CC BY
15
Arctic
Environmental Research
Arctic Environmental Research 20(1): 37-42 UDC 550.822.2:004.94 DOI 10.3897/issn2541-8416.2020.20.1.37
Analysis of the core microstructure of terrigenic reservoirs based on lithological-petrographic studies to support the creation of digital core model
IP Belozerov1, MG Gubaidullin1, AV Yuriev2
1 Higher School of Power Engineering, Oil and Gas, Northern (Arctic) Federal University named after M.V. Lomonosov, Arkhangelsk, Russia
2 OAO "LUKOIL-engineering", Perm, Russia
Corresponding author: Ivan Belozerov (i.belozerov@narfu.ru)
Academic editor: Aleksandr I. Malov ♦ Received 30 April 2020 ♦ Accepted 29 May 2020 ♦ Published 2 November 2020
Citation: Belozerov IP, Gubaidullin MG, Yuriev AV (2020) Analysis of the core microstructure of terrigenic reservoirs based on lithological-petrographic studies to support the creation of digital core model. Arctic Environmental Research 20(1): 37-42. https:// doi.org/10.3897/issn2541-8416.2020.20.1.37
The question of digital core modelling appears highly relevant due to the fact that there is not always a sufficient amount of core material available from studied wells: in some cases, it is not possible to select core material (in case of loose, weakly cemented rocks); in others, such material may be completely absent. In order to create a computer model of a digital core, it is necessary to have a correct understanding of the pore space microstructure and rock lithological composition and structure, among the most important features determining the quality of sedimentary reservoir rocks. Such information can be obtained by carrying out lithological-petrographic studies of thin sections of reference (standard) core samples.
The aim of the present work is to study petrographic thin sections for their further use in creating a digital core model. The article discusses the methodology and results of laboratory lithological and petrographic studies of thin sections using the available core information.
The paper presents the results of laboratory studies of thin sections of terrigenous sandstones obtained from the Berea Sandstone formation (USA). The choice of the Berea Sandstone is due to its wide recognition by specialists, as well as its homogeneity, both in terms of the grain size of constituent rocks and their filtration and reservoir properties. The work also presents the results of data analysis on lithological and petrographic studies of core material from the terrigenous deposits obtained in the Timan-Pechora province in northern Russia.
The research results can be used for mathematical modelling of the pore space microstructure in a digital core model.
Abstract
Copyright Belozerov IP et al. This is an open access article distributed under the terms of the Creative Commons Attribution License (CC-BY 4.0), which permits unrestricted use, distribution, and reproduction in any medium, provided the original author and source are credited.
Keywords
computer modelling, digital core, lithological and pétrographie studies, lithological composition, pétrographie thin sections, pore space microstructure, sandstone, Terrigenous reservoirs
Introduction
Currently, digital core modelling technology is a popular and developing direction in the assessment of geological oil reserves. The use of this technology is recommended as a supplement to physical laboratory studies, providing a fast and efficient way to model rock properties by extracting information from 3D images (Belozerov et al. 2017).
Attempts to use this technology in practice have mainly been undertaken in the last decade, although the first results of its application to the analysis of reservoir rocks were obtained in the 1980s (Mavko et al. 2003). The development and creation of a digital core in the future will reduce the need for a large number of laboratory experiments and shorten research periods, as well as solving a number of prospecting and exploration tasks allowing the computational recreation of the hydrodynamic picture and real reservoir conditions of a particular field to an acceptable error tolerance (Gubaidullin et al. 2017).
In order to create a digital core model, it is expedient to have some prior information concerning a number of petrophysical characteristics (porosity, permeability, granulometric composition of rocks, etc.), as well as the hydrodynamic and lithologi-cal-petrographic parameters of rocks. Based on the obtained parameter values, a digital model of the porous medium is created.
