Experience in estimation of reservoir properties trends for carbonate reservoirs in the Khoreyver depression based on the results of a integrate analysis of geological and geophysical data

2021 ◽  
pp. 17-21
Author(s):  
A.E. Desyatnikova ◽  
◽  
P.A. Shakhov ◽  
Keyword(s):  
Geophysical Data ◽  
Carbonate Reservoirs ◽  
Reservoir Properties ◽  
Integrate Analysis

SECONDARY CHANGES IN CARBONATE ROCKS OF OIL AND GAS COMPLEXES

2020 ◽  
pp. 18-23
Author(s):  
M.A. Tugarova
Keyword(s):  
Carbonate Rocks ◽  
Oil And Gas ◽  
Carbonate Reservoirs ◽  
Fundamental Importance ◽  
Schematic Diagram ◽  
Reservoir Properties ◽  
Physico Chemical ◽  
Chemical Conditions ◽  
First Time

The article considers the secondary transformations of carbonate rocks of oil and gas complexes, which are of fundamental importance in the formation of reservoir properties. For the first time, a schematic diagram, illustrating the regularities of secondary processes in carbonate reservoirs and their relationship with the physico-chemical conditions of the stratosphere is proposed.

scholarly journals Diagenetic Processes and Reservoir Heterogeneity in Salt-Encased Microbial Carbonate Reservoirs (Late Neoproterozoic, Oman)

Geofluids ◽  
2019 ◽  
Vol 2019 ◽  
pp. 1-19
Author(s):  
Stephan Becker ◽  
Lars Reuning ◽  
Joachim E. Amthor ◽  
Peter A. Kukla
Keyword(s):  
Carbonate Reservoirs ◽  
Salt Diapir ◽  
Strong Impact ◽  
Field Scale ◽  
Reservoir Properties ◽  
Heterogeneous Distribution ◽  
Near Surface ◽  
Porosity Reduction ◽  
Diagenetic Processes ◽  
The Impact

A common problem in dolomite reservoirs is the heterogeneous distribution of porosity-reducing diagenetic phases. The intrasalt carbonates of the Ediacaran-Early Cambrian Ara Group in the South Oman Salt Basin represent a self-sourcing petroleum system. Depositional facies and carbonate/evaporite platform architecture are well understood, but original reservoir properties have been modified by diagenesis. Some of the carbonate reservoirs failed to produce hydrocarbons at acceptable rates, which triggered this study. The extent of primary porosity reduction by diagenetic phases was quantified using point counting. To visualize the distribution of diagenetic phases on a field scale, we constructed 2D interpolation diagenesis maps to identify patterns in cementation. The relative timing of diagenetic events was constrained based on thin-section observations and stable isotope analyses. Near-surface diagenesis is dominated by reflux-related processes, leading to porosity inversion in initial highly porous facies and a patchy distribution of early cements. This strong diagenetic overprint of primary and early diagenetic porosity by reflux-related cements leads to a reduction of stratigraphic and facies control on porosity. Calcite was identified as a burial-related cement phase that leads to an almost complete loss of intercrystalline porosity and permeability. Bitumen is an important pore-occluding phase and time marker of the deep-burial realm. The stratigraphic position of the dolomite reservoirs embedded at the base of a salt diapir had a strong impact on its diagenetic development. The salt isolated the dolomites from external fluids, leading to a closed system diagenesis and the buildup of near lithostatic fluid pressures. In combination, these processes decreased the impact of further burial diagenetic processes. The study highlights that cement distribution in salt-encased carbonate reservoirs is mainly related to early diagenetic processes but can be very heterogeneous on a field scale. Further work is needed to implement these heterogeneities in an integrated numerical reservoir model.

scholarly journals Physical and reservoir properties prediction for reservoir rocksin unconventional gas-bearing geological structures

2014 ◽  
pp. 35-40 ◽  
Author(s):  
L. Skakal's'ka
Keyword(s):  
Mechanical Properties ◽  
Elastic Waves ◽  
Elastic Moduli ◽  
Physical And Mechanical Properties ◽  
Geophysical Data ◽  
Reservoir Properties ◽  
Empirical Relationships ◽  
Geological Structures ◽  
Wave Velocities ◽  
Gas Bearing

Research into the behavior of elastic waves in thin-layered gas-bearing geological structures depends on the choice of geophysical and mathematical models of natural geological media and the numerical methods of problem solving. Hence the efficiency of a quasi-homogeneous, isotropic fractured-porous two-phase medium with given physical and mechanical properties. We have suggested a method of calculating empirical relationships between volumetric compression, porosity and pressure in porous rocks of an arbitrary geological region. Data on Zaluzhany wells were used to calculate the correlation and empirical relationships between reservoir properties and parameters of elastic waves and to distinguish dry and oil-gas saturated rocks. The least square technique made it possible to determine the correlation between the compressibility factor of fluid-saturated rocks and their porosity and pressure. Discrimination between oil and water was based on the density parameter. An algorithm has been suggested to do the corresponding calculations. The theoretical and practical implications of this study are as follows: – developing a numerical analytical predictive model for interpreting acoustic data on thin-layered rocks which is based on the correlations between their dynamic physical (effective wave propagation velocities, amplitude attenuation coefficients and their energy absorption) and reservoir (porosity, fracturing, compressibility) properties; – applying the proposed model and software products in geophysical exploration to interpret the geological and geophysical data on the structure and physical characteristics of sections and the physical properties of gas-bearing basins. In seismic acoustic exploration, the numerical model has to include experimental geological and geophysical data on the peculiarities of rock occurrence in the investigated area, with the physical and mechanical properties of different territories showing considerable variation. Such input data, as well as structural features and scattering properties of rocks (density, bedding, microporosity), ensure a significant increase in the accuracy of the numerical analysis. Preliminary testing was based on the data on the elastic moduli and S-wave velocities for dry and fluid-saturated rocks. Calculations were made of the elastic moduli and P-wave velocities for dry and fluid-saturated rocks of the Western oil and gas region of Ukraine (Zaluzhany-18 and Zaluzhany-19 wells). The aim of this work was to demonstrate the efficiency of the predictive method by examining the reservoir rock properties of the wells and to evaluate their gas saturation using the acoustic logging, geophysical and petrophysical data.

