桂北泗里口老堡组硅质岩的常量、稀土元素特征及成因指示

桂北泗里口老堡组为一套埃迪卡拉纪—寒武纪过渡时期（大约550～540 Ma）深水盆地沉积的硅质岩。它们的SiO2含量普遍高（平均93.8%）;Al2O3含量为0.17%～4.92%,沿剖面自下而上明显增加,上部超过2%;Al/(Al+Fe+Mn)比值多高于0.42;Fe/Ti比值大都小于16.3;Al2O3/( Al2O3+Fe2O3)比值多高于0.4,剖面上部样品的比值为0.8～0.9;Y/Ho比值为26.4～36.9,中、下部样品较高（多高于32）,上部样品的比值接近地壳值（27）;Eu/Eu*平均值为1.0,正异常不明显。剖面下部样品的∑REE含量低（15.9×10-6～27.1×10-6）,具有与现代海水相近的REE配分,没有正的Eu异常,不同于海底的热液流体和与其有关的碧玉的REE配分;中部样品的∑REE含量为26.2×10-6～49.4×10-6,由于所含陆源碎屑的增加,REE配分变得平坦,但仍有海水REE的某些特征;上部样品的∑REE含量为40.5×10-6～59×10-6,显示与平均页岩相似的平坦的REE配分,但∑REE含量仅为平均页岩的大约1/4～1/3。这些常量和稀土元素特征表明,海底热液和陆源碎屑都不可能成为泗里口老堡组硅质岩的重要物源。埃迪卡拉纪—寒武纪过渡时期华南深水盆地厚层硅质岩沉积反映了这一时期大气高CO2浓度,大量陆源化学风化的硅质流入海洋和大量生物的降解可能是造成这些硅质岩形成的基本原因。     

川南沐川地区宣威组底部铌-稀土多金属富集层富集规律、沉积环境与成矿模式

云南、贵州地区对晚二叠世宣威组底部Nb-REE多金属富集层的研究取得了重要进展,但其成因还有较大争议.为厘清沐川地区宣威组底部Nb-REE多金属富集层成因机制及富集规律,本研究开展了野外实地调查、矿物学、岩相古地理与岩石地球化学等系统性研究,探讨其物源、富集规律,建立了成矿模式.结果 表明,川南沐川地区宣威组底部Nb-...     

准噶尔盆地吉木萨尔凹陷芦草沟组甜点页岩油微观赋存特征及成因机制

准噶尔盆地吉木萨尔页岩油是中国典型的陆相页岩油。通过场发射扫描电镜、激光共聚焦、纳米CT、核磁共振等实验技术联合对微纳米孔隙中页岩油赋存特征进行研究,结果表明甜点储层具有纳米—亚微米—微米全尺度含油特征。在微纳米尺度,油、水赋存特征表现为重质组分油附着于2~5 μm以上孔隙的孔壁及充填于2~5 μm以下的孔隙中,中质组分油赋存于2~5 μm以上孔隙的中央,孔隙水含量较少,呈孤立状赋存于2~5 μm以上孔隙的中央,并被中质组分油包裹。页岩油在微纳米孔隙中的赋存不仅受生烃超压充注控制,还受吸附作用及多期次成藏影响。孔隙表面润湿性由亲水润湿反转为亲油润湿是烃类发生吸附的主要原因,多期次成藏造成微纳米孔隙中油质差异及高的含油饱和度。早期生烃超压充注进储层的重质组分油在孔隙表面亲油润湿下吸附于孔隙表面,随着吸附层变厚,纳米级孔隙逐渐被充满,孔隙水被驱替到较大的孔隙中间;后期成熟的中质组分油以此方式进一步充注和调整。研究认为埋深较大的凹陷西部是有利勘探方向。微纳米孔隙中的重质组分油是未来页岩油提高采收率的方向。吉木萨尔页岩油微观赋存特征及成因机制可能具有普遍性,对于中国陆相页岩油的深入研究具有借鉴意义。     

