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Zengye Xie - One of the best experts on this subject based on the ideXlab platform.
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characteristics of source rocks resource potential and exploration direction of sinian cambrian in sichuan basin china
Natural Gas Geoscience, 2018Co-Authors: Guoqi Wei, Zhihong Wang, Wei Yang, Zengye XieAbstract:Abstract The Anyue giant Gas field was discovered in the Sinian-Cambrian Central Sichuan region of the Sichuan Basin in 2013, with geological reserves up to 1 × 10 12 m 3 , which is the first time for the exploration of Natural Gas paleo-reservoirs in the world. The Gas source studies suggest that the Sinian Natural Gas is originated from the Sinian and Cambrian hydrocarbon source rocks, and the systematical study on the Sinian and Cambrian ancient source rocks has important scientific and practical significance for the global oil and Gas geologic domain of the ancient stratum. Based on the drilling data and field profile observation of Sinian and Cambrian in Sichuan Basin, with adoption of the interpretation data of 28000 km-seismic and new drilling data, combined with geochemical analysis of source rocks of 2315 samples, this paper systematically studied the high quality hydrocarbon source rock center, where the source rocks are mainly distributed along the Mianzhu-Changning craton inner rift, with a accumulative thickness reaching 200–450 m, and 50–100 m for the thickness of source rocks in other areas. The hydrocarbon source rocks of the Sinian-Cambrian contributed about 56 %–63% of Natural Gas Resources of the whole basin. Systematical evaluations have been conducted to the mudstone source rocks and their distribution in the III-section of Sinian Dengying Formation, where TOC value is ranging from 0.04% to 4.73%, with an average of 0.65%. The thickness of the source rocks in Central Sichuan region is ranging from 10 to 30 m. The oldest Sinian source rocks that can form large Gas fields in China were systematically studied for the first time, and the total Gas production intensity of the Sinian source rocks in the great Central Sichuan region is (15–28) × 10 8 m 3 /km 2 , where the Gas source conditions for the formation of large Gas fields are available. By using the genetic method and analogy method, the amount of Natural Gas Resources of the Sinian-Cambrian in the basin are re-evaluated as (4.65–5.58) × 10 12 m 3 , and the Resources potential of Natural Gas is huge. The amount of Natural Gas Resources in the Central Sichuan block accounts for about 66% of the total basin Resources, which is the preferred selection for current exploration.
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Characteristics of source rocks, resource potential and exploration direction of Sinian-Cambrian in Sichuan Basin, China
Elsevier, 2017Co-Authors: Guoqi Wei, Zhihong Wang, Wei Yang, Zengye XieAbstract:The Anyue giant Gas field was discovered in the Sinian-Cambrian Central Sichuan region of the Sichuan Basin in 2013, with geological reserves up to 1 × 1012m3, which is the first time for the exploration of Natural Gas paleo-reservoirs in the world. The Gas source studies suggest that the Sinian Natural Gas is originated from the Sinian and Cambrian hydrocarbon source rocks, and the systematical study on the Sinian and Cambrian ancient source rocks has important scientific and practical significance for the global oil and Gas geologic domain of the ancient stratum. Based on the drilling data and field profile observation of Sinian and Cambrian in Sichuan Basin, with adoption of the interpretation data of 28000 km-seismic and new drilling data, combined with geochemical analysis of source rocks of 2315 samples, this paper systematically studied the high quality hydrocarbon source rock center, where the source rocks are mainly distributed along the Mianzhu-Changning craton inner rift, with a accumulative thickness reaching 200–450 m, and 50–100 m for the thickness of source rocks in other areas. The hydrocarbon source rocks of the Sinian-Cambrian contributed about 56 %–63% of Natural Gas Resources of the whole basin. Systematical evaluations have been conducted to the mudstone source rocks and their distribution in the III-section of Sinian Dengying Formation, where TOC value is ranging from 0.04% to 4.73%, with an average of 0.65%. The thickness of the source rocks in Central Sichuan region is ranging from 10 to 30 m. The oldest Sinian source rocks that can form large Gas fields in China were systematically studied for the first time, and the total Gas production intensity of the Sinian source rocks in the great Central Sichuan region is (15–28) × 108 m3/km2, where the Gas source conditions for the formation of large Gas fields are available. By using the genetic method and analogy method, the amount of Natural Gas Resources of the Sinian-Cambrian in the basin are re-evaluated as (4.65–5.58) × 1012 m3, and the Resources potential of Natural Gas is huge. The amount of Natural Gas Resources in the Central Sichuan block accounts for about 66% of the total basin Resources, which is the preferred selection for current exploration. Keywords: Source rocks, Resource potential, Sinian, Cambrian, Sichuan Basi
Jinxing Dai - One of the best experts on this subject based on the ideXlab platform.
