Detailing the Pore Structure of Productive Intervals of Oil Wells Using the Color 3D Imaging

Abstract

The article describes an approach to expanding the methodology for applying hydraulic fracturing in oil fields by adding the possibilities of 3D modeling with color imaging of the pore structure of the productive intervals of wells. As an applied example, the geological and geophysical section of the productive level of one of the wells of the Moscudinskoye oil field, with known data on the integrated interpretation of the results of well-logging and microcomputer tomography, was chosen. According to well-logging data, the productive reservoir in the analyzed section of the section is characterized by a high degree of heterogeneity. Tomographic studies of a full-size core made it possible to identify four lithotypes here with different pore structure features. Accounting for the identified reservoir heterogeneity, as well as data on the thickness and other characteristics of reservoir properties of individual lithotypes that make up the section, made it possible to significantly increase the detail of the final geological model of the wellbore section. A distinctive feature of this final geological model is the use of the method of enlargement of the initial data array by adding intermediate values that were calculated theoretically. The visibility of the final geological model of the borehole walls is provided by color 3D imaging of the calculated data of the enlarged massif and makes it possible to judge the presence of areas with good and weak fluid conductivity on the lateral surface of the borehole walls. According to this model, intrastratal transverse and longitudinal fluid-conducting “corridors” are observed in the circumwell zone that determine the hydro-dynamic movements of natural and artificial fluids in the space of productive reservoirs.

Substantiation of Drilling Parameters for Undermined Drainage Boreholes for Increasing Methane Production from Unconventional Coal-Gas Collectors

“…The peculiarity of technogenic gas reservoirs is the complication of geomechanical conditions caused by the dynamic component of the support pressure when implemented in the transition from the vault theory ("O" circle theory) [16][17][18] to more advanced theories, taking into account the phenomenon of Oparin's "zonal disintegration" of rocks, a discrete and fractal array in the area of lead fracturing [19][20][21][22] (probably with the account of the mathematical apparatus of nonlinear dynamics-solitons, attractors). One of the most debatable areas is the prediction of zones with different parameters of the filtration channels "methane drainage zone" [23][24][25], which provide a decaying metastable solid gas-coal solution and the boundaries (angles of complete displacement) [26][27][28][29] for real conditions of reserve development. For this purpose, a commercial software, which implements numerical simulation methods, such as the finite element method (FEM) in COSFLOW [30,31], CFD gas flow in ANSYS [32,33], CMG-GEM [34], PFC2D [35], finite differential method (FDM) in FLAC3D [36], discrete models [37] (such as UDEC [38,39]), and physical simulation with equivalent materials [40], is widely used.…”

Application of Micro-Seismic Monitoring in Post-Fracturing Evaluation of Shale Gas: A Case Study of Well X from Puguang Area, China

“…To evaluate the effectiveness of post-fracturing, commonly used methods include micro-seismic imaging, fiber optic monitoring, conductive fracture-imaging technology, and so on [10][11][12][13][14]. Micro-seismic monitoring is a direct measurement method for determining the geometric parameters of fractures.…”