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Chris Sladen - One of the best experts on this subject based on the ideXlab platform.
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Seepage in Vietnam — onshore and offshore examples
Marine and Petroleum Geology, 1997Co-Authors: J.j. Traynor, Chris SladenAbstract:Abstract Hydrocarbon seepages in Vietnam are generally linked to migration from Tertiary Source rocks, and seeps are present both onshore and offshore. Residual oil can be observed at outcrop in breached traps within Tertiary sections and in exhumed ‘buried hill’ traps in pre-Tertiary rocks in the onshore Hanoi Basin. There is active oil seepage on the western margin of the offshore Phu Khanh Basin through fractured granites that outcrop at the basin margin. There are examples of onshore gas seepages in southern Vietnam. These are predominantly non-hydrocarbon, mantle-derived gases, sometimes mixed with biogenic methane, and are seeping via hot springs from fractured Mezosoic igneous rocks in active fault zones. Offshore, in the Nam Con Son Basin, sonar, seismic data and sea bed cores show a variety of seepage features, including shallow gas anomalies, mounds and pockmarks on the sea bed, and gas effects in the water column sometimes visible on sonar records. However, sea bed seepage features are not particularly common, and have a low preservation potential in the area due to powerful sea bed currents. Aircraft surveys of the sea surface have revealed several oil slicks that could be related to active oil seepages in the Nam Con Son Basin. Seepage appears to be occurring in Vietnam at two fundamentally different rates. ‘Background’ seepages flow at low rates, typically tens to thousands of cubic feet per day of gas, and up to tens of barrels per day of oil. These seeps flow episodically for extended periods of months or years, and leading to the formation of sea bed mounds. Higher flow rate eruptive seepages may have formed some of the pockmarks, and have a far shorter duration, probably only a few hours or days, with flow rates of millions of cubic feet per day of gas and any associated liquids.
Peng De-hua - One of the best experts on this subject based on the ideXlab platform.
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Geochemical Characteristics of Tertiary Source Rocks in the South Area of Western Qaidam Basin
Natural Gas Geoscience, 2008Co-Authors: Peng De-huaAbstract:Based on analyses of Source rocks in the Tertiary system in the south area of the western Qaidam basin,the low limit value of TOC is fixed on 0.4%.On this basis,the upper part of Xiagancaigou Formation(E23) and the lower part of Xiagancaigou Formation(E13) in the Hongshi sag,Zhahaquan sag and Shizigou zone are considered as effective Source rocks.By the biomarkers analyses of 24 effective Source rocks,we examined the sediment characteristics of the saline lacustrine environment to investigate the Geochemical characteristics.The results show: the Tertiary Source rocks in the area are characterized by even over odd preference of n-Alkanes,Pr/Ph0.6 and high abundance of gammaceranes and C35 homohopanes,but these characteristics are different in all sags or zones.Different values of Pr/Ph,C35 homohopane/C34 homohopane and gammacerane /C30 hopane reveal that the sediment environment of Tertiary Source rocks in the Hongshi sag,Yuejing zone and Shizigou zone is a high-saline lacustrine and strong reduction environment and that of Shizigou zone is relatively inferior,while that of Zhahaquan sag is a low-saline lacustrine and low reduction environment.The two types of oils in the south area of the western Qaidam basin,further,two independent hydrocarbon systems may be indicated by the two patterns of Tertiary Source rocks in the same area.
Gary A Cole - One of the best experts on this subject based on the ideXlab platform.
