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1.
Fractured reservoirs are of prime interest as fracture networks control most of the fluid flow and/or accumulation. However, characterizing 3D fracture patterns from subsurface data remains challenging. Studying fractures on outcrops is a good substitution to 1D data from subsurface exploration tools. In addition, outcrops allow deciphering the nature, origin and conditions for fracture formation through the geodynamic history. In this paper, we aim at characterizing the true 3D fracture patterns and determining the genetic role of facies, diagenesis and rock physical properties. We targeted a platform–slope transect within a carbonate reservoir analog, the Maiella Mountain in central Italy, where implications for analog hydrocarbon reservoir can be discussed.Fracture patterns are sorted based on geometric and kinematic criteria from field measurements and petrographic analyzes on thin-sections. Sedimentary facies, pore types and rock physical properties have been characterized in order to establish the impact of early diagenesis on rock evolution. Diagenetic sequences have been unraveled and correlated to the fractures. Fracture sequences have been determined considering the cross-cutting relationships and compared with burial–uplift history. In the two studied formations (platform and slope carbonates), we interpret a stage of fracturing perpendicular to bedding, formed at shallow depth and occurring prior to major regional tectonic events. The studied carbonates have undergone early diagenesis during fast and shallow burial, conferring early brittle behavior. The amount of stylolites is not correlated to burial depth but to fracture density, porosity and free air P–wave velocity. It means that fracture development, mechanical and petrophysical properties are acquired during early diagenesis.Both studied formations have undergone the same geodynamic history and their brittle response is different and not related to folding but to burial and early cementation. Deciphering the close relationship between sedimentary facies, diagenetic and geodynamic history has allowed unraveling the controling factors on rock properties and therefore on fracture pattern. 相似文献
2.
The results of identification of facies and microfacies of highstand systems tract (HST) deposits in the Zechstein Main Dolomite (Ca2) are presented followed by a critical analysis of the existing views on the paleogeography and facies architecture of the Wielkopolska Platform (eastern part of the Fore-Sudetic Monocline, SW Poland). The authors discuss and question, the existence in zones that have been treated as basinal flat in the analysed area, and an extensive platform margin ooidal barrier. In general, the facies architecture of the study area resembles the block built of the Paleozoic basement.On this background analytical geochemical results are presented and their source nature characterized in the context of a new revised model of the Ca2 basin paleogeography. A new facies classification of carbonates, which has not been applied for the Polish part of the Ca2 basin yet, was presented. The geochemical characteristic of Ca2 rocks indicates that good oil-prone source rocks are present only locally and are connected with calcisiltites and dolomudstones of facies II and dolobindstones of facies IV. These facies are mainly present in the slope and toe-of-slope zones. The microbial-algal facies, abundant in the carbonate platform, have a weaker residual potential. However, the thermal maturity stays within the entire range of the “oil window”, the rocks should be re-labeled as good source rocks. The presence of oil-prone kerogen Type II, and locally even Type I, makes the Ca2 beds in this part of the Wielkopolska Platform a very efficient source rock, the character of which is confirmed by numerous hydrocarbon accumulations, related to the course of tectonic zones and morphology of the basement. The proposed characteristic of source rocks in the new paleogeographic-facies system, enables their better petroleum evaluation and shall enable future prospecting of the perspective zones. 相似文献
3.
Faults and their associated damage zones in sedimentary basins can be sealing, impeding fluid flow and creating permeability barriers, or open, creating fluid pathways. This impacts the reservoir potential of rocks in fault damage zones. Stylolitization and fracturing severely impacted permeability through compartmentalization and cementation of Apium-1, an exploration hole drilled in the northern Perth Basin, Western Australia. Apium-1 is located 1 km into the hanging wall block damage zone of a major NNW-trending normal fault. The drill core consists of fine- to medium-grained quartz arenite overlain by a coarse-grained lag and capped by impermeable shale. It was quantitatively characterized by sedimentary and structural logging, and microstructural and porosity-permeability analysis. Fractures and stylolites in the damage zone of the major fault are shown to have been sealed. Extensional cracks have been sealed by quartz precipitation; shear fractures that locally preserve brecciation are always quartz and siderite cemented; stylolites are common and contain halos of quartz cementation. In each case, porosity was reduced to approximately 1%, with concomitant reduction of permeability to <<0.01 mD. These structures are observed to be interconnected in the core and are likely to form a larger-scale 3D network of steeply-dipping fractures and shallowly-dipping stylolites. The bulk permeability of the damage zone would reflect the permeability of the fractures and stylolites, compartmentalizing the Mesozoic rocks in the northern Perth Basin into elongate NW-SE trending blocks if the magnitude of stress does not exceed the cemented rock strength. 相似文献
4.
