碳酸盐岩储层测井评价方法

从碳酸盐岩储层类型划分、储层参数表征、流体性质判别到数学方法的应用等4个方面,系统总结厘定了国内外碳酸盐岩储层测井评价的方法技术,通过对比分析各种评价方法可知:根据一定的数学算法,综合利用常规测井和成像测井不仅能很好地识别储层类型,而且能实现对储层参数的半定量、定量计算评价。利用常规测井和测井新技术资料(电测井和声波测井)计算出缝洞储层的各项物性参数,在此基础上,结合常规测井、核磁共振测井和偶极横波测井能进一步判别出流体性质。通过与岩心分析结果比较,该储层参数计算方法不仅有效,而且简单可行。数学算法和测井新技术资料在复杂碳酸盐岩储层评价中发挥不可替代的作用,能解决复杂碳酸盐岩储层的计算评价问题。以碳酸盐岩储层特征及流体性质为切入点,结合各种地质、地震和测井资料,借助数学算法,准确地识别储层类型与判别流体性质,并精确求解碳酸盐岩储层特别是缝洞储层的物性参数,将是碳酸盐岩储层测井评价的重点及发展方向。     

多点地质统计学建模的发展趋势

从算法研究、训练图像处理和实际应用三个方面详细解剖了国内外多点地质统计学的发展历程,在此基础上,分析了多点地质统计学主流的几种算法的核心原理、适用范围及优缺点,以此来对储层建模的发展趋势作出展望。目前,多点地质统计学虽是随机建模的一种前沿研究热点,但由于其尚未成熟,仍需对建模算法进行研究。为此,在前人研究的基础上,重点分析了多点地质统计学的发展趋势：合理处理训练图像;合理利用软信息;选择合适的相似性方法;选择合适的标准化方法;合理利用平稳性;算法间的耦合;选择合适的过滤器;拓展缝洞型碳酸盐岩模拟。最后,提出多点地质统计学在储层建模方面,应从增加储层的模拟区域、提高模拟精度、扩大储层相的模拟范围和提高计算机模拟效率等方面进行改进。     

Carbon Fluxes and Sinks: the Consumption of Atmospheric and Soil CO2 by Carbonate Rock Dissolution

Carbonate rock outcrops cover 9%–16% of the continental area and are the principal source of the dissolved inorganic carbon (DIC) transferred by rivers to the oceans, a consequence their dissolution. Current estimations suggest that the flux falls between 0.1–0.6 PgC/a. Taking the intermediate value (0.3 PgC/a), it is equal to 18% of current estimates of the terrestrial vegetation net carbon sink and 38% of the soil carbon sink. In China, the carbon flux from carbonate rock dissolution is estimated to be 0.016 PgC/a, which accounts for 21%, 87.5%–150% and 2.3 times of the forest, shrub and grassland net carbon sinks respectively, as well as 23%–40% of the soil carbon sink flux. Carbonate dissolution is sensitive to environmental and climatic changes, the rate being closely correlated with precipitation, temperature, also with soil and vegetation cover. HCO3- in the water is affected by hydrophyte photosynthesis, resulting in part of the HCO3? being converted into DOC and POC, which may enhance the potential of carbon sequestration by carbonate rock dissolution. The possible turnover time of this carbon is roughly equal to that of the sea water cycle (2000a). The uptake of atmospheric/soil CO2 by carbonate rock dissolution thus plays an important role in the global carbon cycle, being one of the most important sinks. A major research need is to better evaluate the net effect of this sink in comparison to an oceanic source from carbonate mineral precipitation.     

珠江口盆地（东部）珠江组碳酸盐岩层序地层及储层分布

以层序地层学理论为指导,运用岩芯观察及薄片鉴定、测井、录井、地震及其古生物等资料对珠江口盆地（东部）珠江组碳酸盐岩进行层序地层研究,共识别出5个三级层序界面和4个三级层序,各三级层序界面均是Vail的Ⅱ类层序界面的具体表现,建立了珠江组碳酸盐岩的层序地层格架。在层序地层研究的基础上,对碳酸盐岩储层的时空分布进行了系统研究,储层主要发育在三级层序高位体系域。结果表明:有利储集相带分布于流花地区SQ3 HST台地边缘礁及生屑滩,较有利储集相带分布于惠州地区SQ1 HST、SQ2 HST台地边缘礁、生屑滩或台内点礁、生屑滩,以及陆丰地区SQ1 HST台内点礁、生屑滩。     

