首页> 外文期刊>Arabian journal of geosciences >Khatatba Formation as an active source rock for hydrocarbons in the northeast Abu Gharadig Basin, north Western Desert, Egypt
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Khatatba Formation as an active source rock for hydrocarbons in the northeast Abu Gharadig Basin, north Western Desert, Egypt

机译:Khatatba组是埃及西北沙漠北部Abu Gharadig盆地东北部烃类的活性烃源岩

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摘要

Rock samples and a suite of oil samples collected from wells drilled in the northeastern part of the Abu Gharadig Basin were studied to determine the petroleum potential of the Middle to Late Jurassic Khatatba Formation as a source rock for oil produced in the basin. Twenty-four cuttings and two cores in addition to three oil samples from the Riviera-1, Swag-2, and Spyglass-1 wells retrieved from the Upper Cretaceous reservoirs were analyzed. Analyses include total organic carbon (TOC), Rock-Eval pyrolysis, and vitrinite reflectance for rock samples and biomarker analyses for liquid hydrocarbons. Results reveal that the Khatatba Formation is an organic-rich source rock with TOC ranging from 1 to 5 wt%, locally exceeding 21 wt% due to the presence of coal interbeds in the depth interval 4,386-4,388 m. Rock-Eval pyrolysis data show that the Khatatba Formation is dominated by algal type II and mixed type II/III kerogens, but type III and type I kerogens also occur. The Khatatba shales and carbonaceous shales have entered the peak-mature stage of the oil generation window. Tmax for the samples ranges from 436 to 449 A degrees C and vitrinite reflectance measurements between 0.76 and 0.92 %Ro. Geochemical analyses reveal that all analyzed oils were generated from thermally mature and organic-rich shale and carbonaceous shale belonging to Middle-Upper Jurassic and Lower Cretaceous source rocks during early and peak stages of the oil window. The correlation between oil samples from NE Abu Gharadig Basin shows that these oils are quite similar and were generated from mixed marine-terrigenous organic matter formed under suboxic-oxic depositional paleoenvironments. However, the differences in bulk and biomarker properties and light-end content of the oil samples can be attributed to thermal maturation, source rock facies variations, or secondary reservoir transformation, such as evaporative fractionation.
机译:研究了从阿布加拉迪格盆地东北部钻探的井中采集的岩石样品和一组石油样品,以确定中侏罗统哈塔特巴组中晚期至晚期的石油潜力,作为该盆地产生的油源岩。除了从上白垩统储层中采集的Riviera-1,Swag-2和Spyglass-1井的三个油样外,还分析了二十四个岩屑和两个岩心。分析包括总有机碳(TOC),岩石评估热解和岩石样品的镜质体反射率,以及液态烃的生物标志物分析。结果表明,Khatatba组是一种富含有机物的烃源岩,TOC范围为1-5%(重量),由于深度为4,386-4,388 m的煤层间存在,局部超过21%(重量)。 Rock-Eval热解数据表明,Khatatba组主要以藻类II型和II / III型混合型干酪根为主,但III型和I型干酪根也存在。 Khatatba页岩和碳质页岩已进入生油窗的成熟期。样品的Tmax在436至449 A范围内,镜质体反射率测量值在0.76%至0.92%Ro之间。地球化学分析表明,所有分析油都是在油窗的早期和高峰期从属于中上侏罗统和下白垩统烃源岩的热成熟且富含有机质的页岩和碳质页岩中产生的。 NE Abu Gharadig盆地的油样之间的相关性表明,这些油非常相似,并且是由在低氧-高氧沉积古环境下形成的混合海陆有机质产生的。但是,油样品的体积和生物标志物特性以及轻质含量的差异可以归因于热成熟,烃源岩相变化或二次储集层转换(例如蒸发分馏)。

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