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stable carbon isotope compositions and source rock geochemistry of the giant Gas accumulations in the ordos basin china
Organic Geochemistry, 2005Co-Authors: Jinxing Dai, Xia Luo, Wenzheng Zhang, Jianmin GuoAbstract:Ordos Basin, the second largest sedimentary basin in China, contains enormous Natural Gas Resources. Each of the four giant Gas fields discovered so far in this basin (i.e., Sulige, Yulin, Wushenqi and Jingbian) has over 100 billion cubic meters (bcm) or 3.53 trillion cubic feet (tcf) of proven Gas reserves. This study examines the stable carbon isotope data of 125 Gas samples collected from the four giant Gas fields in the Ordos Basin. Source rocks in the Upper Paleozoic coal measures are suggested by the generally high δ13C values of C1–C4 Gaseous hydrocarbons in the Gases from the Sulige, Yulin and Wushenqi Gas fields. While the δ13CiC4 value is higher than that of the δ13CnC4, the dominant ranges for the δ13C1, δ13C2, and δ13C3 values in these Upper Paleozoic reservoired Gases are −34 to −32‰, −27 to −23‰, and −25 to −24‰, respectively. The δ13C values of methane, benzene and toluene in Gases from the Lower Paleozoic reservoirs of the Jingbian field indicate a significant contribution from humic source rocks, as they are similar to those in the Upper Paleozoic reservoirs of the Sulige, Yulin and Wushenqi Gas fields. However, the wide variation and reversal in the δ13C1, δ13C2 and δ13C3 values in the Jinbian Gases cannot be explained using a single source scenario, thus the Gases were likely derived dominantly from the Carboniferous-Permian coal measures with some contribution from the carbonates in the Lower Permian Taiyuan Formation. The Gas isotope data and extremely low total organic carbon contents (<0.2% TOC) suggest that the Ordovician Majiagou Formation carbonates are unlikely to be a significant Gas source rock, thus almost all of the economic Gas accumulations in the Ordos Basin were derived from Upper Paleozoic source rocks.
Ningsheng Chen - One of the best experts on this subject based on the ideXlab platform.
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china s conventional and unconventional Natural Gas Resources potential and exploration targets
Natural Gas Geoscience, 2018Co-Authors: Min Zheng, Shejiao Wang, Qiulin Guo, Man Zheng, Ningsheng ChenAbstract:Abstract A series of significant breakthroughs in exploring conventional and unconventional Natural Gas Resources have been achieved in new strata and new domains. However, the quality of the increased reserves has declined with the entry of unconventional Resources into the reserves sequence. Therefore, the potential of conventional and unconventional Natural Gas Resources as well as important exploration regions of the remaining Natural Gas Resources need to be clarified, and favorable directions need to be established. On the basis of oil and Gas exploration results, discoveries in petroleum geology, and exploration data of the past 10 years acquired by PetroChina, an entire system of resource assessment for conventional and unconventional oil and Gas Resources has been established. The fourth round of resource assessment has been systematically executed. The results indicate that the total conventional Natural Gas Resources of China are 78 × 1012 m3, which shows an increase of 8 × 1012 m3 over the results of the third round of resource assessment. Unconventional Resources include four types of Resources: tight Gas, shale Gas, coalbed methane, and Natural Gas hydrates. Among them, tight Gas reservoirs make up 21.86 × 1012 m3 (Jiyang, Dongpu, Nanxiang, Subei, and others were excluded from the assessed regions). In addition, shale Gas, coalbed methane, and Natural Gas hydrate reservoirs make up 80.21 × 1012 m3, 29.82 × 1012 m3, and 153.06 × 1012 m3, respectively. The remaining Resources for onshore conventional Natural Gas are distributed mainly in four significant domains, which are lithology–strata (clastic rock), marine carbonatites, foreland thrust belts, and complex tectonic belts. Of these, marine carbonatites and foreland thrust belts are the dominant domains. The Resources for offshore Natural Gas are concentrated mainly in three domains, which are offshore structures, organic reefs, and lithology in deep water. The total remaining Natural Gas Resources in marine carbonatites, foreland, lithology–strata, complex tectonic belts, and the South China Sea amount to 59.83 × 1012 m3, which is 94% of the remaining Natural Gas Resources in China. Based on this assessment, favorable targets are selected including 10 targets for conventional Resources, 4 for tight Gas, 4 for coalbed methane, and 6 for shale Gas.