冀西北侏罗系一个新的地层单位——阳眷组

记述侏罗系一个新的地层单位——阳眷组,用以代表张家口地区下花园组(巴柔期)之下,古老地层(前寒武纪或奥陶纪)之上的沉积。阳眷组以砂岩、泥岩为主,底部有一层粗砂岩夹砾岩、砂砾岩透镜体,不整合于冶里组或雾迷山组之上,顶部有一层稳定的菱铁质鲕粒泥岩与下花园组为界;中、上部多为紫红色或杂色,与上覆的含煤地层差别明显;时代可能属早侏罗世晚期。     

赣东北鹅湖岭组的再认识

在分析赣东北鹅湖岭组及有关地层的地质特征、地层划分现状及产生分岐的原因的基础上,提出以岩性、岩相为划分依据,将鹅湖岭组与喷发相相对应,将其下界、上界分别置于沉积喷发相与喷发相、喷发相与喷发沉积相的相变界面上。从而将北京地质学院指定的打鼓顶组建组剖面上的"打鼓顶组"并入鹅湖岭组;将赣东北其它地区的鹅湖岭组下界由安山岩层顶界处上移至安山岩层之上灰绿色砂岩层的顶界处,将铅山一上饶一带鹅湖岭组上界下移至原鹅湖岭组上部的底界处。     

福建省下二叠统童子岩组风暴沉积特征

本文详细研究了福建省早二叠世童子岩期含煤岩系中风暴沉积的分布层位及沉积相序特征，在此基础上，对童子岩组风暴沉积的古地理环境进行了初步探讨。     

Palynology and petroleum potential of the Kazhdumi Formation (Cretaceous: Albian–Cenomanian) in the South Pars field,northern Persian Gulf

The Kazhdumi Formation of the Bangestan Group is a well-known source rock that has produced abundant oil in most petroleum fields in the Zagros Basin, which stretches from northwest to southwest Iran over hundreds of kilometres. The formation reaches a thickness of 230 m at the type section in northwest Zagros but thins out to 40–50 m in wells studied from the South Pars giant petroleum field, where it comprises mainly grey shales with occasional intercalations of marls and sandstones. South Pars, best known as the Iranian part of the world's largest non-associated gas field, contains small quantities of oil above and below the Kazhdumi Formation.     

下扬子烃源岩新层位——中下奥陶统

中下奥陶统通常主要作为储层看待,然而皖南地区的下奥陶统宁国组主要为一套富含笔石的灰黑色—黑色薄层硅质、碳质泥岩,属广海陆棚相至深海盆地相沉积;而中奥陶统胡乐组主要为一套同样富含笔石的深灰色薄层粉砂质泥岩和中厚层硅质泥岩,属深海陆棚相至盆地相沉积。二者分布范围相当,但宁国组厚度明显大于胡乐组。下奥陶统宁国组6个样品的岩石热解数据显示,恢复后的TOC均值为1.24%。根据上升流的识别标准,宁国组和胡乐组的岩性和岩相特征以及宁国组地球化学测试结果,推测皖南地区中下奥陶统可能是一套受上升流影响的中—好烃源岩。鉴于南黄海是下扬子的主体,建议加强南黄海中下奥陶统烃源岩的研究。     

Marine hydrocarbon source rocks of the Upper Permian Longtan Formation and their contribution to gas accumulation in the northeastern Sichuan Basin,southwest China

Identification of the main hydrocarbon source rocks of the large Puguang gas field (northeastern Sichuan Basin, southwest China) has been the subject of much discussion in recent years. A key aspect has been the lack of a comprehensive understanding of the development of hydrocarbon source rocks of the Upper Permian Longtan Formation, which had been thought to contain mainly coal seams and thick carbonate layers. In this paper, based on geological data from more than ten wells and outcrops and their related mineralogy and geochemistry, we investigated the depositional environment and main factors controlling organic matter enrichment in the Longtan Formation. We propose a model which combines information on the geological environment and biological changes over time. In the model, organic matter from prolific phytoplankton blooms was deposited in quiescent platform interior sags with rising sea-levels. During the Longtan period, the area from Bazhong to Dazhou was a platform interior sag with relatively deep water and a closed environment, which was controlled by multiple factors including syngenetic fault settling, isolation of submarine uplifts and rising sea-levels leading to water column stratification. Although the bottom water was anoxic, the phytoplankton were able to bloom in the well-lit upper euphotic zone thus giving rise to a set of sapropelic black shales and marlstones containing mostly algal organic matter with minor terrestrial contributions. As a consequence, these rocks have a high hydrocarbon generation potentials and can be classified as high-quality source rocks. The area from Bazhong to Dazhou is a center of hydrocarbon generation, being the main source of reservoired paleo-oils and presently discovered as pyrobitumen in the Puguang gas field. The identification of these source rocks is very important to guide future petroleum exploration in the northeastern Sichuan Basin.     

