THE DEGREE OF INFLUENCE OF A FORMATION FLUSHING MULTIPLICITY FACTOR ON THE OIL RECOVERY FACTOR FROM THE DEPOSITS OF THE FERGANA OIL- AND GAS-BEARING AREA, REPRESENTED BY CARBONATE ROCKS

2020 ◽  
pp. 41-47
Author(s):  
A.Kh. Agzamov ◽  
◽  
N.Kh. Ermatov ◽  
A.A. Agzamov ◽  
Kh.M. Mukhammadiev ◽  
...  
Keyword(s):  
Oil Recovery ◽  
Carbonate Rocks ◽  
Oil And Gas ◽  
Recovery Factor ◽  
Multiplicity Factor ◽  
Gas Bearing

scholarly journals Prospects and Forecasting of Deep-Seated Oil and Gas Reservoirs of the Meso-Ceno Deposits of Azerbaijan

2020 ◽  
Vol 4 (2) ◽  
pp. 1-3
Author(s):  
Sultanov LA
Keyword(s):  
Carbonate Rocks ◽  
Oil And Gas ◽  
Petrophysical Properties ◽  
Gas Reservoirs ◽  
Geological Material ◽  
Oil And Gas Reservoirs ◽  
Petrophysical Data ◽  
Exploratory Wells ◽  
The Republic ◽  
Gas Bearing

Recently, in the Republic has been deploying drilling explorations from the eastern part to less studied central and western areas. In this reason, had a particular importance the generalization of the available geological and geophysical materials related to the new focus territory, the evaluation of the prospects of individual lithologic-stratigraphic complexes and the forecasting of deep-seated oil and gas reservoirs. Studies carried out in this direction are given in this paper, which describes the analysis of different petrophysical data. At the same time were re-interpreted reservoir and petrophysical properties of rocks, mesocenozoic deposits taken from the drilled exploratory wells and geological material of the areas of oil and gas bearing area, where are widely distributed deposits of the productive strata (PT-lower Pliocene). As a result of analysis and interpretation of geological, geophysical and petrophysical date, it has been established that oil-and- gas-bearing reservoirs are mainly fractured volcanogenic-sedimentary and carbonate rocks.

scholarly journals Ocena efektywności ekonomicznej procesu WAG na podstawie danych eksperymentalnych dla jednego z krajowych złóż ropy naftowej

Nafta-Gaz ◽  
2021 ◽  
Vol 77 (2) ◽  
pp. 75-81
Author(s):  
Mirosław Wojnicki ◽  
◽  
Jerzy Kuśnierczyk ◽  
Sławomir Szuflita ◽  
Marcin Warnecki ◽  
...  
Keyword(s):  
Oil Recovery ◽  
Oil And Gas ◽  
Recovery Factor ◽  
Recovery Method ◽  
Waste Gas ◽  
Natural Gases ◽  
Acidic Gases ◽  
Water Alternating Gas ◽  
Dolomite Formation ◽  
Carbonate Formations

The challenge related to the need for an increase of the recovery factor concerns numerous mature, also domestic oilfields, including the most important ones – located in Main Dolomite formation. Satisfactory recovery factor can be ensured only through applying an effective enhanced oil recovery method (EOR). Water Alternating Gas (WAG), as one of the most effective EOR methods, has been tested in conditions characteristic for domestic deposits in carbonate formations. The results of experimental and simulation works carried out at the Oil and Gas Institute (INiG – PIB) indicate significant potential for the application of the WAG method in domestic conditions. An unquestionable advantage of the WAG method is the opportunity to utilize various types of gases, including flue/waste gas or low-energy natural gas. This issue deserves special attention because, as we know, the reduction in the emissions of gases involved in global warming is critical for the future of our planet. Their utilization in EOR methods, coupled with their safe storage in geological structures, constitute measures that reduce the environmental footprint of produced oil. In the article, based on the of experimental results, a simplified economic analysis of the utilization of four gas types in the form of acidic gases (carbon dioxide and its mixture with hydrogen sulfide) and natural gases (high and very high nitrogen content) in the WAG method was carried out. That allowed to identify the most economically optimal variants of the WAG method. The results showed that despite significantly lower effectiveness of nitrogen-rich natural gases in enhancing oil recovery (in the context of recovery factor), their application might be justified in economic terms. The selection of the optimal variant for enhancing recovery is strongly influenced by the assumed (current) cost of acquiring the injected media, and of course by the current (and forecasted) crude oil price.

