and macropores, and corresponding specific surface areas. All three pore fractions contribute to the shales’ total pore volumes, while the total specific surface areas are mainly contributed to by micropores and mesopores. There is a positive correlation between pore volumes and TOC contents, indicating that the porosities in the shales are dominated by organic matter pores with TOC content being the main parameter controlling pore development. TOC-normalized pore volumes decrease with a further increase in the TOC content from 1.6% to 4.2%. This may be related to the fact that the TOC-rich shales are more susceptive to mechanical compaction. Clay mineral content appears to have little effect on the pore volume or specific surface area development in the shales. Shale samples with clay-rich siliceous shale lithofacies display similar TOC contents, porosities, and fractional volumes of all pore sizes and specific surface areas with those of the silica-rich argillaceous and argillaceous/siliceous mixed lithofacies. This suggests that the marine shales with silica-rich argillaceous and argillaceous/siliceous mixed lithofacies from the Longmaxi Formation in the Jiaoshiba area are capable of generating significant amount of pore spaces for shale gas storage. Sichuan basin Elsevier Pore structures Elsevier Longmaxi formation Elsevier Organic-rich marine shale Elsevier Shale lithofacies Elsevier Qin, Zhejian oth Yang, Rui oth Dong, Tian oth He, Sheng oth Hao, Fang oth Yi, Jizheng oth Shu, Zhiguo oth Bao, Hanyong oth Liu, Keyu oth Enthalten in Elsevier Science Guo, Zhen ELSEVIER Honesty-Humility and unethical behavior in adolescents: The mediating role of moral disengagement and the moderating role of system justification 2021 Amsterdam [u.a.] (DE-627)ELV006295584 volume:101 year:2019 pages:265-280 extent:16 https://doi.org/10.1016/j.marpetgeo.2018.11.038 Volltext GBV_USEFLAG_U GBV_ELV SYSFLAG_U 44.67 Kinderheilkunde VZ AR 101 2019 265-280 16 |
| allfields_unstemmed |
10.1016/j.marpetgeo.2018.11.038 doi GBV00000000000516.pica (DE-627)ELV045742499 (ELSEVIER)S0264-8172(18)30516-6 DE-627 ger DE-627 rakwb eng 610 VZ 44.67 bkl Guo, Xiaowen verfasserin aut Comparison of pore systems of clay-rich and silica-rich gas shales in the lower Silurian Longmaxi formation from the Jiaoshiba area in the eastern Sichuan Basin, China 2019transfer abstract 16 nicht spezifiziert zzz rdacontent nicht spezifiziert z rdamedia nicht spezifiziert zu rdacarrier The Jiaoshiba area in the eastern Sichuan Basin hosts the largest commercial shale gas field in China with an annual production of 1.7 BCF. The gases are primarily produced from the clay-rich siliceous marine shales in the Wufeng and Longmaxi formations. In this paper, sixteen organic-rich shale samples from a variety of lithofacies from the Longmaxi Formation in the Jiaoshiba area were studied to evaluate the pore systems of clay-rich shales by comparison with the silica-rich gas shales. The investigation includes the assessment of porosity and pore size distribution by means of shale bulk and skeletal density measurements, low-pressure N2/CO2 gas adsorption and mercury intrusion. The shale samples with different lithofacies have porosity values ranging from 3.25% to 5.65% and display similar fractional volumes of micropores, mesopores and macropores, and corresponding specific surface areas. All three pore fractions contribute to the shales’ total pore volumes, while the total specific surface areas are mainly contributed to by micropores and mesopores. There is a positive correlation between pore volumes and TOC contents, indicating that the porosities in the shales are dominated by organic matter pores with TOC content being the main parameter controlling pore development. TOC-normalized pore volumes decrease with a further increase in the TOC content from 1.6% to 4.2%. This may be related to the fact that the TOC-rich shales are more susceptive to mechanical compaction. Clay mineral content appears to have little effect on the pore volume or specific surface area development in the shales. Shale samples with clay-rich siliceous shale lithofacies display similar TOC contents, porosities, and fractional volumes of all pore sizes and specific surface areas with those of the silica-rich argillaceous and argillaceous/siliceous mixed lithofacies. This suggests that the marine shales with silica-rich argillaceous and argillaceous/siliceous mixed