The Upper Cretaceous carbonates cropping out in the Murge Plateau are good analogues of the fractured and faulted carbonate oil reservoirs of southern Italy. For this reason, a detailed field analysis focused on structural architecture of fault and fracture networks has been carried out in the Murge Plateau. The well-bedded carbonates exposed there are crosscut by a set of bed-parallel stylolites and two sets of bed-perpendicular cross-orthogonal joints/veins. These structural elements were likely formed under vertical loading during burial diagenesis and flexure of the Apulian foreland of the Southern Apennines fold-and-thrust belt. Bed-parallel stylolites and bed-perpendicular cross-orthogonal joints/veins represent the background deformation that was overprinted by the fault-related localized deformation. The fault sets documented in the study area are arranged in two kinematically-compatible fault networks. The first one is made up of WNW-ESE and NNW-SSE oriented strike-slip faults, right- and left-lateral, respectively, and NW–SE oriented normal faults. The second fault network consists of WNW-ESE oriented left-lateral strike-slip faults, and NE–SW oriented normal faults.First, both architecture and dimensional parameters of the fault and fracture networks have been characterized and computed by means of statistical analysis. Then, the permeability structures associated to the aforementioned networks have been assessed in order to determine the role exerted by fault architecture and dissolution/cementation processes on the fluid storage and migration pathways within the studied platform carbonates. Network 1 faults show a quite variable fluid behavior, in which the fluid flow is strongly affected by inherited structural elements and karst dissolution, whereas network 2 faults show a more uniform, fluid conduit behavior. 相似文献
5.
The largest condensate field of the Ordovician reef-shoal reservoirs, in China, was discovered along the N°1 fault zone in the Tarim Basin. However, current drilling activities are hindered by the low and unstable production from these carbonate reservoirs. A detailed structural analysis of 3-D seismic data identified three segments along the N°1 fault zone characterized by differences in structural geometry and evolution. Segmentation of the N°1 fault zone has resulted in the variation of characteristics and distribution of the Upper Ordovician carbonate reservoirs. Due to fault induced differential uplift before the Late Ordovician, a narrow and thick-rimmed platform margin rich in reefs has developed in the eastern segment, whereas wider and thinner shoals developed in the central and western segments. We clearly identified a fault block uplift related erosional unconformity, and associated karstification at the top of the Upper Ordovician carbonates in the eastern segment. In this segment, the karst caves resulted in the high and stable hydrocarbon production. In the central segment, good matrix reservoirs exist, but due to the lack of fault-related enhancement of the reservoirs quality, only relatively low production is observed. In the western segment, where fracture-vug reservoirs occurred in relation to later fault damage zones, production is much greater but unstable. Large-scale fracture-caves reservoirs related to fault activity, rather than the good unfaulted matrix reservoirs, lead to the high production of oil and gas. We classify these reef-shoal reservoirs as faulting modified reservoirs. Further exploitation should focus more on the fault damage zone beyond the platform margin rather than the microfacies in the Lower Paleozoic carbonates. 相似文献
6.
Christian Tueckmantel Quentin J. Fisher Carlos A. Grattoni Andrew C. Aplin 《Marine and Petroleum Geology》2012,29(1):129-142
Understanding the impact of faults on fluid flow in the subsurface is important for the extraction of oil, gas and groundwater as well as the geological storage of waste products. We address two problems present in current industry-standard workflows for fault seal analysis that may lead to fault rocks not being represented adequately in computational fluid flow models. Firstly, fluid flow properties of fault rocks are often measured only for small-scale faults with throws not exceeding a few centimetres. Large seismic-scale faults (throws >20 m) are likely to act as baffles or conduits to flow but they are seldom recovered from subsurface cores and consequently fault rock data for them is sparse. Secondly, experimental two-phase fluid flow data is lacking for fault rocks and, consequently, uncertainties exist when modelling flow across faults in the presence of two or more immiscible phases. We present a data set encompassing both single- and two-phase fluid flow properties of fault and host rocks from the 90-Fathom fault and its damage zone at Cullercoats Bay, NE England. Measurements were made on low-throw single and zones of deformation bands as well as on slip-surface cataclasites present along the ～120 m throw main fault. Samples were analysed using SEM and X-ray tomography prior to petrophysical measurements. We show that single deformation bands, deformation band zones and slip-surface cataclasites exhibit dissimilar single- and two-phase fluid flow properties. This is due to grain-size reduction being more pronounced in slip-surface cataclasites and changes in microstructure being fault-parallel for deformation bands but mostly fault-perpendicular for slip-surface cataclasites. A trend of fault rocks with low absolute permeabilities exhibiting lower relative permeabilities than more permeable rocks at the same capillary pressure is evident. 相似文献
7.