scholarly journals INFLUENCE OF BUSINESS DIGITALIZATION ON THE OIL RECOVERY FACTOR AND IMPROVING THE EFFICIENCY OF THE OIL AND GAS COMPANIES ACTIVITY

2019 ◽  
pp. 73-79 ◽  
Author(s):  
A. D. Balashova ◽  
O. I. Bolshakova
Keyword(s):  
Oil Recovery ◽  
Government Regulation ◽  
Industrial Revolution ◽  
Oil And Gas ◽  
Recovery Factor ◽  
Effective Management ◽  
Fourth Industrial Revolution ◽  
Operational Management ◽  
Oil And Gas Companies ◽  
Hydrocarbon Reserves

Against the background of the decline structure of hydrocarbon reserves in Russia, the maintenance of a stable level of production and enhanced oil recovery at mature fields is associated with the introduction of technologies of the fourth industrial revolution (Industry 4.0). The real and possible impact of digitalization on the oil recovery factor and impact of the technological solutions on the development hard-to-recover reserves have been сonsidered in the article. Special attention has been paid to the transition to intellectual methods of management, within the framework of digitalization, which ensure the effective management for all company’s processes, provide objective and transparent information for making accurate and operational management decisions. To ensure a significant effect from the digital transformation of the industry, it is necessary to create favorable investment conditions, including government regulation and stimulation.

scholarly journals Experimental Study on Enhanced Condensate Recovery by Gas Injection in Yaha Condensate Gas Reservoir

Geofluids ◽  
2021 ◽  
Vol 2021 ◽  
pp. 1-15
Author(s):  
Yiming Wu ◽  
Kun Yao ◽  
Yan Liu ◽  
Xiangyun Li ◽  
Mimi Wu ◽  
...  
Keyword(s):  
Oil Recovery ◽  
Recovery Rate ◽  
Oil And Gas ◽  
Gas Injection ◽  
Recovery Factor ◽  
Co2 Injection ◽  
Gas Reservoirs ◽  
Gas Reservoir ◽  
Injection Method ◽  
Production Ratio

A condensate gas reservoir is an important special oil and gas reservoir between oil reservoir and natural gas reservoir. Gas injection production is the most commonly used development method for this type of gas reservoir, but serious retrograde condensation usually occurs in the later stages of development. To improve the recovery efficiency of condensate oil in the middle and late stages of production of a condensate gas reservoir, a gas injection parameter optimization test study was carried out, taking the Yaha gas condensate reservoir in China as an example. On the premise that the physical experimental model and key parameters met the actual conditions of the formation, the injection method, injection medium, injection-production ratio, and other parameters of the condensate gas reservoir were studied. Research on the injection method showed that the top injection method had a lower gas-oil ratio and higher condensate oil recovery. The study of injection medium showed that the production effect of carbon dioxide (CO2) injection was the best injection medium, and the maximum recovery rate of condensate oil was 95.11%. The injection-production ratio study showed that the injection-production ratio was approximately inversely proportional to the recovery factor of condensate gas and approximately proportional to the recovery factor of condensate oil. When the injection-production ratio was 1 : 1, the maximum recovery rate of condensate oil was 83.31%. In summary, in the later stage of gas injection development of the Yaha condensate gas reservoir, it was recommended to choose the development plan of CO2 injection at the top position with an injection-production ratio of 1 : 1. This research can not only provide guidance for the later formulation of gas injection plans for Yaha condensate gas reservoirs but also lay a foundation for the research of gas injection migration characteristics of other condensate gas reservoirs.

scholarly journals Hydrothermal-metasomatic systems as the most important factor for the formation of elements of the oil and gas-bearing complex in the Bazhenov-Abalak sediments

Georesursy ◽  
2021 ◽  
Vol 23 (2) ◽  
pp. 142-151
Author(s):  
Evgenia V. Karpova ◽  
Aleksey O. Khotylev ◽  
Ekaterina A. Manuilova ◽  
Aleksandr A. Mayorov ◽  
Elizaveta A. Krasnova ◽  
...  
Keyword(s):  
Carbonate Rocks ◽  
Oil And Gas ◽  
Pore Space ◽  
Structural Elements ◽  
Mineral Formation ◽  
Reservoir Properties ◽  
Thin Sections ◽  
The Impact ◽  
Gas Bearing ◽  
Scanning Electron

