Pore structure of Cambrian shales from the Sichuan Basin in China and implications to gas storage

The microstructure of black siliceous shale from the lower Cambrian Niutitang Formation, Sichuan Basin in China was investigated by the combination of field emission scanning electron microscope (FE-SEM) and argon ion beam milling. The nanometer-to micrometer-scale pore systems of shales are an important control on gas storage and fluid migration. In this paper, the organic porosity in shale samples within oil and gas window has been investigated, and the formation mechanism and diagenetic evolution of nanopores have been researched.FE-SEM reveals five pore types that are classified as follows: organic nanopores, pores in clay minerals, nanopores of framework minerals, intragranular pores in microfossils, and microfractures. Numerous organic nanopores are observed in shales in the gas window, whereas microfractures can be seen within the organic matter of shales in the oil window. Microfractures in oil window shales could be attributed to pressure buildup in the organic matter when incompressible liquid hydrocarbon are generated, and the orientation of microfractures is probably parallel to the bedding and strength anisotropy of the formation. Pores in clay minerals are always associated with the framework of clay flakes, and develop around rigid mineral grains because the pressure shadows of mineral grains protect pores from collapse, and the increasing of silt content would lead to an increase in pressure shadows and improve porosity. Nanopores of rock framework are probably related to dissolution by acidic fluids from hydrocarbon generation, and the dissolution-related pores promote permeability of shales. Porosity in the low-TOC, low-thermal-maturity shales contrast greatly with those of high-TOC, high-thermal-maturity shales. While the high-TOC shales contain abundant organic microporosity, the inorganic pores can contribute a lot to the porosity of the low-TOC shales.     

Study on the Cretaceous turbidite and reservoir features in the Qingshankou Formation in northern Songliao Basin,NE China

Based on analysis of well and drilling data, cores, sediment grains and 3D seismic data, four types of turbidites–slope fan, channelized, laminated and sublacustrine fan turbidite–are identified in Members 1 and 2 of the Qingshankou Formation in northern Songliao Basin. The slope fan turbidite is located in Members 1 and 2 of the Qingshankou Formation. It is dominated by silt and fine sand and is distributed in an SN-trending ribbon zone along the slope break at delta front in the western part of the basin. The channelized turbidite is located at the bottom of Member 1 of the Qingshankou Formation. It is dominated by silt and fine sand and is distributed in an SN-trending strip-shaped zone along the Qijia-Gulong sag, with funnel-shaped sublacustrine fans at the end. The laminated turbidite body is located in Member 2 of the Qingshankou Formation. It is dominated by siltstone and argillaceous siltstone and is distributed continuously in a tongue-shaped zone along the northern delta front towards the lacustrine region, with belt-like distributaries at the central part and sublacustrine fans at the end. Low-permeability and low-yield lithologic reservoirs are formed near the delta front within the slope fan turbidite and channelized turbidite. There are “sweet spots” in local regions, where reservoir reform techniques are required to attain high industrial yields. Laminated turbidite and sublacustrine fans can form unconventional and continuous reservoirs that generally have no natural productivity; industrial production is impossible until horizontal drilling and multistage volume fracturing are employed. Therefore, the research results are important to the exploration of unconventional oil and gas reservoirs in northern Songliao Basin.     

Impact of high water pressure on oil generation and maturation in Kimmeridge Clay and Monterey source rocks: Implications for petroleum retention and gas generation in shale gas systems

This study presents results for pyrolysis experiments conducted on immature Type II and IIs source rocks (Kimmeridge Clay, Dorset UK, and Monterey shale, California, USA respectively) to investigate the impact of high water pressure on source rock maturation and petroleum (oil and gas) generation. Using a 25 ml Hastalloy vessel, the source rocks were pyrolysed at low (180 and 245 bar) and high (500, 700 and 900 bar) water pressure hydrous conditions at 350 °C and 380 °C for between 6 and 24 h. For the Kimmeridge Clay (KCF) at 350 °C, Rock Eval HI of the pyrolysed rock residues were 30–44 mg/g higher between 6 h and 12 h at 900 bar than at 180 bar. Also at 350 °C for 24 h the gas, expelled oil, and vitrinite reflectance (VR) were all reduced by 46%, 61%, and 0.25% Ro respectively at 900 bar compared with 180 bar. At 380 °C the retardation effect of pressure on the KCF was less significant for gas generation. However, oil yield and VR were reduced by 47% and 0.3% Ro respectively, and Rock Eval HI was also higher by 28 mg/g at 900 bar compared with 245 bar at 12 h. The huge decrease in gas and oil yields and the VR observed with an increase in water pressure at 350 °C for 24 h and 380 °C for 12 h (maximum oil generation) were also observed for all other times and temperatures investigated for the KCF and the Monterey shale. This shows that high water pressure significantly retards petroleum generation and source rock maturation. The retardation of oil generation and expulsion resulted in significant amounts of bitumen and oil being retained in the rocks pyrolysed at high pressures, suggesting that pressure is a possible mechanism for retaining petroleum (bitumen and oil) in source rocks. This retention of petroleum within the rock provides a mechanism for oil-prone source rocks to become potential shale gas reservoirs. The implications from this study are that in geological basins, pressure, temperature and time will all exert significant control on the extent of petroleum generation and source rock maturation for Type II source rocks, and that the petroleum retained in the rocks at high pressures may explain in part why oil-prone source rocks contain the most prolific shale gas resources.     