Fracture and in-situ stress studies were conducted for unconventional prospect evaluation in the Silurian Qusaiba Shale, northern Saudi Arabia. Borehole image logs, oriented cores, seismic, and drilling observations were used in the studies. The fractures include natural fractures and induced fractures. The induced fractures were studied to assess the stress regime in terms of directions and magnitudes. The present day maximum horizontal in-situ stress trend varies from NNW-SSE to NNE-SSW, and shows a regional pattern dominated by Arabian plate tectonics. The relative magnitudes of the current day stresses are characteristic of an extensional to strike-slip regime. Natural fractures of microscopic (microfractures) to macroscopic (macrofractures) scales include extension fractures (joints/veins), and faults manifested as shear and hybrid (extensional-shear and compressional-shear) fractures. Joints clustering into zones are rare, unless when associated with fault zones. Over half of the faults (56%) show clustering into fault zones with their widths (thickness) varying by up to 5 orders of magnitude, and lengths and displacements varying by up to 4 orders of magnitudes respectively. The study identified five distinctive, regional, fracture sets: one gently dipping (bedding-parallel or at low angle to bedding) and up to four moderately to steeply dipping fracture sets: an easterly striking set is the oldest, followed by three younger major sets striking NNW-SSE, N-S, and NNE-SSW. The younger fractures are nearly parallel to the present day maximum horizontal in-situ stress. Crack-seal mechanism (natural hydrofracturing) dominates initial fracture growth, some with several phases of partial to complete mineralization or coating, dominated by calcite, quartz, and dolomite. Aqueous and hydrocarbon gaseous and fluid inclusions are common in the fractures' mineral filling. The regional nature of in-situ stresses and natural fractures means their occurrence, orientation, relative dominance, and relative age and relative apertures are easier to predict and manipulate for well planning and completion, including hydrofracturing. Forward modeling shows that natural fracture network are not critically stressed under reservoir conditions but when subjected to massive hydrofracture stimulation they and the bedding discontinuities form the seeds for the growth of a complex hydrofracture network that potentially grows out of presumed stress-barriers. Lack of stress rotation around faults in wells supports the modeling results. Microseismic monitoring gives time-lapse (incremental) microseismic events of two types; random and linear patterns parallel to maximum horizontal in-situ stress and the predominant natural fracture trend. Bulk microseismic cloud has no unique link to fault trends mapped from high resolution borehole images. This finding challenges the usability of uncalibrated microseimic monitoring of massive hydrofracturing to map faults. 相似文献
8.
The Callovian–Oxfordian carbonates in the northeastern Amu Darya Basin of southeastern Turkmenistan, are composed of medium-to thick-bedded, mostly grainy limestones with various skeletal (bivalves, brachiopods, echinoderms, foraminifera, corals, and sponge) and non-skeletal grains (intraclasts, ooids, and peloids). The 6 microfacies types recognized in the Callovianand and 18 microfacies types in Oxfordian carbonates are grouped into two depositional phases, ramp and platform. The Callovian carbonates were deposited on a carbonate ramp, which evolved into a depositional platform in the Oxfordian. The main components of the Oxfordian platform margin complex are reefs and shoals. The principal reef builders are corals, algae and sponges. Regional tectonic movements, eustatic sea-level changes and sedimentation rates were the primary controlling factors of facies evolution during the Callovian–Oxfordian time in the northeastern Amu Darya Basin. 相似文献
9.
We acquired structural, granulometric and permeability data from a total of 25 extensional fault zones developed in high-porosity sandy sediments of the Crotone basin. Undeformed sediments have mean permeability values in the 103–105 mD range. The studied fault zones have displacement values spanning from a few centimeters to about 100 m, and generally show well-defined narrow fault cores bounded by damage zones on both hangingwall and footwall sides. Fault core rocks developed by progressive comminution and consist of foliated granular material and gouge lenses along indurated and striated slip surfaces. Mean fault core rock permeability broadly ranges between 101 and 104 mD, although we recorded permeability values lower than 10 mD in gouge lenses. Fault damage zones typically consist of closely spaced single to anastomosing cataclastic deformation bands with different degrees of complexity and mean permeability between 102 and 104 mD, i.e. lower than host sands. We obtained empirical relationships between bulk permeability, fault zone thickness, and fault displacement. In particular, both fault cores and damage zones tend to widen with increasing fault displacement, especially in the first ten meters. Most bulk permeability reductions in both fault cores and damage zones occur at sub-seismic scale, and decrease for displacement greater than 25–30 m. 相似文献
10.