lithofacies from the Longmaxi Formation in the Jiaoshiba area are capable of generating significant amount of pore spaces for shale gas storage. The Jiaoshiba area in the eastern Sichuan Basin hosts the largest commercial shale gas field in China with an annual production of 1.7 BCF. The gases are primarily produced from the clay-rich siliceous marine shales in the Wufeng and Longmaxi formations. In this paper, sixteen organic-rich shale samples from a variety of lithofacies from the Longmaxi Formation in the Jiaoshiba area were studied to evaluate the pore systems of clay-rich shales by comparison with the silica-rich gas shales. The investigation includes the assessment of porosity and pore size distribution by means of shale bulk and skeletal density measurements, low-pressure N2/CO2 gas adsorption and mercury intrusion. The shale samples with different lithofacies have porosity values ranging from 3.25% to 5.65% and display similar fractional volumes of micropores, mesopores and macropores, and corresponding specific surface areas. All three pore fractions contribute to the shales’ total pore volumes, while the total specific surface areas are mainly contributed to by micropores and mesopores. There is a positive correlation between pore volumes and TOC contents, indicating that the porosities in the shales are dominated by organic matter pores with TOC content being the main parameter controlling pore development. TOC-normalized pore volumes decrease with a further increase in the TOC content from 1.6% to 4.2%. This may be related to the fact that the TOC-rich shales are more susceptive to mechanical compaction. Clay mineral content appears to have little effect on the pore volume or specific surface area development in the shales. Shale samples with clay-rich siliceous shale lithofacies display similar TOC contents, porosities, and fractional volumes of all pore sizes and specific surface areas with those of the silica-rich argillaceous and argillaceous/siliceous mixed lithofacies. This suggests that the marine shales with silica-rich argillaceous and argillaceous/siliceous mixed lithofacies from the Longmaxi Formation in the Jiaoshiba area are capable of generating significant amount of pore spaces for shale gas storage. Sichuan basin Elsevier Pore structures Elsevier Longmaxi formation Elsevier Organic-rich marine shale Elsevier Shale lithofacies Elsevier Qin, Zhejian oth Yang, Rui oth Dong, Tian oth He, Sheng oth Hao, Fang oth Yi, Jizheng oth Shu, Zhiguo oth Bao, Hanyong oth Liu, Keyu oth Enthalten in Elsevier Science Guo, Zhen ELSEVIER Honesty-Humility and unethical behavior in adolescents: The mediating role of moral disengagement and the moderating role of system justification 2021 Amsterdam [u.a.] (DE-627)ELV006295584 volume:101 year:2019 pages:265-280 extent:16 https://doi.org/10.1016/j.marpetgeo.2018.11.038 Volltext GBV_USEFLAG_U GBV_ELV SYSFLAG_U 44.67 Kinderheilkunde VZ AR 101 2019 265-280 16 |
| allfieldsGer |
10.1016/j.marpetgeo.2018.11.038 doi GBV00000000000516.pica (DE-627)ELV045742499 (ELSEVIER)S0264-8172(18)30516-6 DE-627 ger DE-627 rakwb eng 610 VZ 44.67 bkl Guo, Xiaowen verfasserin aut Comparison of pore systems of clay-rich and silica-rich gas shales in the lower Silurian Longmaxi formation from the Jiaoshiba area in the eastern Sichuan Basin, China 2019transfer abstract 16 nicht spezifiziert zzz rdacontent nicht spezifiziert z rdamedia nicht spezifiziert zu rdacarrier The Jiaoshiba area in the eastern Sichuan Basin hosts the largest commercial shale gas field in China with an annual production of 1.7 BCF. The gases are primarily produced from the clay-rich siliceous marine shales in the Wufeng and Longmaxi formations. In this paper, sixteen organic-rich shale samples from a variety of lithofacies from the Longmaxi Formation in the Jiaoshiba area were studied to evaluate the pore systems of clay-rich shales by comparison with the silica-rich gas shales. The investigation includes the assessment of porosity and pore size distribution by means of shale bulk and skeletal density measurements, low-pressure N2/CO2 gas adsorption and mercury intrusion. The shale samples with different lithofacies have porosity values ranging from 3.25% to 5.65% and display similar fractional volumes of micropores, mesopores and macropores, and corresponding specific surface areas. All three pore fractions contribute to the shales’ total pore volumes, while the total