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.     

Jurassic source rocks in the Vienna Basin (Austria): Assessment of conventional and unconventional petroleum potential

The Upper Jurassic marlstones (Mikulov Fm.) and marly limestones (Falkenstein Fm.) are the main source rocks for conventional hydrocarbons in the Vienna Basin in Austria. In addition, the Mikulov Formation has been considered a potential shale gas play. In this paper, organic geochemical, petrographical and mineralogical data from both formations in borehole Staatz 1 are used to determine the source potential and its vertical variability. Additional samples from other boreholes are used to evaluate lateral trends. Deltaic sediments (Lower Quarzarenite Member) and prodelta shales (Lower Shale Member) of the Middle Jurassic Gresten Formation have been discussed as secondary sources for hydrocarbons in the Vienna Basin area and are therefore included in the present study.The Falkenstein and Mikulov formations in Staatz 1 contain up to 2.5 wt%TOC. The organic matter is dominated by algal material. Nevertheless, HI values are relative low (<400 mgHC/gTOC), a result of organic matter degradation in a dysoxic environment. Both formations hold a fair to good petroleum potential. Because of its great thickness (∼1500 m), the source potential index of the Upper Jurrasic interval is high (7.5 tHC/m²). Within the oil window, the Falkenstein and Mikulov formations will produce paraffinic-naphtenic-aromatic low wax oil with low sulfur content. Whereas vertical variations are minor, limited data from the deep overmature samples suggest that original TOC contents may have increased basinwards. Based on TOC contents (typically <2.0 wt%) and the very deep position of the maturity cut-off values for shale oil/gas production (∼4000 and 5000 m, respectively), the potential for economic recovery of unconventional petroleum is limited. The Lower Quarzarenite Member of the Middle Jurassic Gresten Formation hosts a moderate oil potential, while the Lower Shale Member is are poor source rock.     

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。     

珠江口盆地惠州凹陷恩平组源岩特征及勘探潜力

惠州凹陷是珠江口盆地已经证实的富生烃凹陷,存在文昌组和恩平组两套有效烃源岩,一直以来都是以文昌组中深湖相烃源岩为勘探重点。随着勘探的深入,惠州地区以恩平组为代表的浅湖-沼泽相烃源岩的贡献越来越明显,惠州凹陷东部新区基本都为浅湖-沼泽相烃源岩供烃,周边井钻探证实该套烃源岩已经成藏。通过构造-结构剖析、物源分析、地震相调研对比、沉积体系细致研究以及对浅湖-沼泽相烃源岩的特征分析,揭示了惠东地区浅湖-沼泽相烃源岩优势发育机理。经过计算,惠东新区浅湖-沼泽相烃源岩资源量为8.6亿t,占到惠东地区总资源量的3/4,具有较大的勘探潜力。在总结惠东新区浅湖-沼泽相烃源岩特征的基础上优选出惠东新区浅湖-沼泽相烃源岩最有利勘探区带。本次研究摆脱了惠州凹陷单一烃源岩勘探束缚,推动了新区勘探进程。     

琼东南盆地深水区中央峡谷黄流组物源特征

物源分析作为岩相-古地理研究的前提和基础,物源体系决定了砂体的展布和储集性能。为明确中央峡谷体系黄流组储集体展布规律及下一步勘探方向,本文应用中央峡谷最新钻井资料,采用重矿物组合、锆石U-Pb测年等分析方法,结合地震反射特征,对中央峡谷黄流组物源体系特征进行分析。地震反射特征表明来自海南隆起和昆嵩隆起物源的三角洲体系,通过二次搬运沉积了陆架斜坡区和盆底的低位海底扇,为中央峡谷的沉积充填提供了充足的粗碎屑沉积物;新钻井黄流组样品中重矿物组合以白钛矿、石榴石、磁铁矿含量较高为主要特征,与莺歌海盆地受蓝江物源影响和琼东南盆地受丽水-秋滨河物源影响的地层重矿物组合相似;锆石U-Pb测年分析表明,中央峡谷黄流组地层中样品年龄图谱具有30~2 000Ma变化范围,与莺歌海盆地受昆嵩隆起物源影响的钻井以及越南现代河流采集的沙样具有非常一致的年龄段和丰度。综上所述,中央峡谷受多物源的影响,越南昆嵩隆起为主的琼东南盆地西部物源体系,是琼东南盆地乐东凹陷晚中新世深水扇以及中央峡谷粗碎屑物质的主要沉积物供给来源区。     

Distribution characteristics of delta reservoirs reshaped by bottom currents: A case study from the second member of the Yinggehai Formation in the DF1-1 gas field,Yinggehai Basin,South China Sea