Depositional and palaeoenvironmental variation of lower Turonian nearshore facies in the Bohemian Cretaceous Basin,Czech Republic

Dark grey strata belonging to the basal horizons of the Bílá Hora Formation (lower Turonian) were exposed during quarrying at the locality of Plaňany (Bohemian Cretaceous Basin). Based mainly on quarry maps, the early Turonian rocky bottom was reconstructed in the area of about 14,800 m². Two sedimentologic and palaeoecological settings were recognized in the area. Dark grey deposits form part of the first setting, representing a fill of large and deep depressions on the northern foot of the Plaňany elevation. The second setting with a phosphatic lag is located on the elevated part of the area. Dark grey sedimentation belongs to the UC6a and particularly to the UC6b nannoplankton zones. During the latter zone the dark sedimentation passed upwards into light siltstones. The enrichment of C_org and S, clay minerals with an important kaolinite peak, formation of framboidal pyrite and the enrichment of macrofauna and phosphatic particles are characteristic of the basal portions of the dark deposits. The sulphate reduction zone is suggested for this sedimentary environment. In the associations of phosphatic particles, shark coprolites, faecal pellets and sponge fragments prevail. No phosphatic lag is developed. On the other hand, the phosphatic lag directly overlying the Cenomanian relics is most characteristic of the second setting. This lag is a product of sedimentary condensation, characterized by a long-lasting concentration of phosphatic particles and phosphogenesis, accompanied by encrustation of closely adjacent free rock surfaces by a faunal community with Terebella. Additional biostratigraphic data presently contributed to a proposed correlation of both settings. Micropalaeontological data (foraminifera, palynomorphs, nannoplankton) indicate that the phosphatic lag and basal dark grey deposits may be approximately coeval. The stagnant depositional conditions with only very slow sea-level rise are thought to have lasted for a relatively long period that includes a significant part of the Whiteinella archaeocretacea Zone (lowermost Turonian). In elevated parts, condensation could proceed under conditions of prevailingly weak currents and strong oxidation of organic matter, while decomposition of organic matter was probably very slow and incomplete in depressions below the elevation. The sedimentary condensation in both settings is highlighted by the remarkable formation of abundant glauconite in local deposits.     

北美东部被动大陆边缘盆地的分段性与油气勘探

北美东部被动大陆边缘是世界上最古老的完整被动大陆边缘之一,是研究被动大陆边缘发育演化的天然实验室。本文在大量国外研究成果的基础上,应用盆地构造解析方法,深入研究了北美东部被动大陆边缘盆地群的地质结构和构造演化特征,并揭示了盆地群的油气地质规律。研究认为,北美东部盆地群沉积充填和不整合面发育具有明显的分段性和差异性。以区域不整合面为界,不同段盆地可划分为不同的构造层:南段盆地可划分为两套构造层;中段南部盆地可划分为3套构造层;中段北部盆地可划分为4套构造层;而北段盆地可划分为5套构造层。盆地群整体经历了陆内裂谷—陆间裂谷—被动大陆边缘的演化过程,但不同段盆地的构造演化具有明显的分段性和迁移性:晚三叠世沉降中心位于南段盆地;早侏罗世初期迁移至中段盆地,南段大陆开始裂解;中侏罗世逐渐迁移至北段盆地,中段大陆开始裂解;早白垩世晚期,北段大陆开始裂解。受持续的抬升剥蚀及大西洋岩浆活动省的联合作用,南段盆地和中段大多数盆地缺乏油气保存条件;斯科舍盆地和大浅滩盆地是主要的含油气盆地,以上侏罗统烃源岩为主,主要发育断层—背斜圈闭和盐体刺穿圈闭,整体表现为“自生自储”和“下生上储”的特征。     

