The heavy mineral assemblages and chemistry of detrital spinel grains from the Senonian basin of the Transdanubian Range (TR) were examined and compared with previous results from Jurassic and Lower Cretaceous successions of the Gerecse Mountains of the Transdanubian Range Unit. The heavy minerals recorded that in the area of Transdanubian Range the sedimentary cover, low-grade metamorphic and granitic rocks of the continental crust were eroded in the Coniacian and Santonian. Detritus of high-grade metamorphics was transported to the bathyal basin during Campanian time. The ophiolitic source area indicated by the presence of chrome spinel, ilmenite and magnetite still existed and persisted through the Late Cretaceous. Compared to the low TiO2 content (lower than 0.2 wt%) of detrital spinels from Jurassic and Lower Cretaceous sediments of the Gerecse Mountains, the most characteristic features of spinels in the Senonian sediments are as follows: exceptionally high TiO2 content (about 0.5-4.7 wt%), relatively high amount of Cr2O3 (about 33-50.8 wt%) and high total iron (sumFeO=15-36 wt%). The data on detrital spinels from the Ajka Coal and Csehbánya Formations suggests that xenoliths (mainly dunites), which previously enclosed the spinel grains, may have been formed from alkalic-tholeiitic magma as crystal accumulates. This was the potential source rock of high TiO2-bearing spinel grains.
Authors:Tamás Földes, Gizella B. Árgyelán, Péter Bogner, Imre Repa, Balázs Kiss, and Kinga Hips
This paper summarizes the benefits of non-destructive core measurements by medical Computer Tomograph (CT) in integrated 3D reservoir characterization. A direct relationship exists between CT measurements and petrography, conventional petrophysical analysis and well logs. Based on CT measurements the internal structure of core samples, and the geometry of framework constituents, porosity type and pore size distribution, as well as fracturing, can be described. There is a close connection between distribution of the Hounsfield Unit of CT measurements and pore size distribution detected by conventional petrophysical analysis. Calculation of effective porosity from petroleum saturation experiments provides a new way to determine the porosity of the whole core sample. Beside the description of reservoir parameters, the results of CT measurements can be extended over the surrounding area of the well. By matching the cylinder maps of CT to FMI images and other well logs the original position of the core samples can be reconstructed. Applying high-tech CT measurements in 3D reservoir characterization and modeling of fluid migration significantly reduces the exploration and production risks.