Evaluation of filtration-capacitive properties of complex reservoir rocks using the results of core microtomography

2019 ◽  
pp. 86-88
Author(s):  
S.R. Bembel ◽  
◽  
V.M. Aleksandrov ◽  
A.A. Ponomarev ◽  
P.V. Markov ◽  
...  
Keyword(s):  
Reservoir Rocks ◽  
Capacitive Properties

scholarly journals Prediction of filtration and capacitive properties and oil saturation characteristics of complex structure carbonate reservoirs (on the example of the Northwestern part of DDB)

2020 ◽  
pp. 78-87
Author(s):  
O. V. Oliinyk ◽  
S. A. Vyzhva ◽  
V. V. Antoniuk ◽  
I. M. Bezrodna
Keyword(s):  
Gamma Ray ◽  
Complex Structure ◽  
Well Logging ◽  
Carbonate Reservoir ◽  
Donets Basin ◽  
Northwestern Part ◽  
Oil Saturation ◽  
Reservoir Rocks ◽  
Capacitive Properties ◽  
Carbonate Deposits

The world achievements of the study of carbonate reservoir rocks with secondary voids have been analyzed. An integrated approach to the study of this type of reservoir has been demonstrated on the example of reservoir rocks of the Visean strata of the South-Berestivske field in the North-Western part of the Dnipro-Donets Basin. The purpose of this article is to predict the reservoir filtration-capacitive properties, as well as oil saturation characte-ristics of complex carbonate reservoir rocks using well logging data. To solve this problem, an integrat-ed approach is used. It includes the methods of porosities balance and functional transformations (normalization) of the electrical and radioactive well logging curves (lateral logging - neutron gamma ray logging, impulse neu-tron-neutron logging - neutron gamma ray logging). As a result, the authors have identified intervals in the Visean carbonate deposits with cavernous voids and cracks. Each individual geophysical method is influenced by the structure of the void space. Due to this, when calculating the porosity coefficient for different probes, the au-thors identify intervals represented by carbonate deposits, mainly of the porous-cavernous type. However, there is an interval of 4287.6-4289.6 m of porous-cavernous-fractured type. It is established that in the selected layers the coefficients of different types of porosity are: secondary - 2.5-6%, cavernous - 1.7-5% and fracture -0.2%. The thickness of pro-ductive sediments varies within 0.8 - 2.4 m (the average value is 2 m). The authors also substantiated the choice of parameters when calculating the saturation coefficient in complex structural reservoirs. Moreover, it is noted that the reservoir properties are provided by the presence of secondary voids, namely the cavities through which the fluid is filtered, and the rock matrix is compacted, poor-porous and low-permeable.

Silurian carbonate reservoir rocks of the joint zone of the Khoreyver depression and the Chernyshev ridge

2021 ◽  
Vol 3 ◽  
pp. 41-48
Author(s):  
I.I. Danshchikova ◽  
◽  
T.V. Maidl ◽  
A.V. Zhuravlev ◽  
V.S. Nikiforova ◽  
...  
Keyword(s):  
Carbonate Reservoir ◽  
Void Space ◽  
Reservoir Rocks ◽  
Lower Silurian ◽  
Coastal Marine ◽  
First Case ◽  
Capacitive Properties ◽  
Chernyshev Ridge ◽  
Filtration Properties ◽  
Hydrocarbon Deposits

The paper presents a comprehensive study of low-capacity Silurian carbonate reservoir rocks in the northeastern regions of the Timan-Pechora province. Silurian deposits in the sections of the Khosedayu swell, the Talbey block, and the Makarikha-Salyukin anticlinal zone are mainly secondary dolomites and, to a lesser extent, limestones, as well as with low-power interlayers of agrillites, clay dolomites, dolomite-anhydrite rocks. The deposits were formed in coastal-marine and shallow-marine conditions. As a result of the conducted studies, it was noted that dolomites with a shadow biohermal structure have the best filtration properties in the Lower Silurian, and bioclastic limestones – in the Upper Silurian. The reservoir rocks of the Talbey block of the Chernyshev ridge have the best filtration-capacitive properties. The main volume of the void space in the first case is associated with cavities and cracks, in the second one – with matrix porosity. However, the signs of modern karst in the salts of Malo-Tavrotinsky strata observed from the core indicate a possible reformation of the deposits, which requires more careful attention when predicting deposits. The results obtained can contribute to the design of a rational system for the development of hydrocarbon deposits.

scholarly journals Digital core modeling technology for determining the reservoir-capacitive properties of terrigenous reservoirs

2021 ◽  
Vol 1201 (1) ◽  
pp. 012065
Author(s):  
M G Gubaidullin ◽  
I P Belozerov
Keyword(s):  
Core Model ◽  
Core Material ◽  
Reservoir Rocks ◽  
Modeling Technology ◽  
Terrigenous Rocks ◽  
Physical Experiments ◽  
Capacitive Properties ◽  
Digital Core ◽  
Hydrocarbon Fields

Abstract For today digital core modelling technology is demanded and developing instrument in conducting the main reservoir-capacitive properties of terrigenous rocks. This technology is becoming more widespread in connection with the development of computer and nanotechnologies. The main attempts to apply the digital core model in practice have been undertaken in the last decade, although the first examples of its use for the analysis of reservoir rocks date back to the 80s of the last century. Improvement of digital core modeling technology will allow to cope with the problem of lack or absence of core material, as well as to solve the problems of studying loose, weakly cemented and other rocks, "problematic" of conducting physical experiments. In addition, it seems relevant to create a digital core block that fits into the general digitalization platform of technologies related to reservoir-capacitive properties in the development of hydrocarbon fields. With the use of a digital core model, it also becomes possible to effectively refine and supplement the calculated parameters in laboratory core studies, reducing the likelihood of errors in the obtained results.