specific surface areas are mainly contributed to by micropores and mesopores. There is a positive correlation between pore volumes and TOC contents, indicating that the porosities in the shales are dominated by organic matter pores with TOC content being the main parameter controlling pore development. TOC-normalized pore volumes decrease with a further increase in the TOC content from 1.6% to 4.2%. This may be related to the fact that the TOC-rich shales are more susceptive to mechanical compaction. Clay mineral content appears to have little effect on the pore volume or specific surface area development in the shales. Shale samples with clay-rich siliceous shale lithofacies display similar TOC contents, porosities, and fractional volumes of all pore sizes and specific surface areas with those of the silica-rich argillaceous and argillaceous/siliceous mixed lithofacies. This suggests that the marine shales with silica-rich argillaceous and argillaceous/siliceous mixed lithofacies from the Longmaxi Formation in the Jiaoshiba area are capable of generating significant amount of pore spaces for shale gas storage. The Jiaoshiba area in the eastern Sichuan Basin hosts the largest commercial shale gas field in China with an annual production of 1.7 BCF. The gases are primarily produced from the clay-rich siliceous marine shales in the Wufeng and Longmaxi formations. In this paper, sixteen organic-rich shale samples from a variety of lithofacies from the Longmaxi Formation in the Jiaoshiba area were studied to evaluate the pore systems of clay-rich shales by comparison with the silica-rich gas shales. The investigation includes the assessment of porosity and pore size distribution by means of shale bulk and skeletal density measurements, low-pressure N2/CO2 gas adsorption and mercury intrusion. The shale samples with different lithofacies have porosity values ranging from 3.25% to 5.65% and display similar fractional volumes of micropores, mesopores and macropores, and corresponding specific surface areas. All three pore fractions contribute to the shales’ total pore volumes, while the total specific surface areas are mainly contributed to by micropores and mesopores. There is a positive correlation between pore volumes and TOC contents, indicating that the porosities in the shales are dominated by organic matter pores with TOC content being the main parameter controlling pore development. TOC-normalized pore volumes decrease with a further increase in the TOC content from 1.6% to 4.2%. This may be related to the fact that the TOC-rich shales are more susceptive to mechanical compaction. Clay mineral content appears to have little effect on the pore volume or specific surface area development in the shales. Shale samples with clay-rich siliceous shale lithofacies display similar TOC contents, porosities, and fractional volumes of all pore sizes and specific surface areas with those of the silica-rich argillaceous and argillaceous/siliceous mixed lithofacies. This suggests that the marine shales with silica-rich argillaceous and argillaceous/siliceous mixed lithofacies from the Longmaxi Formation in the Jiaoshiba area are capable of generating significant amount of pore spaces for shale gas storage. Sichuan basin Elsevier Pore structures Elsevier Longmaxi formation Elsevier Organic-rich marine shale Elsevier Shale lithofacies Elsevier Qin, Zhejian oth Yang, Rui oth Dong, Tian oth He, Sheng oth Hao, Fang oth Yi, Jizheng oth Shu, Zhiguo oth Bao, Hanyong oth Liu, Keyu oth Enthalten in Elsevier Science Guo, Zhen ELSEVIER Honesty-Humility and unethical behavior in adolescents: The mediating role of moral disengagement and the moderating role of system justification 2021 Amsterdam [u.a.] (DE-627)ELV006295584 volume:101 year:2019 pages:265-280 extent:16 https://doi.org/10.1016/j.marpetgeo.2018.11.038 Volltext GBV_USEFLAG_U GBV_ELV SYSFLAG_U 44.67 Kinderheilkunde VZ AR 101 2019 265-280 16 |