Materials and methods
At the first stage of the study, ten standard size core samples were obtained from sandstone obtained from the terrigenous Berea Sandstone (USA) deposit. The reason for selecting test samples from this deposit is due to these sandstones being widely recognised and considered advantageous by specialists in the oil
industry for conducting applied research and testing various technologies. These rocks have minimal filtration anisotropy and reservoir properties, relatively high porosity and permeability, as well as homogeneous grains of constituent rocks and good sorting. Based on the studied samples, the values of the main filtration-capacity properties were determined. Filtration studies were additionally carried out in order to obtain the dependences of fluid permeability coefficients on temperature.
For detailed characterisation of sandstones, silt-stones and clayey rocks, as well as clarification of the combination of granulometric elements in them, various granulometric analysis methods are used for studying rock structures using thin sections under a microscope (Khanin 1969). In order to obtain such information, a petrographic description of 10 thin sections of the terrigenous Berea Sandstone deposit was carried out. The sections were made from the available core material at random, since the rocks were quite homogeneous in their material composition.
The studied rocks are represented by light grey sandstones of medium-fine-grained, fine-medium-grained, predominantly appearing as reservoirs of moderately useful capacity with pore type III class (Khanin 1969). Their porosity, according to the data of petrophysical analyses, varies in the range of 17-20% (for thin sections up to 15%). The determination of porosity from thin sections is carried out according to the generally accepted methods used in the description of petrographic thin sections.
In terms of material composition, the rocks are characterised by quartz content of 70-85%, feldspars 2-5%, rock fragments of various genesis 10-20%, mica 1-2%. Mixed cement: locally developed contact type cementation with conformal contacts of individuals; regenerative quartz does not exceed 1%; clay pore-film cement 2-5%; authigenic carbonate acts as pore corrosive cement (2-5%).
It should also be noted that the increased porosity in these rocks is due to the quartz grains and other fragments being packed less densely on ac-
count of their irregular and semi-rounded shape. The results of studies of thin sections are presented in Table 1.
Table 1. Results of studies of thin sections
Section No.
Porosity,% by thin sections,%
Grain size, mm
Sorting
Brief lithological description
Photo of thin sections
5
10
0.22-0.40
good
Fine-medium-grained oligomictic quartz sandstone with combined cement, pigmented with bitumen, porous. The spotty texture is due to the uneven pigmentation of the BOM. The structure is psammitic fine-medium-grained.
Magnification x100. Polarised light.
Up to 15
0.20-0.45
good
Fine-medium-grained oligomictic quartz sandstone with combined cement, pigmented with bitumen, porous. The spotty texture is due to the uneven pigmentation of the BOM, porous. The structure is psammitic fine-medium-grained.
Magnification x100. Daylight.
good
Medium-fine-grained oligomictic quartz sandstone with contact type cementation (compaction), porous carbonate cement, rare quartz regeneration cement, spotty oil-saturated. The spotty texture is due to the uneven distribution of carbonate material and BOM. The structure is psammitic, medium-fine-grained.
Magnification x25. Polarised light.
Medium
Fine-medium-grained oligomictic quartz sandstone with combined cement, unevenly oil-saturated. The texture is spotty. The structure is psammitic fine-medium-grained.
Magnification x100. Polarised light.
Medium
Fine-medium-grained oligomictic quartz sandstone with combined cement, pigmented with bitumen, porous. The texture spotty is due to the pigmentation of the BOM. The structure is psammitic fine-medium-grained.
Magnification x100. Daylight.
2
3
4
6
2
3
10
2
3
4
5
6
5
10
Section No. Porosity,% by thin sections,% Grain size, mm Sorting Brief lithological description Photo of thin sections
6 10-12 0.22-0.35 Medium Fine-medium-grained oligomictic quartz sandstone with contact-type cementation, areas with pore-type carbonate cement, pigmented with bitumen. The texture is spotty. The structure is psammitic fine-medium-grained. Magnification x100. Polarised light.
7 10-15 0.15-0.32 Medium Medium-fine-grained oligomictic quartz sandstone with contact type cementation, quartz regeneration cement, locally with porous carbonate cement, spotty oil-saturated. The spotty texture is due to uneven oil saturation. The structure is psammitic, medium-fine-grained. Magnification x100. Daylight.
