渝东北下寒武统水井沱组陆棚相黑色页岩沉积演化特征   总被引：1，自引：0，他引：1       下载免费PDF全文

朱瑜  张帆  李少荣 《地质科学》2016,(3):961-977

渝东北地区位于四川中生代前陆盆地和扬子陆块南部被动边缘褶冲带的结合部位,形成东西向密集、大体平行、不对称的背、向斜构造。研究区下寒武统水井沱组发育在克拉通内坳陷形成的滞留盆地沉积环境中,是页岩气富集层位,埋藏深,岩相组合变化大。本文利用地层剖面组合、岩性、标准层、地层厚度和地球化学指标等将水井沱组页岩地层划分为两个三级层序（SQ1、 SQ2）,每个层序又进一步划分为两个体系域,即海侵体系域TST和高位体系域HST。通过野外剖面沉积相分析和沉积相平面展布特征的研究,结合连井剖面、黑色页岩分布规律等分析该区陆棚相黑色页岩沉积演化特征。研究结果表明：该套页岩主要由浅海深水陆棚相、浅水陆棚相和砂质陆棚相组成,为3种陆棚亚相沉积。  相似文献   

吉木萨尔凹陷芦草沟组烃源岩评价及页岩油富集条件探讨          下载免费PDF全文

邱振  陶辉飞  卢斌  吴晓智  杨智  唐勇  崔景伟  周杰 《地质科学》2016,(2):533-546

准噶尔盆地吉木萨尔凹陷芦草沟组为一套优质陆相烃源岩, 是我国当前页岩油气研究的热点地区之一.基于吉木萨尔凹陷18口井芦草沟组约为580 m岩心观察、薄片观察、地球化学测试等数据, 对芦草沟组烃源岩岩石类型、地球化学特征等方面开展了研究与评价, 结果表明: 1)芦草沟组烃源岩整体上为优质烃源岩, 且以Ⅰ-Ⅱ型有机质类型为主, 处于低熟至成熟阶段; 2)烃源岩主要划分为5种类型, 包括纯页岩、白云质页岩、纯泥岩, 白云质泥岩和粉砂质泥岩, 其有机质类型和丰度存在一定差异.综合研究得出, 吉木萨尔凹陷芦草沟组优质有效烃源岩的有机质丰度下限值为2.0%, 并认为TOC≥2.0%的烃源岩段也是该区页岩油发育的有利层段.  相似文献   

Release of selected chemical elements from shale drill cuttings to aqueous solutions of different pH     

《Applied Geochemistry》2016

  相似文献   

Deep groundwater circulation and associated methane leakage in the northern Canadian Rocky Mountains     

《Applied Geochemistry》2016

Concern over potential impact of shale gas development on shallow groundwater systems requires greater understanding of crustal scale fluid movement. We examined natural deeply circulating groundwater systems in northeastern British Columbia adjacent to a region of shale gas development, in order to elucidate origin of waters, depths of circulation, and controls on fluid flow. These systems are expressed as thermal springs that occur in the deformed sedimentary rocks of the Liard Basin. Stable isotope data from these springs show that they originate as meteoric water. Although there are no thermal anomalies in the region, outlet temperatures range from 30 to 56 °C, reflecting depth of circulation. Based on aqueous geothermometry and geothermal gradients, circulation depths up to 3.8 km are estimated, demonstrating connection of deep groundwater systems to the surface. Springs are also characterised by leakage of thermogenic gas from deep strata that is partly attenuated by methanotrophic microbial communities in the spring waters. Springs are restricted to anomalous structural features, cross cutting faults, and crests of fault-cored anticlines. On a regional scale they are aligned with the major tectonic features of the Liard Line and Larsen Fault. This suggests that while connection of surface to deep reservoirs is possible, it is rare and restricted to highly deformed geologic units that produce permeable pathways from depth through otherwise thick intervening shale units. Results allow a better understanding of potential for communication between deep shale gas units and shallow aquifer systems.  相似文献   

鄂尔多斯盆地东部二叠系山西组页岩气成藏条件与有利区筛选     

兰朝利  郭伟  王奇  张欣 《地质学报》2016,90(1):177-188

鄂尔多斯盆地东部榆106井区山西组页岩沉积在三角洲平原分流河道间沼泽、天然堤、决口扇远端与洼地环境。根据有机地球化学、物性、含气性、岩性实验分析,结合钻井、录井、测井资料与沉积相研究,开展了该区山西组页岩气成藏条件与有利区分布研究。山西组页岩有机碳含量较高,山二段平均5.28%,山一段平均3.02%,有机质类型以Ⅱ_2、Ⅲ型干酪根为主,有机质成熟度较高,R_o平均1.89%,生气条件优越。页岩孔隙度平均1.7%,渗透率平均0.0415×10~(-3)μm~2,平均含气量0.64 m~3/t,页岩单层厚度小,垂向上普遍与致密砂岩、煤层组成互层,累计厚度较大(平均达75 m),页岩渗透性较好而储集性能稍差。页岩脆性矿物含量平均49.9%,黏土矿物含量平均50.1%,黏土矿物含量较高,资源丰度普遍较低,但是页岩埋深小于3000 m,试气产能较高(0.64×10~4m~3/d),商业开发潜力较好。山二段有机质含量比山一段更高,含气性比山一段更好。主要基于页岩厚度与沉积相展布预测的山二段页岩气有利区呈北东向、南北向条带状展布,受分流河道间沼泽微相的控制。  相似文献   