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10.1016/j.marpetgeo.2018.11.038 doi GBV00000000000516.pica (DE-627)ELV045742499 (ELSEVIER)S0264-8172(18)30516-6 DE-627 ger DE-627 rakwb eng 610 VZ 44.67 bkl Guo, Xiaowen verfasserin aut Comparison of pore systems of clay-rich and silica-rich gas shales in the lower Silurian Longmaxi formation from the Jiaoshiba area in the eastern Sichuan Basin, China 2019transfer abstract 16 nicht spezifiziert zzz rdacontent nicht spezifiziert z rdamedia nicht spezifiziert zu rdacarrier The Jiaoshiba area in the eastern Sichuan Basin hosts the largest commercial shale gas field in China with an annual production of 1.7 BCF. The gases are primarily produced from the clay-rich siliceous marine shales in the Wufeng and Longmaxi formations. In this paper, sixteen organic-rich shale samples from a variety of lithofacies from the Longmaxi Formation in the Jiaoshiba area were studied to evaluate the pore systems of clay-rich shales by comparison with the silica-rich gas shales. The investigation includes the assessment of porosity and pore size distribution by means of shale bulk and skeletal density measurements, low-pressure N2/CO2 gas adsorption and mercury intrusion. The shale samples with different lithofacies have porosity values ranging from 3.25% to 5.65% and display similar fractional volumes of micropores, mesopores and macropores, and corresponding specific surface areas. All three pore fractions contribute to the shales’ total pore volumes, while the total specific surface areas are mainly contributed to by micropores and mesopores. There is a positive correlation between pore volumes and TOC contents, indicating that the porosities in the shales are dominated by organic matter pores with TOC content being the main parameter controlling pore development. TOC-normalized pore volumes decrease with a further increase in the TOC content from 1.6% to 4.2%. This may be related to the fact that the TOC-rich shales are more susceptive to mechanical compaction. Clay mineral content appears to have little effect on the pore volume or specific surface area development in the shales. Shale samples with clay-rich siliceous shale lithofacies display similar TOC contents, porosities, and fractional volumes of all pore sizes and specific surface areas with those of the silica-rich argillaceous and argillaceous/siliceous mixed lithofacies. This suggests that the marine shales with silica-rich argillaceous and argillaceous/siliceous mixed lithofacies from the Longmaxi Formation in the Jiaoshiba area are capable of generating significant amount of pore spaces for shale gas storage. The Jiaoshiba area in the eastern Sichuan Basin hosts the largest commercial shale gas field in China with an annual production of 1.7 BCF. The gases are primarily produced from the clay-rich siliceous marine shales in the Wufeng and Longmaxi formations. In this paper, sixteen organic-rich shale samples from a variety of lithofacies from the Longmaxi Formation in the Jiaoshiba area were studied to evaluate the pore systems of clay-rich shales by comparison with the silica-rich gas shales. The investigation includes the assessment of porosity and pore size distribution by means of shale bulk and skeletal density measurements, low-pressure N2/CO2 gas adsorption and mercury intrusion. The shale samples with different lithofacies have porosity values ranging from 3.25% to 5.65% and display similar fractional volumes of micropores, mesopores and macropores, and corresponding specific surface areas. All three pore fractions contribute to the shales’ total pore volumes, while the total specific surface areas are mainly contributed to by micropores and mesopores. There is a positive correlation between pore volumes and TOC contents, indicating that the porosities in the shales are dominated by organic matter pores with TOC content being the main parameter controlling pore development. TOC-normalized pore volumes decrease with a further increase in the TOC content from 1.6% to 4.2%. This may be related to the fact that the TOC-rich shales are more susceptive to mechanical compaction. Clay mineral content appears to have little effect on the pore volume or specific surface area development in the shales. Shale samples with clay-rich siliceous shale lithofacies display similar TOC contents, porosities, and fractional volumes of all pore sizes and specific surface areas with those of the silica-rich argillaceous and argillaceous/siliceous mixed lithofacies. This suggests that the marine shales with silica-rich argillaceous and argillaceous/siliceous mixed lithofacies from the Longmaxi Formation in the Jiaoshiba area are capable of generating significant amount of pore spaces for shale gas storage. Sichuan basin Elsevier Pore structures Elsevier Longmaxi formation Elsevier Organic-rich marine shale Elsevier Shale lithofacies Elsevier Qin, Zhejian oth Yang, Rui oth Dong, Tian oth He, Sheng oth Hao, Fang oth Yi, Jizheng oth Shu, Zhiguo oth Bao, Hanyong oth Liu, Keyu oth Enthalten in Elsevier Science Guo, Zhen ELSEVIER Honesty-Humility and unethical behavior in adolescents: The mediating role of moral disengagement and the moderating role of system justification 2021 Amsterdam [u.a.] (DE-627)ELV006295584 volume:101 year:2019 pages:265-280 extent:16 https://doi.org/10.1016/j.marpetgeo.2018.11.038 Volltext GBV_USEFLAG_U GBV_ELV SYSFLAG_U 44.67 Kinderheilkunde VZ AR 101 2019 265-280 16 |