An ichnological-assemblage approach to reservoir heterogeneity assessment in bioturbated strata: Insights from the Lower Cretaceous Viking Formation,Alberta, Canada

Facies-scale trends in porosity and permeability are commonly mapped for reservoir models and flow simulation; however, these trends are too broad to capture bed and bed-set heterogeneity, and there is a need to up-scale detailed, bed-scale observations, especially in low-permeability reservoir intervals. Here we utilize sedimentology and ichnology at the bed- and bedset-scale to constrain the range of porosity and permeability that can be expected within facies of the Lower Cretaceous Viking Formation of south-central, Alberta, Canada.Three main facies were recognized, representing deposition from the middle shoreface to the upper offshore. Amalgamated, hummocky cross-stratified sandstone facies (Facies S_HCS) consist of alternations between intensely bioturbated beds and sparsely bioturbated/laminated beds. Trace fossil assemblages in bioturbated beds of Facies S_HCS are attributable to the archetypal Skolithos Ichnofacies, and are morphologically characterized by vertical, sand-filled shafts (VSS). Bioturbated beds show poor reservoir properties (max: 10% porosity, mean: 85.1 mD) compared to laminated beds (max 20% porosity, mean: 186 mD). Bioturbated muddy sandstone facies (Facies S_B) represent trace fossil assemblages primarily attributable to the proximal expression of the Cruziana Ichnofacies. Four ichnological assemblages occur in varying proportions, namely sediment-churning assemblages (SC), horizontal sand-filled tube assemblages (HSF), VSS assemblages, and mud-filled, lined, or with spreiten (MLS) assemblages. Ichnological assemblages containing horizontal (max: 30% porosity, mean: 1.28 mD) or vertical sand-filled burrows (max: 10% porosity, mean: 2.2 mD) generally have better reservoir properties than laminated beds (max: 20% porosity, mean: 0.98 mD). Conversely, ichnological assemblages that consist of muddy trace fossils have lower porosity and permeability (max 10% porosity, mean: 0.89 mD). Highly bioturbated, sediment churned fabrics have only slightly higher porosity and permeability overall (max: 15% porosity, mean: 1.29 mD). Bioturbated sandy mudstone facies (Facies M_B) contain ichnofossils representing an archetypal expression of the Cruziana Ichnofacies. Four ichnological assemblages occur throughout Facies M_B that are similar to Facies S_B; SC, HSF, VSS, and MLS assemblages. The SC (max: 15% porosity, mean: 21.67 mD), HSF (max: 20% porosity, mean: 3.79 mD), and VSS (max: 25% porosity, mean: 7.35 mD) ichnological assemblages have similar or slightly lower values than the laminated beds (max: 20% porosity, mean: 10.7 mD). However, MLS assemblages have substantially lower reservoir quality (max: 10% porosity, mean: 0.66 mD).Our results indicate that the most likely occurrence of good reservoir characteristics in bioturbated strata exists in sand-filled ichnological assemblages. This is especially true within the muddy upper offshore to lower shoreface, where vertically-oriented trace fossils can interconnect otherwise hydraulically isolated laminated sandstone beds; this improves vertical fluid transmission. The results of this work largely corroborate previous findings about ichnological impacts on reservoir properties. Unlike previous studies, however, we demonstrate that the characteristics of the ichnological assemblage, such as burrow form and the nature of burrow fill, also play an important role in determining reservoir characteristics. It follows that not all bioturbated intervals (attributed to the same facies) should be treated equally. When upscaling bed-scale observations to the reservoir, a range of possible permeability-porosity values can be tested for model sensitivity and to help determine an appropriate representative elementary volume.