Fractures not only control the distribution of oil and gas reservoirs, but also are key points in the research of oil and gas reservoir development programmes. The tectonic fractures in the Lower Cambrian shale reservoirs in the Feng'gang No. 3 block are effective reservoir spaces for hydrocarbon accumulation, and these fractures are controlled by palaeotectonic stress fields. Therefore, quantitatively predicting the development and distribution of tectonic fractures in the Lower Cambrian shale reservoir is important for the exploration and exploitation of shale gas in the Feng'gang No. 3 block. In the present study, a reasonable geological, mechanical and mathematical model of the study area was established based on the faults systems interpreted from seismic data, fracture characteristics from drilling data, uniaxial and triaxial compression tests and experiments on the acoustic emissions (AE) of rocks. Then, a three-dimensional (3-D) finite element method is applied to simulate the palaeotectonic stress field with the superposition of the Yanshan and Himalayan movements and used to predict the fracture distribution. The simulation results indicate that the maximum principal stress value within the study area ranged from 269.97 MPa to 281.18 MPa, the minimum principal stress ranged from 58.29 MPa to 79.64 MPa, and the shear stress value ranged from 91.05 MPa to 106.21 MPa. The palaeotectonic stress field is controlled by the fault zone locations. The fracture development zones are mainly controlled by the tectonic stress fields and are located around the faults, at the end of the fault zones, at the inflection point and at the intersection of the fault zones. 相似文献
11.
烃源岩的形成和分布受多种因素的影响,构造作用是一个主要的方面。研究认为,断裂作用对烃源岩的影响较大,大的断裂对周边富烃凹陷的形成有明显的控制作用,同时断层活动产生的热量也会影响烃源岩的演化。火山作用造成的岩浆侵入体携带的热能可认为是一个附加热源,促进烃源岩的演化。热液中的一些稀有元素会促进源岩的分布和生烃速率,对烃源岩生烃产生积极作用。构造活动中,挤压作用产生的超压也在一定程度上对烃源岩产生影响。 相似文献
12.
The southern uplift of the Qiongdongnan Basin is a deepwater area in which no wells have beens drilled. The Miocene-Quaternary strata in the Xisha Islands, which are located 40–100 km to the south, are composed of carbonate reef formations. Paleotectonic and paleogeographic analyses of the basin suggest that the southern uplift experienced favorable geological conditions for the development of carbonate reefs during the Miocene.The high-impedance carbonates have high amplitudes and low frequencies on seismic profiles. The reefs are distributed on paleotectonic highs and are thicker than the contemporaneous formations. A forward model of the variation in carbonate thickness based on lithological and velocity information from wells in nearby regions can simulate the seismic response of carbonates with different thicknesses. We identified several important controlling points for determining the thickness of carbonates from seismic profiles, including the pinchout point,the λ/4 thickness point, and the λ/2 thickness point. We depict a carbonate thickness map in the deepwater area of the southern Qiongdongnan Basin based on this model. The carbonate thickness map, the paleotectonic and paleogeographic background, and the seismic response characteristics of reefs suggest that the carbonates that developed on the southern uplift of the Qiongdongnan Basin during the Miocene were mainly an isolated carbonate platform peninsula and ramp deposits. It consisted of gentle ramp platform, steep slope platform,platform depression, gravity flow, and reef bank facies. 相似文献
13.