碳酸盐岩中地开石的分布特征及其成因

塔里木盆地巴楚-麦盖提地区石炭系小海子组碳酸盐岩中存在大量地开石,利用X射线粉晶衍射对该矿物进行了鉴定,利用阴极发光显微镜和扫描电镜对地开石的形态与分布进行了研究。地开石晶体为短柱状,晶体大小约3~13 μm,分布在溶蚀孔、白云石晶间孔和缝合线的溶解段中。经岩石薄片和阴极发光观察,发现在地开石出现的岩样中存在萤石。地开石与萤石组合的出现,表明该地区小海子组存在着热液活动。经统计,地开石和萤石通常富集于某一层,可追踪热液流体来源的深度。由于地层中未见地开石的前身矿物,并且在温度低于100℃的地层中也出现了地开石,推断该区地开石为热液成因。热液流体不仅为地开石形成创造了条件,还导致了小海子组碳酸盐岩产生大量溶蚀孔隙。热液与岩石间的水岩反应导致萤石交代白云石,溶孔壁白云石重结晶。通过对储层物性数据的分析,表明热液溶蚀能明显增加孔隙度,但萤石和地开石的形成对孔隙度起破坏作用。热液溶蚀是小海子组碳酸盐岩储层形成的重要机理,对指导该区油气勘探具有实际意义。     

巴颜喀拉盆地长石头山二叠纪—三叠纪碳酸盐岩丘的沉积岩石学和地球化学特征

青海巴颜喀拉盆地长石头山二叠纪—三叠纪碳酸盐岩丘是由罕见的块状纯灰岩组成,灰岩具团块结构,由泥微晶方解石团块和栉状生长的泥微晶方解石胶结物组成,部分泥微晶方解石发生了重结晶作用。灰岩的矿物组成主要为方解石,平均含量达97%,化学成分除CaO外,其余均低于5‰。灰岩的5%HNO3可溶相（碳酸盐矿物）稀土元素页岩配分模式具...     

安徽巢湖-南陵地区栖霞组碳酸盐岩定量微相分析

安徽巢湖-南陵地区栖霞组地层较为发育,厚度稳定,具有较高的有机质含量和良好的孔隙度。前人对本区栖霞组碳酸盐岩的微相研究均为定性的工作,因此,定量分析栖霞组碳酸盐岩的微相特征对其沉积相的进一步确定及油气资源的预测与勘探均具有重要的意义。栖霞组中第一段为斜坡中部沉积,颗粒和开阔海生物含量及颗粒/基质比最高,分别为35.65%、0.43%和0.70;第二段为斜坡下部沉积,颗粒含量和颗粒/基质比值最小,分别为24.69%和0.38,开阔海生物含量也最高,为0.43%;第三段为开阔台地沉积,具有较高的颗粒含量和最低的开阔海生物含量,分别为32.68%和0.34%;第四段为斜坡中上部沉积,具有较高的颗粒含量和颗粒/基质比,分别为29.91%和0.52,开阔海生物含量为2.39%。该结论与以往认识一致,进一步佐证了前人的研究成果。     

湖相碳酸盐岩烃源岩有机显微组分分类及其岩石学特征——以酒西盆地为例

酒西盆地主力烃源岩为下白垩统下沟组和赤金堡组暗色半深湖相-深湖相的白云质泥岩和泥质白云岩,是典型的湖相碳酸盐岩烃源岩。通过对酒西盆地下白垩统二百多块湖相碳酸盐岩烃源岩详细的有机岩石学研究,解剖了湖相碳酸盐岩烃源岩中有机质的赋存形式,揭示了藻纹层为有机质纹层的主要发育形式,其与富泥晶白云石纹层和富粘土纹层构成湖相碳酸盐岩烃源岩特有的"三元式纹层"沉积结构,系统总结了各显微组分的光性、成因、生烃性及分布规律,提出了以全岩和干酪根为基础的湖相碳酸盐岩有机显微组分分类方案,首次鉴定出对酒西盆地油气有贡献的主要生烃组分为腐泥无定形体、腐殖无定形体以及浮游藻类体、孢粉体、壳屑体五种有机显微组分。     