The Dongfang1-1 gas field (DF1-1) in the Yinggehai Basin is currently the largest offshore self-developed gas field in China and is rich in oil and gas resources. The second member of the Pliocene Yinggehai Formation (YGHF) is the main gas-producing formation and is composed of various sedimentary types; however, a clear understanding of the sedimentary types and development patterns is lacking. Here, typical lithofacies, logging facies and seismic facies types and characteristics of the YGHF are identified based on high-precision 3D seismic data combined with drilling, logging, analysis and testing data. Based on 3D seismic interpretation and attribute analysis, the origin of high-amplitude reflections is clarified, and the main types and evolution characteristics of sedimentary facies are identified. Taking gas formation upper II (IIU) as an example, the plane distribution of the delta front and bottom current channel is determined; finally, a comprehensive sedimentary model of the YGHF second member is established. This second member is a shallowly buried “bright spot” gas reservoir with weak compaction. The velocity of sandstone is slightly lower than that of mudstone, and the reflection has medium amplitude when there is no gas. The velocity of sandstone decreases considerably after gas accumulation, resulting in an increase in the wave impedance difference and high-amplitude (bright spot) reflection between sandstone and mudstone; the range of high amplitudes is consistent with that of gas-bearing traps. The distribution of gas reservoirs is obviously controlled by dome-shaped diapir structural traps, and diapir faults are channels through which natural gas from underlying Miocene source rocks can enter traps. The study area is a delta front deposit developed on a shallow sea shelf. The lithologies of the reservoir are mainly composed of very fine sand and coarse silt, and a variety of sedimentary structural types reflect a shallow sea delta environment; upward thickening funnel type, strong toothed bell type and toothed funnel type logging facies are developed. In total, 4 stages of delta front sand bodies (corresponding to progradational reflection seismic facies) derived from the Red River and Blue River in Vietnam have developed in the second member of the YGHF; these sand bodies are dated to 1.5 Ma and correspond to four gas formations. During sedimentation, many bottom current channels (corresponding to channel fill seismic facies) formed, which interacted with the superposed progradational reflections. When the provenance supply was strong in the northwest, the area was dominated by a large set of delta front deposits. In the period of relative sea level rise, surface bottom currents parallel to the coastline were dominant, and undercutting erosion was obvious, forming multistage superimposed erosion troughs. Three large bottom current channels that developed in the late sedimentary period of gas formation IIU are the most typical.     

陆丰凹陷韩江组旋回地层学分析及天文年代标尺的建立

珠江口盆地为新生代典型的海相盆地,也是我国重要的海上油气生产基地。前期已有很多学者对珠江口盆地的地层划分与对比开展了研究,但研究的精度不够。为了提高珠江口盆地陆丰凹陷韩江组地层划分与对比的精度,选择珠江口盆地陆丰凹陷A、B井韩江组的自然伽马数据序列作为古气候替代性指标,使用频谱分析、滤波等方法进行旋回地层学分析。通过深度域频谱分析和小波分析认为,该套地层中保存了米兰科维奇旋回信号,且主要受405 ka长偏心率周期的影响。利用稳定的405 ka长偏心率周期进行天文调谐,结合古生物地层年代框架,建立起陆丰凹陷“绝对”天文年代标尺;结合碳氧同位素变化曲线,估算出2次碳同位素负漂移和1次碳同位素正向偏移事件的持续时间;利用天文旋回周期计算出陆丰凹陷韩江组的沉积速率,发现沉积速率的变化与海平面变化具有相关性。     

珠江口盆地惠州凹陷迁移型层序特征及其意义

迁移型层序是陆相湖盆中一种特殊的层序构型,但是其特征以及主控因素尚不清楚.通过对珠江口盆地惠州凹陷文昌组层序地层学研究,发现下文昌组三级层序PSQ1~PSQ4主要发育在凹陷南部,上文昌组三级层序PSQ5~PSQ7主要发育在凹陷北部;三级层序PSQ1~PSQ7逐渐由南东向北西发生跨洼陷迁移.这种迁移型层序是由幕式构造活动差异性造成的,在裂陷IA幕,惠州凹陷南部控凹断裂活动强度大,发育以下文昌组为主的T型层序构型;在裂陷IB幕,北部断裂活动加强,南部的断裂活动减弱,造成沉积、沉降中心迁移到惠州凹陷北部,发育以上文昌组为主的H型层序构型.迁移型层序及其控制下的砂体和烃源岩在侧向迁移、叠加过程中,更利于生、储、盖等油气成藏要素的有效配置,形成多区块、多层段油气藏组合.      

四川盆地震旦系灯影组葡萄状白云岩成因

四川盆地震旦系灯影组发育巨厚的白云岩,其中灯影组二段和四段发育大量具有各种形态的葡萄状白云岩,其直径最长可达75cm,有的平行于层面,有的穿层。剖面资料表明,葡萄状白云岩发育多期等厚环边胶结物,中部残留大量未充填的不规则洞穴,这成为与岩溶喀斯特作用相关的地下溶蚀作用的证据。围岩泥晶白云石为早期海水中原生结晶的产物,后来的胶结物可划分为4期: (1)自泥晶化白云石(部分样品中可见)作为最早的一期胶结物,由于各种生物化学作用和生物作用的影响而紧贴着围岩发育;(2)第2期胶结物纤维状白云石可能为海水中直接沉淀的产物,经历后期成岩作用后,具有完全有序的结构,晶胞参数接近理想值;(3)细—中晶白云石为第3期胶结物,包含纤维状白云石溶蚀残余,形成于构造抬升之后的近地表大气淡水环境;(4)第4期胶结物中—粗晶白云石为埋藏环境下直接结晶的产物,充填了孔洞中心,残留部分未充填孔洞。灯影组受到了岩溶喀斯特作用、胶结作用以及白云石化作用等成岩作用的影响,其中与葡萄状白云岩有关的岩溶喀斯特作用对于灯影组储集层的发育至关重要。对灯影组葡萄状白云岩的研究,不仅有助于深入探讨灯影组储集层成因和演化及灯影组白云岩的成因,而且有助于指导四川盆地前寒武系油气勘探。