A model of the activity of hydrothermal-metasomatic systems confined to certain structural elements is proposed in the present article. The model is based on the analysis of a large volume of traditional studies: measurements of porosity coefficients, permeability, pyrolytic measurements - together with specific measurements: isotopic composition of carbonate rocks, temperature of homogenization of gas-liquid inclusions, studies of the composition of rocks with a scanning electron microscope, a description of petrographic thin sections. The model allows to generalize the results of the impact of hydrothermal-metasomatic systems on the reservoir properties of the rocks of the Bazhenov-Abalak complex: constructive – leaching processes and increasing reservoir properties, and destructive – massive mineral formation that fills the pore space, up to the formation of secondary seals.

scholarly journals GEOTHERMAL ZONALITY OF OIL AND GAS BEARING DEPOSITS IN THE NORTH-WESTERN TERRITORY OF NOVOSIBIRSK REGION

2018 ◽  
pp. 69-76 ◽  
Author(s):  
D. A. Novikov ◽  
S. V. Ryzhkova ◽  
F. F. Dultsev ◽  
A. V. Chernykh
Keyword(s):  
Ground Water ◽  
Carbonate Rocks ◽  
Oil And Gas ◽  
Northern Territory ◽  
Paleozoic Basement ◽  
The North ◽  
Novosibirsk Region ◽  
Jurassic Rocks ◽  
Gas Bearing ◽  
North Western

The article is devoted to the approach to geothermal zonality. The results of geothermal studies of oil and gas bearing deposits in the northern territory of Novosibirsk region and adjacent areas are presented. Geothermal zoning was carried out, and the major geothermal anomalies were determined. The features of the geothermal zonality of Mesozoic sediments in the region under investigation are first of all defined by the material composition of the Paleozoic basement, the structural arrangement, and the warming effect of ground water during its crossflows from deeper lying horizons. Formation temperatures get leveled within the boundaries of Aptian-Albian-Cenomanian sediments, and no anomalies are distinguished. The highest geothermal gradients sup to 3,6-4,6 °C/100 m and correspond to the edge zones of the development of intrusive formations of pre-Jurassic rocks. Lower gradients sup to 2,4-3,0 °C/100 m and characterize the regions, in which Paleozoic carbonate rocks occur.

Micro-Emulsion Phase Behavior of a Cationic Surfactant at Intermediate Interfacial Tension in Sandstone and Carbonate Rocks

2015 ◽  
Vol 137 (1) ◽  
Author(s):  
Mahmood Reza Yassin ◽  
Shahab Ayatollahi ◽  
Behzad Rostami ◽  
Kamran Hassani ◽  
Vahid Taghikhani
Keyword(s):  
Phase Behavior ◽  
Relative Permeability ◽  
Oil Recovery ◽  
Carbonate Rocks ◽  
Recovery Factor ◽  
Surfactant Flooding ◽  
Permeability Ratio ◽  
Micro Emulsion ◽  
Winsor Type Iii ◽  
Optimum Salinity

Based on the conventional approach, the trapped oil in rock pores can be easily displaced when a Winsor type (III) micro-emulsion is formed in the reservoir during surfactant flooding. On the other hand, the Winsor type (III) involves three phase flow of water, oil, and micro-emulsion that causes considerable oil phase trapping and surfactant retention. This work presents an experimental study on the effect of micro-emulsion phase behavior during surfactant flooding in sandstone and carbonate core samples. In this study, after accomplishing salinity scan of a cationic surfactant (C16–N(CH3)3Br), the effects of Winsor (I), Winsor (III) and Winsor (II) on oil recovery factor, differential pressure drop, relative permeability, and relative permeability ratio were investigated extensively. To carry out a comparative study, homogeneous and similar sandstone and carbonate rocks were selected and the effects of wettability alteration and dynamic surfactant adsorption were studied on them. The results of oil recovery factor in both rock types showed that Winsor (I) and Winsor (III) are preferred compared to Winsor (II) phase behavior. In addition, comparison of normalized relative permeability ratio at high water saturations revealed that Winsor (I) has more appropriate oil and water relative permeability than Winsor (II). The results presented in this paper demonstrate that optimum salinity which results in higher recovery factor and better oil displacement may occur at salinities out of Winsor (III) range. Therefore, the best way to specify optimum salinity is to perform core flood experiments at several salinities, which cover all phase behaviors of Winsor (I), Winsor (III), and Winsor (II).

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