1 2 3 4 5 6
8 10 0.25-0.35 good Medium-grained oligomictic quartz sandstone with contact type cementation, sporadically with porous carbonate cement and quartz regeneration cement. The texture is spotty. The structure is psammitic, medium-grained. Magnification x100. Polarised light.
9 10 0.25-0.40 good Medium-grained oligomictic quartz sandstone with contact type cementation, quartz regeneration cement, sporadically with chlorite-hydromica cement of film-porous type. The texture is unclear. The structure is psammitic, medium-grained. Magnification x100. Daylight.
10 10-12 0.22-0.40 good Medium-grained oligomictic quartz sandstone with combined cement, pigmented with bitumen, porous. The spotty texture is due to the pigmentation of the BOM. The structure is psammitic, medium-grained. Magnification x100. Polarised light.
In addition to lithological and petrographic stud- rocks for five deposits of the Timan-Pechora provies of rocks from the Berea Sandstone formation, an ince was carried out in order to identify the main fac-analysis of the lithological and petrographic data of tors that determine the porosity and permeability of
terrigenous reservoirs. Based on the analysis, it was found that the grain size of rock-forming minerals is one of the main factors.
By definition, rock porosity corresponds to spaces in a rock that are free of the solid mineral phase (Ma-lysheva 1993), i.e. theoretically, grain size should not affect porosity. This is evidenced by the lack of a direct relationship between the grain size distribution and porosity (Fig. 1). Rocks of different granulomet-ric composition can have the same porosity.
--------------[------
: * ♦♦ t
♦
♦ \ 1
I ♦
0,00 0.20 0,40 0,60 0,30 1,00 1,20 L,40 Average '::; :: i size nun
Fig. 1. Dependence of open porosity on the average grain size of the studied rocks
The permeability coefficient of terrigenous rocks is influenced by: granulometric composition of rocks, sorting, grain shape and packing (Mikhailov 2006). The reservoir properties are also influenced by the composition and content of the cementing material.
Results
In the course of the analysis, it was revealed that the more homogeneous the rocks in terms of particle size, the higher the porosity. This is also evidenced by the data published in (Amosova 2000). It follows that the porosity of a containing space consisting of identical spheres with cubic packing is 47.6%, while with the densest rhombohedral packing, the porosity is 25.96%. In both cases, the deviation of individual spheres from the total size will be accompanied by a decrease in porosity: the greater the porosity, the lower the sorting (homogeneity) of fragments. This
is due to the fact that small fragments are located in large pores (Amosova 2000).
No direct relationship was found between grain size and porosity. The degree of porosity and permeability is influenced by the degree of roundness of the clastic material. Thus, rock fragments of irregular shape and semi-rounded particles are packed less densely, leading to an increase in porosity.
As a rule, the more heterogeneous the sandstone is in terms of the size of its particles, the lower is its porosity, since fine grains clog the pores of the sand formed by large particles (Mikhailov 2006). Such rocks exhibit good sorting of clastic material.
Discussion
For further use in a digital model, the obtained pe-trographic description of thin sections is semantically well-arranged, making it possible to extract meaningful lexemes and apply latent semantic analysis (LSA) as a text processing method. LSA is a natural language information processing technique that analyses the relationship between a collection of documents and the terms used in them (Susan 2005). In future, this will allow the context-dependent values of lexemes to be extracted from the description for the subsequent clustering of thin sections according to their photographs using machine learning methods, and, thus, to extract information essential for the model of the core microstructure from available petrographic information derived from the reports on the core studies.
Due to the grain size of rock-forming minerals being one of the main factors determining the porosity and permeability of terrigenous reservoirs, the microstructure of the rock technology can be modelled by packing spheres with the same size distribution as the size distribution of the grains of the modelled rock. For a more efficient construction of rock microstructure during modelling, elements other than spheres should be considered, for example, sphe-ro-polyhedrons, since, in the studied rocks, quartz grains and rock fragments having an irregular shape and semi-rounded particles are packed less densely, leading to an increase in porosity.
References
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