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comparison of pore systems of clay-rich and silica-rich gas shales in the lower silurian longmaxi formation from the jiaoshiba area in the eastern sichuan basin, china |
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Comparison of pore systems of clay-rich and silica-rich gas shales in the lower Silurian Longmaxi formation from the Jiaoshiba area in the eastern Sichuan Basin, China |
| abstract |
The Jiaoshiba area in the eastern Sichuan Basin hosts the largest commercial shale gas field in China with an annual production of 1.7 BCF. The gases are primarily produced from the clay-rich siliceous marine shales in the Wufeng and Longmaxi formations. In this paper, sixteen organic-rich shale samples from a variety of lithofacies from the Longmaxi Formation in the Jiaoshiba area were studied to evaluate the pore systems of clay-rich shales by comparison with the silica-rich gas shales. The investigation includes the assessment of porosity and pore size distribution by means of shale bulk and skeletal density measurements, low-pressure N2/CO2 gas adsorption and mercury intrusion. The shale samples with different lithofacies have porosity values ranging from 3.25% to 5.65% and display similar fractional volumes of micropores, mesopores and macropores, and corresponding specific surface areas. All three pore fractions contribute to the shales’ total pore volumes, while the total specific surface areas are mainly contributed to by micropores and mesopores. There is a positive correlation between pore volumes and TOC contents, indicating that the porosities in the shales are dominated by organic matter pores with TOC content being the main parameter controlling pore development. TOC-normalized pore volumes decrease with a further increase in the TOC content from 1.6% to 4.2%. This may be related to the fact that the TOC-rich shales are more susceptive to mechanical compaction. Clay mineral content appears to have little effect on the pore volume or specific surface area development in the shales. Shale samples with clay-rich siliceous shale lithofacies display similar TOC contents, porosities, and fractional volumes of all pore sizes and specific surface areas with those of the silica-rich argillaceous and argillaceous/siliceous mixed lithofacies. This suggests that the marine shales with silica-rich argillaceous and argillaceous/siliceous mixed lithofacies from the Longmaxi Formation in the Jiaoshiba area are capable of generating significant amount of pore spaces for shale gas storage. |
| abstractGer |
The Jiaoshiba area in the eastern Sichuan Basin hosts the largest commercial shale gas field in China with an annual production of 1.7 BCF. The gases are primarily produced from the clay-rich siliceous marine shales in the Wufeng and Longmaxi formations. In this paper, sixteen organic-rich shale samples from a variety of lithofacies from the Longmaxi Formation in the Jiaoshiba area were studied to evaluate the pore systems of clay-rich shales by comparison with the silica-rich gas shales. The investigation includes the assessment of porosity and pore size distribution by means of shale bulk and skeletal density measurements, low-pressure N2/CO2 gas adsorption and mercury intrusion. The shale samples with different lithofacies have porosity values ranging from 3.25% to 5.65% and display similar fractional volumes of micropores, mesopores and macropores, and corresponding specific surface areas. All three pore fractions contribute to the shales’ total pore volumes, while the total specific surface areas are mainly contributed to by micropores and mesopores. There is a positive correlation between pore volumes and TOC contents, indicating that the porosities in the shales are dominated by organic matter pores with TOC content being the main parameter controlling pore development. TOC-normalized pore volumes