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China's conventional and unconventional Natural Gas Resources: Potential and exploration targets
Elsevier, 2018Co-Authors: Min Zheng, Shejiao Wang, Qiulin Guo, Man Zheng, Ningsheng ChenAbstract:A series of significant breakthroughs in exploring conventional and unconventional Natural Gas Resources have been achieved in new strata and new domains. However, the quality of the increased reserves has declined with the entry of unconventional Resources into the reserves sequence. Therefore, the potential of conventional and unconventional Natural Gas Resources as well as important exploration regions of the remaining Natural Gas Resources need to be clarified, and favorable directions need to be established. On the basis of oil and Gas exploration results, discoveries in petroleum geology, and exploration data of the past 10 years acquired by PetroChina, an entire system of resource assessment for conventional and unconventional oil and Gas Resources has been established. The fourth round of resource assessment has been systematically executed. The results indicate that the total conventional Natural Gas Resources of China are 78 × 1012 m3, which shows an increase of 8 × 1012 m3 over the results of the third round of resource assessment. Unconventional Resources include four types of Resources: tight Gas, shale Gas, coalbed methane, and Natural Gas hydrates. Among them, tight Gas reservoirs make up 21.86 × 1012 m3 (Jiyang, Dongpu, Nanxiang, Subei, and others were excluded from the assessed regions). In addition, shale Gas, coalbed methane, and Natural Gas hydrate reservoirs make up 80.21 × 1012 m3, 29.82 × 1012 m3, and 153.06 × 1012 m3, respectively. The remaining Resources for onshore conventional Natural Gas are distributed mainly in four significant domains, which are lithology–strata (clastic rock), marine carbonatites, foreland thrust belts, and complex tectonic belts. Of these, marine carbonatites and foreland thrust belts are the dominant domains. The Resources for offshore Natural Gas are concentrated mainly in three domains, which are offshore structures, organic reefs, and lithology in deep water. The total remaining Natural Gas Resources in marine carbonatites, foreland, lithology–strata, complex tectonic belts, and the South China Sea amount to 59.83 × 1012 m3, which is 94% of the remaining Natural Gas Resources in China. Based on this assessment, favorable targets are selected including 10 targets for conventional Resources, 4 for tight Gas, 4 for coalbed methane, and 6 for shale Gas. Keywords: Resources assessment, Resources potential of Natural Gas, Remaining Resources potential of Natural Gas, Resources distribution, Major exploration region, Favorable target zon
Lei Jiang - One of the best experts on this subject based on the ideXlab platform.