Enhanced Capacitive Properties of All-solid-state Symmetric Graphene Supercapacitors by Incorporating Nitrogen-doping and SnO$lt;inf$gt;2$lt;/inf$gt; Nanoparticles

2015 ◽  
Vol 30 (6) ◽  
pp. 662 ◽  
Author(s):  
YU Jian-Hua ◽  
XU Li-Li ◽  
ZHANG Wu-Shou ◽  
ZHU Qian-Qian ◽  
WANG Xiao-Xia ◽  
...  
Keyword(s):  
Solid State ◽  
Nitrogen Doping ◽  
Capacitive Properties

Reduction of Polymer Adsorption on Reservoir Rocks

1988 ◽  
Vol 43 (4) ◽  
pp. 533-543 ◽  
Author(s):  
G. Chauveteau ◽  
J. Lecourtier ◽  
L. T. Lee
Keyword(s):  
Polymer Adsorption ◽  
Reservoir Rocks

Stratigraphic Intervals for Oil and Tar Sand Deposits in the Uinta Basin, Utah

2017 ◽  
Vol 54 (4) ◽  
pp. 227-264
Author(s):  
Ronald Johnson ◽  
Justin Birdwell ◽  
Paul Lillis
Keyword(s):  
Brackish Water ◽  
Source Rocks ◽  
Uinta Basin ◽  
Green River ◽  
Reservoir Rocks ◽  
Stratigraphic Framework ◽  
Two Samples ◽  
The Rich ◽  
And Migration ◽  
Almost All

To better understand oil and bitumen generation and migration in the Paleogene lacustrine source rocks of the Uinta Basin, Utah, analyses of 182 oil samples and tar-impregnated intervals from 82 core holes were incorporated into a well-established stratigraphic framework for the basin. The oil samples are from the U.S. Geological Survey Energy Resources Program Geochemistry Laboratory Database; the tar-impregnated intervals are from core holes drilled at the Sunnyside and P.R. Spring-Hill Creek tar sands deposits. The stratigraphic framework includes transgressive and regressive phases of the early freshwater to near freshwater lacustrine interval of Lake Uinta and the rich and lean zone architecture developed for the later brackish-to-hypersaline stages of the lake. Two types of lacustrine-sourced oil are currently recognized in the Uinta Basin: (1) Green River A oils, with high wax and low β-carotane contents thought to be generated by source rocks in the fresh-to-brackish water lacustrine interval, and (2) much less common Green River B oils, an immature asphaltic oil with high β-carotane content thought to be generated by marginally mature to mature source rocks in the hypersaline lacustrine interval. Almost all oil samples from reservoir rocks in the fresh-to-brackish water interval are Green River A oils; however four samples of Green River A oils were present in the hypersaline interval, which likely indicates vertical migration. In addition, two samples of Green River B oil are from intervals that were assumed to contain only Green River A oil. Tar sand at the P.R. Spring-Hill Creek deposit are restricted to marginal lacustrine and fluvial sandstones deposited during the hypersaline phase of Lake Uinta, suggesting a genetic relationship to Green River B oils. Tar sand at the Sunnyside deposit, in contrast, occur in marginal lacustrine and alluvial sandstones deposited from the early fresh to nearly freshwater phase of Lake Uinta through the hypersaline phase. The Sunnyside deposit occurs in an area with structural dips that range from 7 to 14 degrees, and it is possible that some tar migrated stratigraphically down section.

THE BASIC TYPES OF SECONDARY CHANGES IN RESERVOIR ROCKS IN THE TERRITORY OF THE WEST SIBERIA PLATE

2015 ◽  
pp. 26-30
Author(s):  
A. V. Podnebesnykh ◽  
S. V. Kuznetsov ◽  
V. P. Ovchinnikov
Keyword(s):  
Oil Recovery ◽  
West Siberia ◽  
Recovery Factor ◽  
Change Processes ◽  
The West ◽  
Reservoir Rocks ◽  
Tectonically Active ◽  
Porosity And Permeability ◽  
Active Zones ◽  
Regional Character

On the example of the group of fields in the West Siberia North the basic types of secondary changes in reservoir rocks are reviewed. Some of the most common types of such changes in the West Siberian plate territory include the processes of zeolitization, carbonation and leaching. These processes have, as a rule, a regional character of distribution and are confined to the tectonically active zones of the earth's crust. Due to formation of different mineral paragenesises the secondary processes differently affect the reservoir rocks porosity and permeability: thus, zeolitization and carbonization promote to reducing the porosity and permeability and leaching improvement. All this, ultimately leads to a change of the oil recovery factor and hydrocarbons production levels. Study and taking into account of the reservoir rocks secondary change processes can considerably influence on placement of operating well stock and on planning of geological and technological actions.

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