decrease with a further increase in the TOC content from 1.6% to 4.2%. This may be related to the fact that the TOC-rich shales are more susceptive to mechanical compaction. Clay mineral content appears to have little effect on the pore volume or specific surface area development in the shales. Shale samples with clay-rich siliceous shale lithofacies display similar TOC contents, porosities, and fractional volumes of all pore sizes and specific surface areas with those of the silica-rich argillaceous and argillaceous/siliceous mixed lithofacies. This suggests that the marine shales with silica-rich argillaceous and argillaceous/siliceous mixed lithofacies from the Longmaxi Formation in the Jiaoshiba area are capable of generating significant amount of pore spaces for shale gas storage. |
| abstract_unstemmed |
The Jiaoshiba area in the eastern Sichuan Basin hosts the largest commercial shale gas field in China with an annual production of 1.7 BCF. The gases are primarily produced from the clay-rich siliceous marine shales in the Wufeng and Longmaxi formations. In this paper, sixteen organic-rich shale samples from a variety of lithofacies from the Longmaxi Formation in the Jiaoshiba area were studied to evaluate the pore systems of clay-rich shales by comparison with the silica-rich gas shales. The investigation includes the assessment of porosity and pore size distribution by means of shale bulk and skeletal density measurements, low-pressure N2/CO2 gas adsorption and mercury intrusion. The shale samples with different lithofacies have porosity values ranging from 3.25% to 5.65% and display similar fractional volumes of micropores, mesopores and macropores, and corresponding specific surface areas. All three pore fractions contribute to the shales’ total pore volumes, while the total specific surface areas are mainly contributed to by micropores and mesopores. There is a positive correlation between pore volumes and TOC contents, indicating that the porosities in the shales are dominated by organic matter pores with TOC content being the main parameter controlling pore development. TOC-normalized pore volumes decrease with a further increase in the TOC content from 1.6% to 4.2%. This may be related to the fact that the TOC-rich shales are more susceptive to mechanical compaction. Clay mineral content appears to have little effect on the pore volume or specific surface area development in the shales. Shale samples with clay-rich siliceous shale lithofacies display similar TOC contents, porosities, and fractional volumes of all pore sizes and specific surface areas with those of the silica-rich argillaceous and argillaceous/siliceous mixed lithofacies. This suggests that the marine shales with silica-rich argillaceous and argillaceous/siliceous mixed lithofacies from the Longmaxi Formation in the Jiaoshiba area are capable of generating significant amount of pore spaces for shale gas storage. |
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<?xml version="1.0" encoding="UTF-8"?><collection xmlns="http://www.loc.gov/MARC21/slim"><record><leader>01000caa a22002652 4500</leader><controlfield tag="001">ELV045742499</controlfield><controlfield tag="003">DE-627</controlfield><controlfield tag="005">20230626012202.0</controlfield><controlfield tag="007">cr uuu---uuuuu</controlfield><controlfield tag="008">191021s2019 xx |||||o 00| ||eng c</controlfield><datafield tag="024" ind1="7" ind2=" "><subfield code="a">10.1016/j.marpetgeo.2018.11.038</subfield><subfield code="2">doi</subfield></datafield><datafield tag="028" ind1="5" ind2="2"><subfield code="a">GBV00000000000516.pica</subfield></datafield><datafield tag="035" ind1=" " ind2=" "><subfield code="a">(DE-627)ELV045742499</subfield></datafield><datafield tag="035" ind1=" " ind2=" "><subfield code="a">(ELSEVIER)S0264-8172(18)30516-6</subfield></datafield><datafield tag="040" ind1=" " ind2=" "><subfield code="a">DE-627</subfield><subfield code="b">ger</subfield><subfield code="c">DE-627</subfield><subfield code="e">rakwb</subfield></datafield><datafield tag="041" ind1=" " ind2=" "><subfield code="a">eng</subfield></datafield><datafield tag="082" ind1="0" ind2="4"><subfield code="a">610</subfield><subfield code="q">VZ</subfield></datafield><datafield tag="084" ind1=" " ind2=" "><subfield code="a">44.67</subfield><subfield code="2">bkl</subfield></datafield><datafield tag="100" ind1="1" ind2=" "><subfield