Geochemical characteristics and origin of gases from the Upper, Lower Paleozoic and the Mesozoic reservoirs in the Ordos Basin, China

Hu, Anping; Li, Jian; Zhang, Wenzheng; Li, Zhisheng; Hou, Lei; Liu, Quanyou

doi:10.1007/s11430-008-5005-1

Cited by 38 publications

(42 citation statements)

References 14 publications

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“…The Upper Paleozoic coal-type gas in the Ordos Basin has been commonly accepted to be derived from the C 3 t-P 1 s coal-measure source rocks [19][20][21][22][23][24][25][26]. Only a set of humic source rocks, that is, the C 3 t-P 1 s coal measures, is developed in the Hangjinqi area in northern Ordos Basin.…”

Section: Source Of Tight Gasmentioning

confidence: 99%

“…The Paleozoic oil-type gas is mainly distributed in the O 1 m carbonate reservoirs, and it is believed to be derived from the O 1 m carbonate rocks [27,29,57] or C 3 t limestone [19,20,58]. The C 3 t limestone is mainly distributed in central Ordos Basin such as the Jingbian area and has been considered to contribute to the Lower Paleozoic gas in the Jingbian gas field; however, the C 3 t limestone is undeveloped in northern Ordos Basin such as the Hangjinqi area [19].…”

Section: Source Of Tight Gasmentioning

confidence: 99%

“…The C 3 t limestone is mainly distributed in central Ordos Basin such as the Jingbian area and has been considered to contribute to the Lower Paleozoic gas in the Jingbian gas field; however, the C 3 t limestone is undeveloped in northern Ordos Basin such as the Hangjinqi area [19]. Although the O 1 m carbonate rocks in the Ordos Basin mainly have not reached the standard of hydrocarbon generation due to the low TOC content [20], they display certain hydrocarbon generation potential; for example, the self-generated and self-reservoired oil-type gas has been discovered in the presalt O 1 m reservoirs in central-eastern Ordos Basin. The presalt O 1 m source rocks display an average TOC content of 0.3% with kerogen type I, and the O 1 m source rocks could generate a certain amount of oil-type gas since the samples with TOC content higher than 0.4% account for 28.2% of the total [59].…”

Section: Source Of Tight Gasmentioning

confidence: 99%

“…Several giant Upper Paleozoic tight gas fields with proven reserves over 100 × 10 9 m 3 have been discovered in the Carboniferous-Permian tight sandstone, for example, Sulige, 2 Geofluids Yulin, Daniudi, Wushenqi, and Zizhou. The Upper Paleozoic natural gas is commonly considered as coal-type gas from the Carboniferous-Permian coal-measure source rocks [19][20][21][22][23][24][25][26]. However, the Lower Paleozoic natural gas was generally believed to be mixed by both coal-type gas from the Upper Paleozoic coal measures and oil-type gas from the marine source rocks [27][28][29].…”

Section: Introductionmentioning

confidence: 99%

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Genetic Types and Source of the Upper Paleozoic Tight Gas in the Hangjinqi Area, Northern Ordos Basin, China

Liu

et al. 2017

Geofluids

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The molecular and stable isotopic compositions of the Upper Paleozoic tight gas in the Hangjinqi area in northern Ordos Basin were investigated to study the geochemical characteristics. The tight gas is mainly wet with the dryness coefficient (C 1 /C 1-5 ) of 0.853-0.951, and 13 C 1 and 2 H-C 1 values are ranging from −36.2‰ to −32.0‰ and from −199‰ to −174‰, respectively, with generally positive carbon and hydrogen isotopic series. Identification of gas origin indicates that tight gas is mainly coal-type gas, and it has been affected by mixing of oil-type gas in the wells from the Shilijiahan and Gongkahan zones adjacent to the Wulanjilinmiao and Borjianghaizi faults. Gas-source correlation indicates that coal-type gas in the Shiguhao zone displays distalsource accumulation. It was mainly derived from the coal-measure source rocks in the Upper Carboniferous Taiyuan Formation (C 3 t) and Lower Permian Shanxi Formation (P 1 s), probably with a minor contribution from P 1 s coal measures from in situ Shiguhao zone. Natural gas in the Shilijiahan and Gongkahan zones mainly displays near-source accumulation. The coal-type gas component was derived from in situ C 3 t-P 1 s source rocks, whereas the oil-type gas component might be derived from the carbonate rocks in the Lower Ordovician Majiagou Formation (O 1 m).

