Abstract
This article presents a novel methodology for data integration including laboratory data, the results of standard well logging measurements and interpretation and the interpretation of XRMI imager data for determination of the porosity and permeability of the fracture system in carbonate rock. An example of the results of the micro computed tomography applied for carbonate rock is included. Data were obtained on the area of the Polish Lowland Zechstein Main Dolomite formation. The input set of data included the results of mercury injection porosimetry (MICP), thin section and polished section analysis, well logging measurements and comprehensive interpretation and micro computed tomography. The methodology of the macrofractures’ analysis based on borehole wall imagery as well as estimation of their aperture was described in detail. The petrophysical characteristics of the fracture systems were analyzed as an element of standard interpretation of well logging data along a carbonate formation. The results of permeability determination, with micro-, mezzo- and macrofractures’ presence in the rock taken into consideration, were compared with outcomes of the drill stem tests (DSTs).
Highlights
In modern hydrocarbon prospection, completion and exploitation, attention is focused on detailed characterization of reservoir rocks to limit the risk of new areas for effective exploitation and calculation of reserves
This paper shows how combination of the imaging well logging method (XRMI log) with older, well-known microscopic techniques of calculating micro- and mezzofractures [10] with the support of mercury injection porosimetry (MICP) allows for characterizing fractured carbonates
The estimated total volume of porosity represented by these two classes does not exceed 0.5% of the effective rock porosity calculated during well logging data interpretation
Summary
Completion and exploitation, attention is focused on detailed characterization of reservoir rocks to limit the risk of new areas for effective exploitation and calculation of reserves. Quantitative analysis of capillary pressure curves from mercury injection porosimetry (MICP) allows determination of the genetic type of intergranular pore–micro-fracture systems. The results of macroscopic observations and microscopic laboratory experiments including mercury injection porosimetry allow determination of the character and degree of development of pore–fracture systems, which can be the basis for characterization of rock formation as the reservoir rock. The attention is focused on the characterization of porous/fractured rocks in detail to obtain the best possible tool to calibrate well logs with the use of limited laboratory data. This paper shows how combination of the imaging well logging method (XRMI log) with older, well-known microscopic techniques of calculating micro- and mezzofractures [10] with the support of mercury injection porosimetry (MICP) allows for characterizing fractured carbonates. An example of using the novel micro computed tomography methodology for fracture mapping and characterization is presented in the article [11,12]
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