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diagenesis and its impact on a microbially derived carbonate reservoir from the middle triassic leikoupo formation sichuan basin china
AAPG Bulletin, 2018Co-Authors: Lei Jiang, Zhaohui Xu, Suyun Hu, Wenzhi Zhao, Qilong Fu, Hongliu Zeng, Andras FallAbstract:The uppermost Middle Triassic Leikoupo Formation in the western Sichuan Basin of China has recently been shown to host as much as 5.3 tcf (1.5 × 1012 m3) of Natural Gas Resources. The reservoir rocks, composed mainly of microbially derived dolomudstone (e.g., thrombolites and stromatolites), are characterized by low porosity (<8%) and permeability (<0.001 to 10 md). The limestone is commonly tight and not of reservoir quality because of abundant meteoric calcite cementation, whereas the dolostone has various types of pores dominated by solution-enlarged pores and vugs, microbial framework pores, and micropores. Breccias are well developed in places, probably because of dissolution of underlying evaporites (e.g., anhydrite) by an influx of low-salinity fluids (e.g., freshwater and seawater) during an early burial stage. Early dolomitization created micropores in the dolomudstone, and subsequent diagenetic events were dominated by calcite, dolomite, quartz cementation, pyrite replacement, compaction, fracturing, and development of stylolites. Localized hydrothermal activity has been evidenced by high homogenization temperatures (∼160°C–200°C) obtained from fluid inclusions in fracture-filling cements. Bacterial sulfate reduction probably resulted in H2S generation, pyrite precipitation, and solution-enlarged pore and vug formation, whereas part of the current H2S in these reservoirs may have been sourced from thermochemical sulfate reduction or an underlying formation (e.g., the Feixiangguan Formation). Development of microfractures and associated micropores was probably the final diagenetic event, which improved pore interconnectivity. This study confirms the effect of diagenesis on the development of a microbial dolomudstone reservoir, which may be applicable to other similar microbial carbonate reservoirs elsewhere, for example, Middle Triassic sections of the Tethys region and offshore Brazil.
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contrasting diagenetic evolution patterns of platform margin limestones and dolostones in the lower triassic feixianguan formation sichuan basin china
Marine and Petroleum Geology, 2017Co-Authors: An Jiang Shen, Richard H Worden, Lei Jiang, Xun Yue HeAbstract:Abstract Deeply-buried carbonate-reservoirs from the Lower Triassic Feixianguan Formation in the Sichuan Basin of China host extensive Natural Gas Resources. These reservoirs are predominantly found in oolitic shoals, with the reservoir quality of dolomitized zones being higher than that of undolomitized limestone counterparts. Here we present a combination of petrographic, isotopic, fluid inclusion, and quantitative porosity data in order to understand and predict the diagenetic processes that have impacted the reservoir quality of dolostones and limestones. The porosity of limestones has been reduced to ∼7.5% due to calcite cementation, whereas the porosity in oolitic dolostones is not cemented with calcite and typically has ∼23.5% porosity. Dolomitization and concurrent early-diagenetic gypsum growth played crucial roles on the development and preservation of high porosity in the oolitic dolostone, first by stabilizing the rock fabric to inhibit loss of porosity during burial, and secondly through the generation of new porosity by dissolution of carbonate and anhydrite. A negative shift of δ 18 O and salinity values ( 13 C values (∼−20‰ VPDB) and δ 18 O (∼−10‰ VPDB) together with elevated calcite precipitation temperatures (>110 °C). It is likely that TSR was responsible for the formation of enlarged dissolution vugs that increased porosity by ∼2% in dolostones due to: i) anhydrite dissolution, ii) production of significant amounts of water resulting in formation water undersaturated with respect to calcite and dolomite, iii) generation of H 2 S, and CO 2 , and the consequent reaction of H 2 S with the siderite (FeCO 3 ) component in calcite and dolomite. This study demonstrates the importance of diagenesis in the formation of deeply-buried, high-quality reservoirs in ooid-dominated grainstones influenced by the presence of evaporites. Our results should be useful for guiding future exploration and reservoir developments in similar paleogeographic and diagenetic settings.
Guoqi Wei - One of the best experts on this subject based on the ideXlab platform.
