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Petrophysical rock typing and permeability prediction in tight sandstone reservoir

Lis-Śledziona Anita

Acta Geophysica

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2019

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Vol. 67, no. 6

1895--1911

EN

In this paper, the low-permeability reservoir was subdivided into several units based on three models; in the first model, porosity, permeability, pore sizes, and shale volume were used as an input in the heterogeneous rock analysis clustering workflow to define rock units; in the second model, rock types were defined using flow zone index. The third flow unit discriminator was proposed by the author; the model is based on relation between porosity, permeability, irreducible water saturation, and pore size distribution. Also, Wyllie–Rose equation for permeability in tight reservoir was core-calibrated, and coefficients e, d, and Kw were established. The reservoir is built of thin layers of sandstones with variable porosity, permeability, pore sizes, and irreducible water. The research was performed in two wells where as input well log data, the laboratory results of mercury injection porosimetry, permeability measurements, and nuclear magnetic resonance data were used. Furthermore, it was investigated whether the presence of fractures identified on XRMI images were strictly related to one flow unit.

2

Podział skały zbiornikowej na jednostki o jednakowych właściwościach hydraulicznych w celu dokładniejszego wyznaczania przepuszczalności podczas modelowania przepływów w złożu gazu

Jarzyna J., Ha Quang M.

Przegląd Geologiczny

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2009

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Vol. 57, nr 11

996-1003

EN

Petrophysical parameters such as porosity and permeability and bulk density are input data for modeling hydrocarbon flow in reservoirs with the use of Eclipse® program (Schlumberger). The modeling is preceded by preliminary works comprising division of reservoir into hydraulic (flow) units, HU, and their characterization by geometrical and geological factors. Flow Zone Index, FZI, is a factor enabling easier description of movement of media in pore space only on the basis of combination of permeability and porosity. Then, HUs are determined on the basis of FZIs. The tested gas deposit belonged to a group of typical Miocene reservoirs from the Polish part of the Carpathian Foredeep. In this deposit, gas accumulations are related to deltaic sediments represented by sandstone and mudstone layers of various thickness, and heterolites with claystone, mudstone and sandstone intercalations. In the case of this deposit, the wealth of laboratory data made possible credible differentiation of FZI and HU. The tested methodology can also be applied to investigations of reservoirs bearing potable, mineral and geothermal water as well as those used for storage of sequestrated carbon dioxide.

3

Variability of the Rotliegend sandstones in the Polish part of the Southern Permian Basin - permeability and porosity relationships

Jarzyna J., Puskarczyk E., Bała M., Papiernik B.

Annales Societatis Geologorum Poloniae

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2009

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Vol. 79, No 1

13-26

EN

The Flow Zone Index, FZI, applied to order relations between the effective porosity and permeability of the Rotliegend sandstones in the Polish part of the Southern Permian Basin turns out to be a useful and effective factor to evaluate ability of media flow in a rock formation. A dataset of over 2000 samples from 78 wells was analysed. Based only on porosity and permeability, FZI includes all non-parameterized features of rocks as tortuosity and diameters of porous channels, volume of trapped parts of capillary roads, specific surface of pore space, and others. When FZI increases, the ability of fluid to move through the porous space increases. In most cases, the Rotliegend sandstones reveal FZI in the range of 0.5-2.0. The highest FZI, ca. 100, is related to fractured part of the studied formation. The combination of FZI and facies information from several wells in the study area (over 1200 samples) showed a good correlation. On the basis of FZI we can divide a set of samples of the Rotliegend sandstone into groups of defined fluid flow abilities and relate them to facies. Also, we show the way of estimation of the reliable values of permeability in full geological log of a borehole on the basis of FZI, and the total porosity determined from well logging interpretation.

4

Zależności między parametrami petrofizycznymi klastycznych skał karbońskich w basenie lubelskim na przykładzie obszaru Stężycy

Jarzyna J., Bała M.

Geologia / Akademia Górniczo-Hutnicza im. Stanisława Staszica w Krakowie

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2005

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T. 31, z. 3/4

337-355

PL

Określono zależności między porowatością i przepuszczalnością oraz wskaźnikiem przepływu FZI w klastycznych utworach karbonu należących do środkowego namuru i dolnego westfalu w basenie lubelskim w rejonie Stężycy. Zaobserwowano zróżnicowanie FZI w poziomach złożowych i w warstwach bez objawów węglowodorów w wydzielonym kompleksie depozycyjnym III oraz w kompleksach III i II. Przeprowadzono analizę statystyczną parametrów petrofizycznych, tj. porowatości, przepuszczalności, objętości piaskowca i iłu w otworach Stężyca 1, 2, 3K i 4 w celu określenia typowych cech dla skał w profilu karbonu, kompleksu III oraz interwału produktywnego w kompleksie III. Wysokie współczynniki korelacji wskazują, że dane są dobrze skorelowane, a porowatość wyznaczona na podstawie badań laboratoryjnych - Poro - może być zastąpiona porowatością PHI, wyznaczoną w wyniku kompleksowej interpretacji profilowań geofizyki otworowej. Wykonano także podziały zbiorów danych wg współczynników FZI i skorelowano porowatość i przepuszczalność w jednorodnych jednostkach przepływu. Relacje określające ruchliwość mediów porowych w jednorodnych jednostkach FZI okazały się silniejsze niż w całym zbiorze. Jako wyniki przeprowadzonych badań przedstawiono także metodę ciągłego wyznaczania współczynnika przepuszczalności in situ na podstawie porowatości PHI

EN

Characteristics of porosity and permeability and Flow Zone Indicator, FZI, of the Carboniferous clastic rocks, especially of the Middle-Namurian Lower-Westfalian in the Stężyca region, Lublin Basin have been presented. There were discovered differences in FZI between the hydrocarbon deposit section and unproductive beds in the determined III complex and between III and II complexes. A statistical analysis was performed for petrophysical parameters, i.e. porosity, permeability, volumes of sand and shale in the wells: Stężyca 1, 2, 3K and 4 to reveal features typical for all Carboniferous data, III complex and hydrocarbon-bearing section of III complex. High correlation coefficients showed data are well correlated and porosity from cores, Poro, can be substituted by porosity from the comprehensive interpretation of logs, PHI. A division of elaborated data sets due to the FZI has been realized and statistical relations between permeability and porosity in homogeneous flow units have been established. Relations describing a mobility of media in pore space for FZI units appeared to be stronger than for the total data set. A method of a continuous K-logging in situ on the base of PHI has also been a result of conducted considerations