Large earthquake‐triggered liquefaction mounds and a carbonate sand volcano in the Mesoproterozoic Wumishan Formation,Beijing, North China

Ten well‐preserved, earthquake‐triggered liquefaction mounds and a carbonate sand volcano have been found in the Mesoproterozoic Wumishan Formation (1550–1400 Ma) in the Beijing area, North China. These features crop out in a roadcut near Zhuanghuwa Village. All ten mounds occur in the same sedimentary layer and have rounded shapes with some concentric and radial fissures arising from the centre. They range from 1.5 to 4 m in diameter and from 10 cm to 30 cm in height. The carbonate sand volcano has a diameter of 110 cm and the ‘crater’ at the top has a depth of about 30 cm. Associated with these mounds and the sand volcano are many ‘normal’ sedimentary structures and numerous soft‐sediment deformation structures. The former include ripple marks, cross‐bedding, stromatolites and desiccation cracks, indicating deposition in a stable shallow‐water peritidal platform environment. The latter include intrastratal faults and folds, seismically formed breccias and carbonate clastic dykes. The morphological features and the genesis of these liquefaction mounds are very similar to mounds formed recently by the great Wenchuan Earthquake of China (2008). Detailed thin‐section study of the mounds found no signs of any kind of biological constructional process; instead it reveals some obvious fluidification and liquefaction characteristics. Comparative studies have shown that these features are probably the products of Mesoproterozoic earthquake activity. Copyright © 2013 John Wiley & Sons, Ltd.     

Early Palaeozoic carbonate reservoirs from the Yingshan Formation of Well block ZG‐43 in Tazhong Low Rise,Central Uplift,Tarim Basin,NW China: geological features and controlling factors

Marine carbonate reservoirs, as a focus of petroleum exploration and development in China, are involved with high exploration risk and prediction difficulty owing to high heterogeneity and diversity of reservoir beds. In the Tarim Basin, NW China, carbonate reservoirs host about 38% of the whole basin's hydrocarbon resources in a large prospecting area mainly distributed in the Cambrian and Ordovician rocks in central (Tazhong) and northern (Tabei) Tarim. Recently, a better understanding has been made of the karsted weathering crust at the top of the Lower Ordovician Yingshan Formation in the northern slope area of the Tazhong Low Rise, Central Uplift, Tarim Basin. As a new frontier of exploration, oil/gas distribution and controlling factors of carbonate reservoirs in the Yingshan Formation are not clearly understood. In this work, we investigated the reservoir beds and oil/gas properties in 13 wells in Well block ZG‐43 on the No. 10 structural belt in the Tazhong Low Rise, and studied hydrocarbon accumulation characteristics with seismic and geochemical data. The Yingshan Formation in Well block ZG‐43 is mainly composed of calcarenite, dolomitic limestone, dolomite, cryptite, as low porosity and low permeability reservoir beds, with fracture‐void porosity constituting the main reservoir pore space. Oil/gas is quasi‐layer distributed beneath the unconformity between the Yingshan and Lianglitag formations to a depth of 140 m. The oil in Well block ZG‐43 is condensate with low density, low viscosity, low sulphur, low resin, low asphaltene, and high wax. The gas is 87.3% methane, generally containing H₂S. The oil/gas distribution pattern is oil in the east and gas in the west, and H₂S content in the west is lower than that in the east. The controlling factors for hydrocarbon are multi‐source supply and multi‐phase charging, interstratal karstification, hydrothermal activity, structural location and sealing condition. A structural–lithological trap is the main type of oil/gas accumulation. Oil/gas distribution was clearly affected by strike–slip faults. Oil/gas with multi‐source supply and multi‐phase charging was controlled by favourable local palaeo‐highs, and affected by later karsting and hydrothermal activity, as well as gas invasion in the Himalayan (Cenozoic) period. Under the caprock of compact limestone in the third to fifth members of the Lianglitag Formation, oil/gas migrated up along the strike–slip fault planes, and moved laterally to both sides in a ‘T’ shape, and formed large‐scale quasi‐layer condensate gas reservoirs controlled by reservoir bed quality. Copyright © 2013 John Wiley & Sons, Ltd.