scholarly journals Improving the carbonate reservoirs development efficiency on the example of the Tournaisian stage deposits

2021 ◽  
pp. 238-247
Author(s):  
V. A. Grishchenko ◽  
◽  
T. V. Pozdnyakova ◽  
B. M. Mukhamadiyev ◽  
V. V. Mukhametshin ◽  
...  
Keyword(s):  
Methodological Approach ◽  
Geological Structure ◽  
Carbonate Reservoirs ◽  
Oil Fields ◽  
Structure Development ◽  
Reservoir Properties ◽  
Development Indicators ◽  
Geological Factors ◽  
Complex Geological Structure ◽  
Development Analysis

The article deals with the issue of carbonate strata of complex geological structure development efficiency improving. Such facilities, as a rule, have deteriorated reservoir properties, parameter anisotropy and are complicated by secondary cavernosity. All of these factors affect the recovery efficiency and are often reflected in development indicators. On the example of Tournaisian stage deposits an example of a methodological approach to the development analysis which takes into consideration various geological factors is presented. As a result, various dependencies were obtained, which when taken into account determin the most promising areas in terms of development efficiency. The issues of the waterflooding system efficiency and the ways of its efficiency increasing are considered separately. Keywords: oil fields development; carbonate reservoirs; development efficiency; waterflooding system.

Contribution of the ALBION Dynamic Analogue in Understanding the Diversity of Fluid Flows in Fractured Carbonate Reservoirs. The Example of the LSBB Instrumented Site

2021 ◽  
Author(s):  
Danquigny Charles ◽  
Massonnat Gérard ◽  
Barbier Mickaël ◽  
Bouxin Pierre ◽  
Dal Soglio Lucie ◽  
...  
Keyword(s):  
Fractured Rock ◽  
Carbonate Reservoirs ◽  
Reservoir Properties ◽  
Rock Classification ◽  
Multi Scale ◽  
Rock Types ◽  
Fractured Medium ◽  
Fractured Carbonate ◽  
Fractured Limestone

Abstract Carbonate reservoirs exhibit an extreme geological heterogeneity inducing a great diversity of fluids flows. Grasping the plurality of flows and the corresponding geological features require data scarcely available from subsurface hydrocarbons fields and even rarely acquired together on outcrop analogues. Among the different sites of the ALBION R&D project, the LSBB underground research laboratory provides outstanding access to both fractured limestone and groundwater dynamics through several experimental areas, including a 3.8 km long tunnel, which penetrates the Barremian-Aptian Urgonian formation to a maximum depth of 519 m. This paper gives an overview of the data acquired and the different works carried out on the LSBB site. From this synthesis, it draws lessons on the characterization of outcrop analogues and some insights for the modeling of fractured carbonate reservoirs. The quantity and diversity of the data acquired on the LSBB site allow: (i) the construction of nested multi-scale geological models, (ii) the comparison of measurements of different physical properties to better characterize the reservoir properties of the fractured rock, (iii) a multi-scale and multi-support approach to heterogeneity. Defining a common geological framework (facies model, rock type classification, inventory of structural objects, etc.) appears to be an essential step, possibly iterative, for the coupled interpretation of the various acquisitions and the extrapolation of results. Building a common geological model as a framework for interpretation help cross-fertilisation between geoscience domains. However, despite the huge amount of data, performing relevant and parsimonious rock typing remains a delicate exercise. This reminds us of the great uncertainties that can exist in establishing rules and concepts from limited data sets, such as those classically available for operational studies. Beyond the characterization of the depositional environment, the observations emphasize the importance of understanding the structural and diagenetic history, which leads to different rock types and current reservoir properties, to successfully define such a rock classification. Furthermore, the organization of flow paths within the fractured medium and its evolution over geologic time condition the processes of diagenesis and karstification. Hydrological processes and history must therefore be taken into account in this genetic reconstruction.

scholarly journals Biomarker hydrocarbons of oils from the Labagan field of the Timan-Pechora oil and gas province

Georesursy ◽  
2020 ◽  
Vol 22 (1) ◽  
pp. 46-54
Author(s):  
Olga V. Valyaeva ◽  
Nadezhda N. Ryabinkina ◽  
Dmitriy A. Boushnev
Keyword(s):  
Organic Matter ◽  
Lower Devonian ◽  
Oil And Gas ◽  
Carbonate Reservoirs ◽  
Reservoir Properties ◽  
Medium Reservoir ◽  
Reducing Environment ◽  
Geochemical Studies ◽  
Biomarker Hydrocarbons

The results of geochemical studies of four oils samples from Paleozoic deposits of the Labagan field of the Timan-Pechora oil and gas province are presented. It is shown that the organic matter, which generated the oil of the Lower Devonian and Tournaisian deposits of the Labagan field, is sapropelic, its accumulation occurred in a marine sub-reducing environment. The oils of the Artinskian and Ufimian deposits are substantially biodegraded. Type of collectors is fissure-porous, secondary-porous. Carbonate reservoirs of the Devonian, Carboniferous and Permian (Artinian) age are characterized by good and medium reservoir properties. Terrigenous reservoirs of the Ufimian deposit have good reservoir properties.

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