Pockmarks are observed worldwide along the continental margins and are inferred to be indicators of fluid expulsion. In the present study, we have analysed multibeam bathymetry and 2D/3D seismic data from the south-western Barents Sea, in relation to gas hydrate stability field and sediment type, to examine pockmark genesis. Seismic attributes of the sediments at and beneath the seafloor have been analysed to study the factors related to pockmark formation. The seabed depths in the study area are just outside the methane hydrate stability field, but the presence of higher order hydrocarbon gases such as ethane and/or propane in the expelled fluids may cause localised gas hydrate formation. The selective occurrence of pockmarks in regions of specific seabed sediment types indicates that their formation is more closely related to the type of seabed sediment than the source path of fluid venting such as faults. The presence of high acoustic backscatter amplitudes at the centre of the pockmarks indicates harder/coarser sediments, likely linked to removal of soft material. The pockmarks show high seismic reflection amplitudes along their fringes indicating deposition of carbonates precipitated from upwelling fluids. High seismic amplitude gas anomalies underlying the region away from the pockmarks indicate active fluid flow from hydrocarbon source rocks beneath, which is blocked by overlying less permeable formations. In areas of consolidated sediments, the upward flow is limited to open fault locations, while soft sediment areas allow diffused flow of fluids and hence formation of pockmarks over a wider region, through removal of fine-grained material. 相似文献
14.
生烃是岩石中所含的有机质产生流体有机化合物的化学反应。岩石有机质化学反应存在两种系统：封闭系统和开放系统，随着埋深加大，烃源岩越来越致密，岩石的化学反应逐渐由开放系统转变为封闭系统。目前的生烃理论仅仅是开放系统下烃源岩成熟与生烃理论，烃源岩成熟与生烃是不匹配的。封闭系统下烃源岩成熟与生烃是不匹配的，烃源岩成熟但不生烃，而是形成另外一种成熟的固体有机质。大多数情况是烃源岩为半封闭系统，烃源岩处于欠生烃状态。构造运动形成的断层和裂隙将烃源岩与疏导层沟通，烃源岩迅速由封闭、半封闭系统转变为开放系统。这种生烃系统的转变形成短时间内过量生烃，笔者将这种生烃作用命名为构造生烃，意味着构造运动期即为主生烃期，伴随着多次构造运动可以形成多个幕式生烃高峰。构造生烃理论开拓两个极其重要的勘探领域：第一，新构造勘探。以往认为已经过了生、排烃期的构造得以解放，如渤海湾郯庐断裂带第四纪圈闭不是过了主生烃期，而是正处于构造生烃的过生烃高峰期。以PL19-3为代表的油气运聚强度只有构造生烃能够解释；第二，超深勘探，特别是天然气勘探。深层勘探的下限将大大延伸，生烃门限，特别是生气门限将大大加深，仅生烃而言万米都不是天然气勘探的极限。 相似文献
15.
Growth faults in gravity-driven extensional provinces are dominated by coast-parallel trends, but coast-perpendicular (transverse) trends are far less documented. The Clemente–Tomas fault in the inner Texas shelf has corrugations that are transverse to the fault and that plunge downdip. A large (8500 km2), high-quality, 3D seismic survey allows a uniquely encompassing perspective into hanging-wall deformation above this corrugated fault surface. Synextensional strata in the hanging wall are folded into alternating transverse ridges and synclines, typically spaced 10 km apart. Forward modelling in dip profiles of an extensional fault having three ramps produces ramp basin-rollover pairs that compare with the seismically revealed ridges and synclines. As they translated down the undulose fault plane, ramp basins and rollovers were juxtaposed along strike, forming the hanging-wall ridges and synclines observed offshore Texas. Fault-surface corrugations correlate broadly with footwall structure. We infer that corrugations on the Clemente–Tomas fault formed by evacuation of an allochthonous salt canopy emplaced in the late Eocene to early Oligocene. Early salt evacuation (Oligocene) created an undulose topography that influenced incipient Clemente-Tomas fault segments as they merged to form an inherently undulose fault. Late salt evacuation (early Miocene) further deformed this fault surface. 相似文献
16.
浅层不能生成油气,浅层成藏要有沟通深层油气源的断层,油气沿断层由深层运移至浅层的过程中可能留下足迹,足迹在地震剖面上有多种表象。统计足迹的表象特征,分析油气运移足迹的成因机理,是研究浅层油气成藏的有效手段。气烟囱等油气运移足迹的识别方法,是在生产中总结出并不断得到验证的经验,对生产有很好指导作用。 相似文献
17.