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identification of organic rich lower Tertiary shales as petroleum Source rocks south louisiana
AAPG Bulletin, 1993Co-Authors: Elizabeth Chinn Mcdade, Roger Sassen, Lloyd M Wenger, Gary A ColeAbstract:ABSTRACT Comprehensive organic geochemical evidence of organic-rich, marine shales in the lower part of the middle Eocene Claiborne Group and the lower Eocene-Paleocene Wilcox Group of south Louisiana is now available that influences models for Gulf Coast petroleum origin. The shales are the only post-Cretaceous age sediments in the northern Gulf of Mexico that meet recognized criteria for oil Source rocks. Many organic-rich Paleogene shales contain terrestrially derived, amorphous kerogen altered by microbial activity, and display pyrolysis results consistent with Type II/III kerogen. Shelf-edge depositional environments favor preservation of hydrogen-rich kerogen. Seismic and sedimentologic interpretations suggest that marine character and thickness increase on the Paleogene continental slope to the south. The shales at burial depths in the 3050-4600 m depth range are at present thermally immature to late mature with respect to oil generation. Detailed geochemical analysis of extractable organic matter and kerogen isolates suggest an oil-Source correlation with Tertiary-reservoired oils in south Louisiana and offshore in the adjacent Gulf of Mexico. Biomarkers of selected samples display high concentrations of C28-bisnorhopane and 18-oleanane that are also found in Tertiary-reservoired oils. The key 18-oleanane biomarker is absent or not reported in Gulf crude oils from Cretaceous and Jurassic Source rocks. Burial and thermal history models suggest the timing of oil migration from Paleogene Source rocks is consistent with emplacement of oils in Tertiary reservoirs. The lower Tertiary Source rocks described here could offer new insight to understanding the origin of oil in other Tertiary deltas.
Zhang Min - One of the best experts on this subject based on the ideXlab platform.
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Geochemical Research in LC 1 Well of Tertiary Source Rocks in the South Area of Western Qaidam Basin
Natural Gas Geoscience, 2009Co-Authors: Zhang MinAbstract:By using the analytical techniques of GC/MS,geochemical characteristics in LC 1 well of Source rocks in the south area of western Qaidam basin are analyzed.The analyses of TOC,hydrocarbon generating potential,and types of organic matter and maturity reveal that:in N21 segment,the Source rock is common in quality;in the segments of E23—E13,the Source rock is high quality;the distribution characteristics of n-alkanes from the Source rocks change largely,there are single peak and double peak;there are obvious phytane advantages,and the abundance of gammacerane is high as a whole except that some segments have low abundance of gammacerane,indicating a strong reducing environment of deposition.
J.j. Traynor - One of the best experts on this subject based on the ideXlab platform.
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Seepage in Vietnam — onshore and offshore examples
Marine and Petroleum Geology, 1997Co-Authors: J.j. Traynor, Chris SladenAbstract:Abstract Hydrocarbon seepages in Vietnam are generally linked to migration from Tertiary Source rocks, and seeps are present both onshore and offshore. Residual oil can be observed at outcrop in breached traps within Tertiary sections and in exhumed ‘buried hill’ traps in pre-Tertiary rocks in the onshore Hanoi Basin. There is active oil seepage on the western margin of the offshore Phu Khanh Basin through fractured granites that outcrop at the basin margin. There are examples of onshore gas seepages in southern Vietnam. These are predominantly non-hydrocarbon, mantle-derived gases, sometimes mixed with biogenic methane, and are seeping via hot springs from fractured Mezosoic igneous rocks in active fault zones. Offshore, in the Nam Con Son Basin, sonar, seismic data and sea bed cores show a variety of seepage features, including shallow gas anomalies, mounds and pockmarks on the sea bed, and gas effects in the water column sometimes visible on sonar records. However, sea bed seepage features are not particularly common, and have a low preservation potential in the area due to powerful sea bed currents. Aircraft surveys of the sea surface have revealed several oil slicks that could be related to active oil seepages in the Nam Con Son Basin. Seepage appears to be occurring in Vietnam at two fundamentally different rates. ‘Background’ seepages flow at low rates, typically tens to thousands of cubic feet per day of gas, and up to tens of barrels per day of oil. These seeps flow episodically for extended periods of months or years, and leading to the formation of sea bed mounds. Higher flow rate eruptive seepages may have formed some of the pockmarks, and have a far shorter duration, probably only a few hours or days, with flow rates of millions of cubic feet per day of gas and any associated liquids.