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Section: Source Of Tight Gasmentioning

confidence: 99%

Section: Source Of Tight Gasmentioning

confidence: 99%

Section: Source Of Tight Gasmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

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Genetic Types and Source of the Upper Paleozoic Tight Gas in the Hangjinqi Area, Northern Ordos Basin, China

Liu

et al. 2017

Geofluids

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“…The dryness of coal-type gases in the Upper Palaeozoic is generally higher than 0.95, with an average of 0.97. The heavy hydrocarbon content is generally less than 7%, with an average of 2.46%, which shows that dry gas is the primary content (Li et al, 2003;Dai et al, 2005a;Hu et al, 2007). Most of the C 2 /C 3 ratios are higher than 5.5, with an average of 7, and the C 1 /(C 2 +C 3 ) ratio is higher than 20 (Li et al, 2003;Dai et al, 2005b;Hu et al, 2007).…”

Section: Genesis Types Of Natural Gasmentioning

confidence: 99%

Genesis Types and Sources of Mesozoic Lacustrine Shale Gas in the Southern Ordos Basin, NW China

Wang

Lei

2015

Energy Exploration & Exploitation

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The continental lacustrine-fluvial facies are the main sedimentary environment of the late Triassic Yanchang Formation in the Ordos Basin of China. The 7 th Member and 9 th Member of the Yanchang Formation (Chang 7 and Chang 9 for short) are shale members that contain an abundance of rich organic matter, in which, natural gas has been found. Ascertaining the genetic types and sources of the shale gas is of considerable significance to the evaluation of the exploratory potential and to reduce the exploratory risk in the Yangchang Formation. The analysis of the geochemistry characteristics of the shale gas, shale desorbed gas and dissolved gas of crude oil in the Yanchang Formation, of the study area, has have been performed. The result shows that the three types of gases are dominated by methane and that the dryness is less than 0.92 and ranges from 0.64 to 0.8. The three types of gases in the Triassic Yanchang Formation have similar gas components but are completely different from the gas components in Palaeozoic coal-derived type gas. The δ 13 C 1 values of the shale gas, shale desorbed gas and crude oil dissolved gas vary between -41.6‰ and -51.6‰, and the average value is -47.8‰. The δ 13 C 2 varies between -40.1‰ and -33.6‰, and the δ 13 C 3 is between -38.6‰ and -30.8‰. The shale gas, shale desorbed gas and crude oil dissolved gas are all oil-type pyrolysis gases, which originate from the shale of Chang 7 and Chang 9. The results indicate that all of the gases have components of lighter methane carbon isotopes, which is obviously inconsistent with the low thermal maturity (0.7%≤Ro≤1.3%) of the shale in the study area. The experiments demonstrate that the isotope fractionation during the process of gas adsorption and desorption is the primary cause of the inconsistence.

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Genesis and accumulation of natural gas in the Upper Palaeozoic strata of north‐eastern Ordos Basin, China

et al. 2018

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The north‐eastern Ordos Basin in Central China has become an exploration target in recent years due to the potential of natural gas resources in the Upper Palaeozoic strata. In this study, by analysing the geochemical characteristics of the source rocks and the natural gas, the genesis of the Upper Palaeozoic natural gas was identified. In addition, the accumulation process was discussed by combining studies of hydrocarbon generation and burial/thermal history. The results reveal three sets of source rocks developed in the study area—Carboniferous Benxi (C2b), Permian Taiyuan (P1t), and Shanxi (P1s) formations—consisting of mudstones, carbonaceous mudstones, and coals. The source rocks contain abundant Type III organic matter and have entered mature to high‐mature stage, while source rocks in the south‐eastern part of the study area have entered the overmature stage due to the activity of Zijinshan magmatic rocks. The natural gas has a high content of methane (average 93.99%). The stable carbon isotope of methane (δ13C1) value (average −37.05‰) and that of ethane (δ13C2) value (average −26.4‰) and the composition of the light hydrocarbons reflect the idea that the natural gas is organic in origin, thermogenic, and mainly terrigenous‐sourced. The evolution of a transitional to continental depositional environment of the source rocks results in the variation in the geochemical characteristics of the Upper Palaeozoic gas in the study area. Analysis of fluid inclusions indicates a long and continuous period of natural gas charging in the study area from 165 to 65 Ma. Sandstone bodies close to or interbedded with the source rocks made the gas charging from the source rocks to the reservoirs over a short distance with high efficiency, while faults and fractures provided paths for the gas migrating to reservoirs vertically far from the source rocks. The huge gas generation potential of the source rocks and continuous distribution pattern of sandstone bodies provides favourable conditions for the development of a large‐scale natural gas reservoir.

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Geochemical characteristics and origin of gases from the Upper, Lower Paleozoic and the Mesozoic reservoirs in the Ordos Basin, China

Cited by 38 publications

References 14 publications

Genetic Types and Source of the Upper Paleozoic Tight Gas in the Hangjinqi Area, Northern Ordos Basin, China

Genetic Types and Source of the Upper Paleozoic Tight Gas in the Hangjinqi Area, Northern Ordos Basin, China

Genesis Types and Sources of Mesozoic Lacustrine Shale Gas in the Southern Ordos Basin, NW China

Genesis and accumulation of natural gas in the Upper Palaeozoic strata of north‐eastern Ordos Basin, China

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