卫星遥感技术在油气勘探中的应用

卫星遥感技术在油气勘探中的应用日趋广泛,尤其在含油气盆地构造研究和烃类微渗漏检测方面取得了显著进展。根据目前国内外的研究资料,结合中国南方的遥感实例,介绍了盆地的遥感构造特征,遥感解译的方法、步骤和实际效果。阐述了遥感技术在油气藏烃类微渗漏勘探中的检测原理、方法和应用。现状表明,高光谱遥感与智能计算将在油气勘探中发挥重要作用。     

盆—山油气关系实例浅析

克拉通盆地的前身常常是古老硬陆块,而有些巨型造山带的前身则是深海。深海中可以形成天然气水合物,并对其下方的游离气和深部的油气具有封盖意义,使它们得以向邻域的台地高处发生迁移,从而使现今造山带的烃源岩与盆地区的油气资源发生内在的联系。北美落基山区泥盆纪伍德福页岩、俄罗斯乌拉尔山区的烃源岩、中东的扎格罗斯山区烃源岩等都是确认的优良烃源岩,它们对油气储量具有积极贡献。我国四川盆地、塔里木盆地油气储量与盆地内烃源岩不匹配的难题也可由造山带(古大洋区)提供油气而得到解释。因此,石油工作者需重视造山带中烃源岩对克拉通盆地油气储量的贡献。     

桂中坳陷海相地层油气成藏与热作用改造

桂中坳陷是在加里东运动基础上形成的晚古生代海相大型沉积坳陷,已演化成为由上古生界和三叠系充填的残留盆地,其中泥盆系深埋地腹,是主要的勘探目的层系。桂中1井揭示泥盆系—石炭系具有两套生储盖组合,钻遇了气测异常、油迹砂岩、固体沥青等三类油气显示,其中泥盆系沥青显示井段累计709m。桂中坳陷古油藏(沥青)主要来源于中—下泥盆统塘丁组和罗富组泥岩。桂中1井和南丹大厂储层固体沥青为运移/成藏的油气发生热裂解而形成的焦沥青。桂中1井经历了两期油气充注,第一期为印支期前的主力生烃期,第二期(晚期)为燕山期—喜马拉雅期,以紧邻油气显示层的可溶烃类为代表。经历了三期油气改造:第一期为印支期前的油气藏经历了地层沉降增温的热裂解作用而演化为固体沥青和甲烷天然气,第二期为燕山晚期岩浆活动导致的更高温度的热蚀变作用,第三期为喜马拉雅期构造抬升的改造或破坏作用对上泥盆统油气藏的影响。晚期成藏的天然气应是下一步的勘探方向。桂中坳陷西部地层保存相对完整(目的层深埋),断裂和岩浆活动相对不发育,可能更有利于天然气的聚集和保存。     

二氧化碳气成藏的断裂控制作用

对二氧化碳(CO_2)气成藏来说,各种级别不同性能断裂的存在是必不可少的条件,按其在成藏过程中功能的不同可以分为成气、疏气、储气和封气四种类型。断裂对幔源-岩浆成因CO_2气最重要的作用是对幔源气的运移疏导作用。幔源CO存在于地下深处,其释放的途径有两种:一是没有岩浆喷发和侵入的情况下,沿深断裂直接释放;二是在岩浆喷溢、侵入过程中冷却时释放的幔源气,断裂作为岩浆喷溢、侵入的通道。岩浆活动为幔源型CO_2成藏提供了主力气源,深大断裂为CO_2提供了运聚的通道和赋存的空间。断裂对变质成因CO_2气的最重要的作用是对CO_2气的生成和疏导作用。在动力变质作用中,断裂活动的构造热使碳酸盐岩分解释放CO_2,压扭性断裂带与张启性断裂的交汇带即成为变质成因CO_2的生成与排放中心;在接触变质作用,断裂不仅作为岩浆或高温热液的通道使得围岩变质释放CO_2,而且也是变质成因CO_2运移释放的通道。     

塔里木盆地北部中、新生代钻孔岩芯古地磁研究──喜山期岩石重磁化与油气移聚

对来自塔里木盆地北部５口钻井的部分中、新生代沉积岩岩芯样品进行了古地磁研究，通过对重磁化组分和特征剩磁组分与露头样品的比较，确定了井下样品的喜山期严重重磁化；并通过烃类分析和对磁性分选颗粒的扫描电镜观察，发现了与碳氢化合物有关的球形磁铁矿颗粒和具有黄铁矿格架颗粒的球形磁铁矿聚集体，从而认为重磁化与油气移聚相关，据此确认了喜山期的油气移聚．