Generating porosity spectrum of carbonate reservoirs using ultrasonic imaging log

Zhang, Jie; Nie, Xiaodong; Xiao, Suyun; Zhang, Chong; Zhang, Zhansong

doi:10.1007/s11600-018-0134-1

Cited by 10 publications

(4 citation statements)

References 12 publications

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“…Meanwhile, micro-resistivity imaging logs were generated in JY1 Well. These ultrahigh-resolution images cover the shortage of cores and play an important role in describing lithology and fabric of formation finely (Zhou, 2008;Xu et al, 2009;Yan et al, 2011;Folkestad et al, 2012;Brekke et al, 2017;Luo et al, 2018;Zhang et al, 2018;Yuan et al, 2020).…”

Section: Databasementioning

confidence: 99%

Utilizing logs to identify complex lithology of tight marl reservoir in the Leikoupo Formation 32 Submember (T2l32) of the Sichuan Basin, China

Yuan,

Wu,

Xin

et al. 2024

Front. Earth Sci.

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Recent exploration has revealed that the Middle Triassic Leikoupo Formation 32 Submember (T2l32) in the Sichuan Basin contains unconventional marl reservoirs with significant natural gas potential. Due to limited cores, old wells, and conventional logs, however, the lithological understanding of T2l32 is incomplete and relies solely on inaccurate mud logs. This lack of lithological foundation challenges geology and petroleum research. To identify complex lithology, this paper presents a double-hierarchical workflow to identify seven types of lithology using logs. The first order distinguishes salt, anhydrite, and marl, while the second order further subdivides marl into anhydrite marl, argillaceous limestone, shaly limestone, and limy shale. Different rocks’ logging response characteristics are summarized based on quantity-limited cores and micro-resistivity imaging logs. Lithological identification of 2D and 3D plots is established using sensitive GR, DEN, and RT. Corresponding identification standards are built in two hierarchies. According to these standards, the lithology of T2l32 is identified in a total of 119 wells. Finally, the lithological characteristics of vertical, horizontal, and plane are discussed in the research area. The research results may aid in comprehending the entire lithological characteristics of the complex marl reservoir in T2l32 of the Sichuan Basin. It would help the exploration potential of petroleum systems in turn.

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Section: Databasementioning

confidence: 99%

Utilizing logs to identify complex lithology of tight marl reservoir in the Leikoupo Formation 32 Submember (T2l32) of the Sichuan Basin, China

Yuan,

Wu,

Xin

et al. 2024

Front. Earth Sci.

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“…Fluid flow and saturation characteristics in a reservoir rock are the crucial parameters that control the quality of reservoir rock and need to be considered in reservoir rock typing (Aliakbardoust and Rahimpour-Bonab 2013). It is also important to recognize the structure and texture of tight, reservoir rocks using the novel approach to known methods-laboratory and well logging (Zhu et al 2018;Puskarczyk et al 2018;Zhang et al 2018). This study presents rock typing with an understanding of petrophysical properties such as porosity, pore size, permeability, and capillary water content.…”

Section: Introductionmentioning

confidence: 99%

Petrophysical rock typing and permeability prediction in tight sandstone reservoir

Lis-Śledziona

2019

Acta Geophys.

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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.

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“…Currently, work is underway to quantify the pore space parameters of carbonate formations based on nano-CT (computed X-ray tomography) measurements (Puskarczyk et al 2018). An interesting approach seems to be the generating porosity spectrum based on ultrasonic imaging log (Zhang et al 2018). The general approach to qualitative fracture analysis is the methodology of complex fractures analysis (CFA) proposed by (Sowiżdżal and Stadtműller 2010).…”

Section: Introductionmentioning

confidence: 99%

Well logging interpretation methodology for carbonate formation fracture system properties determination

Stadtmüller

2019

Acta Geophys.

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The article presents the methodology for the qualitative determination of fracture zones in the profiles of carbonate formations, based on the complex fracture analysis (CFA) method. Three additive fracture ranges were distinguished, characterized by successively increasing aperture and fracture length values, operatively named micro, meso and macro. Furthermore, the quantitative characterization of fractures with different apertures was done. The methodology of laboratory data integration, fracture porosity and fracture permeability measurements performed on thin section and polished section was described as part of the quantitative well logging data interpretation procedure which uses the FPI (fracture porosity index) parameter. The research was performed in the Lower Carboniferous limestone formation that builds the Paleozoic basement of the Carpathian orogeny. An original software dedicated to the analysis of the wellbore images, obtained with the XRMI Halliburton scanner, was used to identify the presence of macro-fractures, determine their aperture and estimate fractures porosity and permeability in the profile of the analyzed rock formation. As a result of the work, postulates regarding the methodology for collecting research material were formulated, in particular: the scope of different laboratory core samples measurements and well log types. The principles of the optimal methodology for identifying fractured zones and quantitative evaluation of petrophysical parameters of recognized fracture systems were defined.

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Generating porosity spectrum of carbonate reservoirs using ultrasonic imaging log

Cited by 10 publications

References 12 publications

Utilizing logs to identify complex lithology of tight marl reservoir in the Leikoupo Formation 32 Submember (T2l32) of the Sichuan Basin, China

Utilizing logs to identify complex lithology of tight marl reservoir in the Leikoupo Formation 32 Submember (T2l32) of the Sichuan Basin, China

Petrophysical rock typing and permeability prediction in tight sandstone reservoir

Well logging interpretation methodology for carbonate formation fracture system properties determination

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