滇黔北坳陷及邻区下志留统龙马溪组页岩气储层特征   总被引：1，自引：0，他引：1  

舒兵  张廷山  梁兴  杨洋  谢磊  张朝 《海相油气地质》2016,(3):22-28

基于8口钻井、2个剖面点的岩样观察和测试分析,滇黔北坳陷及邻区下志留统龙马溪组下段是富有机质泥页岩发育的层段,有机质演化达到过成熟阶段。X衍射全岩分析表明,龙马溪组泥页岩由黏土矿物、石英、碳酸盐、长石、黄铁矿等矿物组成,黏土矿物则以伊利石为主。泥页岩的平均脆性指数56.11%~73.21%,压裂时易于形成网络裂缝;常规物性测试,孔隙度、渗透率很低,扫描电镜观察,纳米级孔隙和裂缝发育。  相似文献   

Palaeopressure reconstruction to explain observed natural hydraulic fractures in the Cleveland Basin     

《Marine and Petroleum Geology》2016

Natural fractures observed within the Lower Jurassic shales of the Cleveland Basin show evidence that pore pressure must have exceeded the lithostatic pressure in order to initiate horizontal fractures observed in cliff sections. Other field localities do not show horizontal fracturing, indicating lower pore pressures there. Deriving the burial history of the basin from outcrop, VR and heat-flow data gives values of sedimentation rates and periods of depositional hiatus which can be used to assess the porosity and pore pressure evolution within the shales. This gives us our estimate of overpressure caused by disequilibrium compaction alone, of 11 MPa, not sufficient to initiate horizontal fractures. However, as the thermal information shows us that temperatures were in excess of 95 °C, secondary overpressure mechanisms such as clay diagenesis and hydrocarbon generation occurred, contributing an extra 11 MPa of overpressure. The remaining 8.5 MPa of overpressure required to initiate horizontal fractures was caused by fluid expansion due to hydrocarbon generation and tectonic compression related to Alpine orogenic and Atlantic opening events. Where horizontal fractures are not present within the Lower Jurassic shales, overpressure was unable to build up as high due to proximity to the lateral draining of pressure within the Dogger Formation. The palaeopressure reconstruction techniques used within this study give a quick assessment of the pressure history of a basin and help to identify shales which may currently have enhanced permeability due to naturally-occurring hydraulic fractures.  相似文献   

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

《Marine and Petroleum Geology》2016

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.  相似文献   

Pore structure of the graptolite-derived OM in the Longmaxi Shale,southeastern Upper Yangtze Region,China     

《Marine and Petroleum Geology》2016

The Lower Silurian Longmaxi Shale in the southeastern Upper Yangtze Region, which has been the main target for shale gas exploration and production in China, is black marine organic-rich shale and rich in graptolites. Graptolites, usually only periderms preserved in shales, are important organic component of the Longmaxi Shale. However, the pore structure of graptolite periderms and its contribution to gas storage has not yet been studied before. A combination of optical microscopy for identification and “mark” of graptolite and scanning electron microscope (SEM) for pore observations were conducted for the Longamxi Shale samples. Results show that pores are anisotropic developed in the Longmaxi graptolite periderms and greatly associated with their fine structure. Micrometer-sized fractures and spindle-shaped pores between cortical fibrils in the cortical bandage are greatly developed at section parallel to the bedding, while they are rare at section perpendicular to the bedding. Besides, numerous sapropel detritus rich in nanometer-sized pores are discretely distributed in the shale. Though graptolite periderms are low porosity from SEM image analysis, microfractures and elongated pores along the graptolite periderm wall may still make the graptolite an interconnected system. Together with the discrete porous sapropel detritus in shale, these graptolite-derived Organic Matter (OM) may form an interconnected organic pore system in the shale. The difference of pore development observed in graptolite periderms and sapropel detritus also give us new insight for the organic pore heterogeneity study. The OM composition, their fine structure and orientation in the rock may be important factors controlling OM pore development. The combination of identifying OM type under optical microscopy and pores observation under SEM for may be an effective method to study the OM pore development especially in shale that contain more OM.  相似文献   

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     

《Marine and Petroleum Geology》2016

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.  相似文献