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characteristics of source rocks resource potential and exploration direction of sinian cambrian in sichuan basin china
Natural Gas Geoscience, 2018Co-Authors: Guoqi Wei, Zhihong Wang, Wei Yang, Zengye XieAbstract:Abstract The Anyue giant Gas field was discovered in the Sinian-Cambrian Central Sichuan region of the Sichuan Basin in 2013, with geological reserves up to 1 × 10 12 m 3 , which is the first time for the exploration of Natural Gas paleo-reservoirs in the world. The Gas source studies suggest that the Sinian Natural Gas is originated from the Sinian and Cambrian hydrocarbon source rocks, and the systematical study on the Sinian and Cambrian ancient source rocks has important scientific and practical significance for the global oil and Gas geologic domain of the ancient stratum. Based on the drilling data and field profile observation of Sinian and Cambrian in Sichuan Basin, with adoption of the interpretation data of 28000 km-seismic and new drilling data, combined with geochemical analysis of source rocks of 2315 samples, this paper systematically studied the high quality hydrocarbon source rock center, where the source rocks are mainly distributed along the Mianzhu-Changning craton inner rift, with a accumulative thickness reaching 200–450 m, and 50–100 m for the thickness of source rocks in other areas. The hydrocarbon source rocks of the Sinian-Cambrian contributed about 56 %–63% of Natural Gas Resources of the whole basin. Systematical evaluations have been conducted to the mudstone source rocks and their distribution in the III-section of Sinian Dengying Formation, where TOC value is ranging from 0.04% to 4.73%, with an average of 0.65%. The thickness of the source rocks in Central Sichuan region is ranging from 10 to 30 m. The oldest Sinian source rocks that can form large Gas fields in China were systematically studied for the first time, and the total Gas production intensity of the Sinian source rocks in the great Central Sichuan region is (15–28) × 10 8 m 3 /km 2 , where the Gas source conditions for the formation of large Gas fields are available. By using the genetic method and analogy method, the amount of Natural Gas Resources of the Sinian-Cambrian in the basin are re-evaluated as (4.65–5.58) × 10 12 m 3 , and the Resources potential of Natural Gas is huge. The amount of Natural Gas Resources in the Central Sichuan block accounts for about 66% of the total basin Resources, which is the preferred selection for current exploration.
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Characteristics of source rocks, resource potential and exploration direction of Sinian-Cambrian in Sichuan Basin, China
Elsevier, 2017Co-Authors: Guoqi Wei, Zhihong Wang, Wei Yang, Zengye XieAbstract:The Anyue giant Gas field was discovered in the Sinian-Cambrian Central Sichuan region of the Sichuan Basin in 2013, with geological reserves up to 1 × 1012m3, which is the first time for the exploration of Natural Gas paleo-reservoirs in the world. The Gas source studies suggest that the Sinian Natural Gas is originated from the Sinian and Cambrian hydrocarbon source rocks, and the systematical study on the Sinian and Cambrian ancient source rocks has important scientific and practical significance for the global oil and Gas geologic domain of the ancient stratum. Based on the drilling data and field profile observation of Sinian and Cambrian in Sichuan Basin, with adoption of the interpretation data of 28000 km-seismic and new drilling data, combined with geochemical analysis of source rocks of 2315 samples, this paper systematically studied the high quality hydrocarbon source rock center, where the source rocks are mainly distributed along the Mianzhu-Changning craton inner rift, with a accumulative thickness reaching 200–450 m, and 50–100 m for the thickness of source rocks in other areas. The hydrocarbon source rocks of the Sinian-Cambrian contributed about 56 %–63% of Natural Gas Resources of the whole basin. Systematical evaluations have been conducted to the mudstone source rocks and their distribution in the III-section of Sinian Dengying Formation, where TOC value is ranging from 0.04% to 4.73%, with an average of 0.65%. The thickness of the source rocks in Central Sichuan region is ranging from 10 to 30 m. The oldest Sinian source rocks that can form large Gas fields in China were systematically studied for the first time, and the total Gas production intensity of the Sinian source rocks in the great Central Sichuan region is (15–28) × 108 m3/km2, where the Gas source conditions for the formation of large Gas fields are available. By using the genetic method and analogy method, the amount of Natural Gas Resources of the Sinian-Cambrian in the basin are re-evaluated as (4.65–5.58) × 1012 m3, and the Resources potential of Natural Gas is huge. The amount of Natural Gas Resources in the Central Sichuan block accounts for about 66% of the total basin Resources, which is the preferred selection for current exploration. Keywords: Source rocks, Resource potential, Sinian, Cambrian, Sichuan Basi