西非下刚果盆地为一典型被动大陆边缘含盐盆地,下刚果盆地北部海域在白垩系海相碳酸盐岩层系获得丰富油气发现。研究区海相碳酸盐岩领域油气勘探面临的核心瓶颈问题,即白垩系碳酸盐岩的沉积模式、演化规律、储层特征以及沉积储层发育控制因素。综合钻井、地震、区域地质等资料,分析认为自下向上相对海平面的上升控制了沉积演化,沉积体系演化模式为浅海碳酸盐岩台地→浅海混积陆棚→半深海-海底扇。下刚果盆地碳酸盐岩储层展布在纵向及平面上均可以划分为内中外3个储层发育带,碳酸盐岩储层最主要发育于下白垩统Albian阶下Sendji组。该时期研究区整体发育浅海碳酸盐岩混积缓坡台地沉积体系,沉积亚相可进一步划分为混积滨岸、后缓坡、浅水缓坡以及深水缓坡4种类型,其中浅水缓坡亚相颗粒滩微相与后缓坡亚相台内浅滩、砂质浅滩微相储层最为发育。碳酸盐岩储层岩性组合主要包括颗粒灰岩、砂岩、砂质灰岩、白云岩4种类型;储层发育主要受沉积相带的控制,并受成岩作用的影响。 相似文献
18.
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. 相似文献
19.
Riphean basins of the central and western Siberian Platform 总被引：1，自引：0，他引：1
Sergey V. FrolovGrigorii G. Akhmanov Elena V. KozlovaOleg V. Krylov Ksenia A. SitarYuriy I. Galushkin 《Marine and Petroleum Geology》2011,28(4):906-920
The Siberian Platform is unique by its volume of Meso-Neoproterozoic sedimentary deposits. For about one billion years (∼1650-650 Ma) several sedimentary basins were developed here, resulting in the formation of several kilometers thickness of sedimentary cover. The Riphean (Mesoproterozoic-Lower Neoproterozoic) rocks are exposed mainly along platform peripheries. The most complete sections are represented by several megacycles. Each megacycle contains terrigenous series at the base and carbonate formations in the upper part. Several isolated and anisochronous basins were created during the Riphean on the territory of East Siberia. Some of them were intracratonic, others were developed on passive margins. Neoproterozoic orogeny along the platform boundaries resulted in re-organization of the Siberian basins, with extensive faulting, uplifting and erosion of the territories.In eastern Siberia, Riphean series contain large hydrocarbon accumulations. The reservoirs were formed mainly due to fracturing and leaching of carbonate strata (e.g. vugular carbonates of the pre-Vendian weathering crust). The Upper Proterozoic deposits are overlain by thick clayey-carbonate and saliferous-carbonate series of the Upper Vendian and Cambrian, isolating them from the upper sedimentary cover. The Riphean basins contained thick, organic rich, clayey and clayey carbonate. In some of them a hydrocarbon generation maximum took place at the end of the Riphean. The pre-Vendian erosion has removed a significant volume of Riphean sediments. During this time a majority of already formed hydrocarbon accumulations have been lost or degraded. Remaining Riphean series have generated hydrocarbons during the Paleozoic.Despite its complex history, the Riphean is still considered highly prospective, with source rocks developing at multiple levels and reservoirs occurring in both carbonate and clastic rocks. Discoveries of new oil-and-gas fields in East Siberia are likely, but will depend on integration of detailed seismic data and a large volume of core data for the correct prognosis of Riphean reservoir distribution. 相似文献
20.
Fluid flow in fractures and host rocks has been investigated in shallow buried Miocene alluvial fan deposits. A structural, petrographical (optical, CL, SE microscopes and XRD) and geochemical (microprobe and δ18O-δ13C stable isotopes) study has been performed in normal faults affecting Serravalian-Tortonian siliciclastic rocks of the Vallès-Penedès basin. These faults formed during the development of the Vallès-Penedès fault-related syncline, which caused the rotation of the earliest fractures. Faulting occurred continuously before, during and after host rock cementation. Rocks affected by faulting are represented by clay-rich gouges, which formed thanks to the high phyllite clast content within the otherwise clean and mature sandstones and conglomerates. Despite the low permeability of these rocks, cross-fault and fault-parallel fluid flows occurred in most of the faults.Host rocks and veins were cemented by two generations of calcite, i.e. Cc1 and Cc2. Cc1 precipitated from meteoric waters at shallow burial conditions whereas Cc2 precipitated from meteoric waters in a confined aquifer.Palygorskite has been identified in shear zones within the gouges indicating their later formation by interaction of Mg-rich fluids with previous smectites. These fluids probably derived from Miocene seawater expelled from the underlying Transitional–Marine Complex “TMC” by compaction.Sedimentation, fracturing and cementation occurred in a very short lapse time of about 6–7 Ma, between the Serravalian-Tortonian age of the sediments and the end of the extensional tectonics in the Vallès-Penedès fault (Pliocene). 相似文献