code="a">Guo, Xiaowen</subfield><subfield code="e">verfasserin</subfield><subfield code="4">aut</subfield></datafield><datafield tag="245" ind1="1" ind2="0"><subfield code="a">Comparison of pore systems of clay-rich and silica-rich gas shales in the lower Silurian Longmaxi formation from the Jiaoshiba area in the eastern Sichuan Basin, China</subfield></datafield><datafield tag="264" ind1=" " ind2="1"><subfield code="c">2019transfer abstract</subfield></datafield><datafield tag="300" ind1=" " ind2=" "><subfield code="a">16</subfield></datafield><datafield tag="336" ind1=" " ind2=" "><subfield code="a">nicht spezifiziert</subfield><subfield code="b">zzz</subfield><subfield code="2">rdacontent</subfield></datafield><datafield tag="337" ind1=" " ind2=" "><subfield code="a">nicht spezifiziert</subfield><subfield code="b">z</subfield><subfield code="2">rdamedia</subfield></datafield><datafield tag="338" ind1=" " ind2=" "><subfield code="a">nicht spezifiziert</subfield><subfield code="b">zu</subfield><subfield code="2">rdacarrier</subfield></datafield><datafield tag="520" ind1=" " ind2=" "><subfield code="a">The Jiaoshiba area in the eastern Sichuan Basin hosts the largest commercial shale gas field in China with an annual production of 1.7 BCF. The gases are primarily produced from the clay-rich siliceous marine shales in the Wufeng and Longmaxi formations. In this paper, sixteen organic-rich shale samples from a variety of lithofacies from the Longmaxi Formation in the Jiaoshiba area were studied to evaluate the pore systems of clay-rich shales by comparison with the silica-rich gas shales. The investigation includes the assessment of porosity and pore size distribution by means of shale bulk and skeletal density measurements, low-pressure N2/CO2 gas adsorption and mercury intrusion. The shale samples with different lithofacies have porosity values ranging from 3.25% to 5.65% and display similar fractional volumes of micropores, mesopores and macropores, and corresponding specific surface areas. All three pore fractions contribute to the shales’ total pore volumes, while the total specific surface areas are mainly contributed to by micropores and mesopores. There is a positive correlation between pore volumes and TOC contents, indicating that the porosities in the shales are dominated by organic matter pores with TOC content being the main parameter controlling pore development. TOC-normalized pore volumes decrease with a further increase in the TOC content from 1.6% to 4.2%. This may be related to the fact that the TOC-rich shales are more susceptive to mechanical compaction. Clay mineral content appears to have little effect on the pore volume or specific surface area development in the shales. Shale samples with clay-rich siliceous shale lithofacies display similar TOC contents, porosities, and fractional volumes of all pore sizes and specific surface areas with those of the silica-rich argillaceous and argillaceous/siliceous mixed lithofacies. This suggests that the marine shales with silica-rich argillaceous and argillaceous/siliceous mixed lithofacies from the Longmaxi Formation in the Jiaoshiba area are capable of generating significant amount of pore spaces for shale gas storage.</subfield></datafield><datafield tag="520" ind1=" " ind2=" "><subfield code="a">The Jiaoshiba area in the eastern Sichuan Basin hosts the largest commercial shale gas field in China with an annual production of 1.7 BCF. The gases are primarily produced from the clay-rich siliceous marine shales in the Wufeng and Longmaxi formations. In this paper, sixteen organic-rich shale samples from a variety of lithofacies from the Longmaxi Formation in the Jiaoshiba area were studied to evaluate the pore systems of clay-rich shales by comparison with the silica-rich gas shales. The investigation includes the assessment of porosity and pore size distribution by means of shale bulk and skeletal density measurements, low-pressure N2/CO2 gas adsorption and mercury intrusion. The shale samples with different lithofacies have porosity values ranging from 3.25% to 5.65% and display similar fractional volumes of micropores, mesopores and macropores, and corresponding specific surface areas. All three pore fractions contribute to the shales’ total pore volumes, while the total specific surface areas are mainly contributed to by micropores and mesopores. There is a positive correlation between pore volumes and TOC contents, indicating