KFU. Card publication. Traditional and precision methods for studying porous space of oil-bearing formation (Russian)

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FEDERAL UNIVERSITY

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TRADITIONAL AND PRECISION METHODS FOR STUDYING POROUS SPACE OF OIL-BEARING FORMATION (RUSSIAN)

Form of presentation

Articles in Russian journals and collections

Year of publication

2017

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Authors, employees of KFU

Kadyrov Rail Ilgizarovich, author

Bibliographic description in the original language

Sungatullin R.K. et al. Traditional and precision methods for studying porous space of oil-bearing formation (Russian) // Oil Ind. J. Oil Industry Journal, 2017. Vol. 2017, � 11. P. 89–91.

Annotation

At present, the coefficient of porosity is traditionally determined by the method of Preobrazhensky and by the results of a petrophysical interpretation of well log data. However, there are many examples of the significant error in its determination, which ultimately affects the determination of their filter-capacitance properties, the recovery rate of oil and extracted reserves. In this paper, the porosity coefficients are compared by traditional and precision methods for oil-containing terrigenous reservoirs of the Paschian (Upper Devonian), and Tula and Bobrikovskian (Lower Carboniferous) horizons, as well as carbonate reservoirs of the Tournaisian stage, using the example of one of the deposits in the central part of the Volga-Ural oil and gas province. It is shown that precision methods make it possible to study in more detail the internal pore space of oil-containing reservoirs. X-ray computer microtomography showed the uneven and multidimensional porosity of Devonian sandstones, due to their micro-lamination. The most accurate values of the porosity coefficient from the results of microtomography were obtained for cubes of the smallest size (with linear dimensions of the sample less than 5 mm), so they correspond to a higher resolution of the survey, which allows detecting smaller pores. In this connection, the inverse dependence of the porosity coefficient on the size of the samples was established. Variability of porosity along the layers in the lateral direction is revealed (the property of 'microfaciality'). The combination of traditional and precision methods for determining porosity coefficients will allow us to calculate the oil recovery factor on explored and developed oil deposits more correctly, because additional information on pore size and cavity, connectivity and type of channels, as well as microfacies are taken into account.

Keywords

ArcGIS, Devonian period, Lower Carboniferous period, Porosity, Reservoir, Volga-Ural oil and gas bearing province, X-ray CT

The name of the journal

Neftyanoe khozyaystvo - Oil Industry

URL

https://www.scopus.com/record/display.uri?eid=2-s2.0-85034985322&origin=resultslist&sort=plf-f&src=s&st1=&st2=&sid=5e934ba82f93b8dc775c38217688610e&sot=b&sdt=b&sl=99&s=TITLE-ABS-KEY%28Traditional+and+precision+methods+for+studying+porous+space+of+oil-bearing+formation%29&relpos=0&citeCnt=0&searchTerm=

Please use this ID to quote from or refer to the card

https://repository.kpfu.ru/eng/?p_id=250600&p_lang=2

Full metadata record

Field DC	Value	Language
dc.contributor.author	Kadyrov Rail Ilgizarovich	ru_RU
dc.date.accessioned	2017-01-01T00:00:00Z	ru_RU
dc.date.available	2017-01-01T00:00:00Z	ru_RU
dc.date.issued	2017	ru_RU
dc.identifier.citation	Sungatullin R.K. et al. Traditional and precision methods for studying porous space of oil-bearing formation (Russian) // Oil Ind. J. Oil Industry Journal, 2017. Vol. 2017, � 11. P. 89–91.	ru_RU
dc.identifier.uri	https://repository.kpfu.ru/eng/?p_id=250600&p_lang=2	ru_RU
dc.description.abstract	Neftyanoe khozyaystvo - Oil Industry	ru_RU
dc.description.abstract	At present, the coefficient of porosity is traditionally determined by the method of Preobrazhensky and by the results of a petrophysical interpretation of well log data. However, there are many examples of the significant error in its determination, which ultimately affects the determination of their filter-capacitance properties, the recovery rate of oil and extracted reserves. In this paper, the porosity coefficients are compared by traditional and precision methods for oil-containing terrigenous reservoirs of the Paschian (Upper Devonian), and Tula and Bobrikovskian (Lower Carboniferous) horizons, as well as carbonate reservoirs of the Tournaisian stage, using the example of one of the deposits in the central part of the Volga-Ural oil and gas province. It is shown that precision methods make it possible to study in more detail the internal pore space of oil-containing reservoirs. X-ray computer microtomography showed the uneven and multidimensional porosity of Devonian sandstones, due to their micro-lamination. The most accurate values of the porosity coefficient from the results of microtomography were obtained for cubes of the smallest size (with linear dimensions of the sample less than 5 mm), so they correspond to a higher resolution of the survey, which allows detecting smaller pores. In this connection, the inverse dependence of the porosity coefficient on the size of the samples was established. Variability of porosity along the layers in the lateral direction is revealed (the property of 'microfaciality'). The combination of traditional and precision methods for determining porosity coefficients will allow us to calculate the oil recovery factor on explored and developed oil deposits more correctly, because additional information on pore size and cavity, connectivity and type of channels, as well as microfacies are taken into account.	ru_RU
dc.language.iso	ru	ru_RU
dc.subject	ArcGIS	ru_RU
dc.subject	Devonian period	ru_RU
dc.subject	Lower Carboniferous period	ru_RU
dc.subject	Porosity	ru_RU
dc.subject	Reservoir	ru_RU
dc.subject	Volga-Ural oil and gas bearing province	ru_RU
dc.subject	X-ray CT	ru_RU
dc.title	Traditional and precision methods for studying porous space of oil-bearing formation (Russian)	ru_RU
dc.type	Articles in Russian journals and collections	ru_RU