that the porosities in the shales are dominated by organic matter pores with TOC content being the main parameter controlling pore development. TOC-normalized pore volumes decrease with a further increase in the TOC content from 1.6% to 4.2%. This may be related to the fact that the TOC-rich shales are more susceptive to mechanical compaction. Clay mineral content appears to have little effect on the pore volume or specific surface area development in the shales. Shale samples with clay-rich siliceous shale lithofacies display similar TOC contents, porosities, and fractional volumes of all pore sizes and specific surface areas with those of the silica-rich argillaceous and argillaceous/siliceous mixed lithofacies. This suggests that the marine shales with silica-rich argillaceous and argillaceous/siliceous mixed lithofacies from the Longmaxi Formation in the Jiaoshiba area are capable of generating significant amount of pore spaces for shale gas storage.</subfield></datafield><datafield tag="650" ind1=" " ind2="7"><subfield code="a">Sichuan basin</subfield><subfield code="2">Elsevier</subfield></datafield><datafield tag="650" ind1=" " ind2="7"><subfield code="a">Pore structures</subfield><subfield code="2">Elsevier</subfield></datafield><datafield tag="650" ind1=" " ind2="7"><subfield code="a">Longmaxi formation</subfield><subfield code="2">Elsevier</subfield></datafield><datafield tag="650" ind1=" " ind2="7"><subfield code="a">Organic-rich marine shale</subfield><subfield code="2">Elsevier</subfield></datafield><datafield tag="650" ind1=" " ind2="7"><subfield code="a">Shale lithofacies</subfield><subfield code="2">Elsevier</subfield></datafield><datafield tag="700" ind1="1" ind2=" "><subfield code="a">Qin, Zhejian</subfield><subfield code="4">oth</subfield></datafield><datafield tag="700" ind1="1" ind2=" "><subfield code="a">Yang, Rui</subfield><subfield code="4">oth</subfield></datafield><datafield tag="700" ind1="1" ind2=" "><subfield code="a">Dong, Tian</subfield><subfield code="4">oth</subfield></datafield><datafield tag="700" ind1="1" ind2=" "><subfield code="a">He, Sheng</subfield><subfield code="4">oth</subfield></datafield><datafield tag="700" ind1="1" ind2=" "><subfield code="a">Hao, Fang</subfield><subfield code="4">oth</subfield></datafield><datafield tag="700" ind1="1" ind2=" "><subfield code="a">Yi, Jizheng</subfield><subfield code="4">oth</subfield></datafield><datafield tag="700" ind1="1" ind2=" "><subfield code="a">Shu, Zhiguo</subfield><subfield code="4">oth</subfield></datafield><datafield tag="700" ind1="1" ind2=" "><subfield code="a">Bao, Hanyong</subfield><subfield code="4">oth</subfield></datafield><datafield tag="700" ind1="1" ind2=" "><subfield code="a">Liu, Keyu</subfield><subfield code="4">oth</subfield></datafield><datafield tag="773" ind1="0" ind2="8"><subfield code="i">Enthalten in</subfield><subfield code="n">Elsevier Science</subfield><subfield code="a">Guo, Zhen ELSEVIER</subfield><subfield code="t">Honesty-Humility and unethical behavior in adolescents: The mediating role of moral disengagement and the moderating role of system justification</subfield><subfield code="d">2021</subfield><subfield code="g">Amsterdam [u.a.]</subfield><subfield code="w">(DE-627)ELV006295584</subfield></datafield><datafield tag="773" ind1="1" ind2="8"><subfield code="g">volume:101</subfield><subfield code="g">year:2019</subfield><subfield code="g">pages:265-280</subfield><subfield code="g">extent:16</subfield></datafield><datafield tag="856" ind1="4" ind2="0"><subfield code="u">https://doi.org/10.1016/j.marpetgeo.2018.11.038</subfield><subfield code="3">Volltext</subfield></datafield><datafield tag="912" ind1=" " ind2=" "><subfield code="a">GBV_USEFLAG_U</subfield></datafield><datafield tag="912" ind1=" " ind2=" "><subfield code="a">GBV_ELV</subfield></datafield><datafield tag="912" ind1=" " ind2=" "><subfield code="a">SYSFLAG_U</subfield></datafield><datafield tag="936" ind1="b" ind2="k"><subfield code="a">44.67</subfield><subfield code="j">Kinderheilkunde</subfield><subfield code="q">VZ</subfield></datafield><datafield tag="951" ind1=" " ind2=" "><subfield code="a">AR</subfield></datafield><datafield tag="952" ind1=" " ind2=" "><subfield code="d">101</subfield><subfield code="j">2019</subfield><subfield code="h">265-280</subfield><subfield code="g">16</subfield></datafield></record></collection>
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