Characterization of Elastic Anisotropy in Eagle Ford Shale: Impact of Heterogeneity and Measurement Scale

2016 ◽  
Vol 19 (03) ◽  
pp. 429-439 ◽  
Author(s):  
Mehdi Mokhtari ◽  
Matt M. Honarpour ◽  
Azra N. Tutuncu ◽  
Gregory N. Boitnott
Keyword(s):  
Elastic Properties ◽  
Elastic Anisotropy ◽  
Dynamic Properties ◽  
Measurement Scale ◽  
Log Analysis ◽  
Well Log ◽  
Measurement Scales ◽  
Eagle Ford Shale ◽  
Eagle Ford ◽  
Well Log Analysis

Summary Heterogeneity and anisotropy were characterized in some Eagle Ford shale samples at various scales by use of scanning-electron-microscopy (SEM) imaging, computed-tomography (CT) scanning, and compressional-velocity scanning. Triaxial testing on 1-in.-diameter and 3-in.-diameter core samples and well-log analysis were used to calculate elastic properties by using vertical transverse isotropic modeling. Correlations between the stiffness coefficients and the correlations between static and dynamic properties from laboratory tests were applied to well-log analysis to improve the calculation of minimum horizontal stress. This paper provides the elastic properties of the Eagle Ford shale at various measurement scales. The paper also elaborates the role of heterogeneity in laboratory testing of shale reservoirs.

Elastic properties of rock salt: Lab measurements and well log analysis in the Gulf of Mexico

2015 ◽  
Author(s):  
Jingjing Zong* ◽  
Robert R. Stewart ◽  
Nikolay Dyaur ◽  
Michael T. Myers
Keyword(s):  
Gulf Of Mexico ◽  
Elastic Properties ◽  
Rock Salt ◽  
Log Analysis ◽  
Well Log ◽  
Well Log Analysis

Modeling the effects of microscale fabric complexity on the anisotropy of the Eagle Ford Shale

2016 ◽  
Vol 4 (2) ◽  
pp. SE17-SE29 ◽  
Author(s):  
Qi Ren ◽  
Kyle T. Spikes
Keyword(s):  
Clay Minerals ◽  
Elastic Properties ◽  
Elastic Anisotropy ◽  
Anisotropy Parameter ◽  
Clay Content ◽  
Preferred Orientation ◽  
Eagle Ford Shale ◽  
Eagle Ford ◽  
Clay Concentration ◽  
Anisotropic Elastic

Microscale fabric influences the elastic properties of rock formations. The complexity of the microscale fabric of shale results from composition, platy clay minerals, kerogen, and their preferred orientation patterns. This microscale fabric is also the likely cause of the elastic anisotropy of the rock. In this paper, we have developed a comprehensive three-step rock-physics approach to model the anisotropic elastic properties of the Upper Eagle Ford Shale. We started with anisotropic differential effective medium modeling, followed by an orientation correction, and then a pressure adjustment. This method accounts for the microscale fabric of the rock in terms of the complex composition, shape, and alignment of clay minerals, pore space, and kerogen. In addition, we accounted for different pressure-dependent behaviors of P- and S-waves. Our modeling provides anisotropic stiffnesses and pseudologs of anisotropy parameters. The modeling results match the log measurements relatively well. The clay content, kerogen content, and porosity decreased the rock stiffness. The anisotropy increases with kerogen content, but the influence of clay content was more complex. Comparing the anisotropy parameter pseudologs with clay content shows that clay content increases anisotropy at small concentrations; however, the anisotropy stays constant, or even slightly decreases, as the clay content continues to increase. This result suggests that the preferred orientation of clay clusters is preserved at low clay concentration but vanishes at high clay concentration. This method could also be applied to other shales with carefully chosen parameters to model anisotropic elastic properties.

Well Log Analysis for Reservoir Characterization of Famenian Carbonates with Criterion of Texture Heterogeneity

2018 ◽  
Author(s):  
Gulnaz Minigalieva ◽  
Albina Nigmatzyanova ◽  
Tatyana Burikova ◽  
Olga Privalova ◽  
Ruslan Akhmetzyanov ◽  
...  
Keyword(s):  
Reservoir Characterization ◽  
Log Analysis ◽  
Well Log ◽  
Well Log Analysis

Well Log Analysis for Reservoir Characterization of Famenian Carbonates with Criterion of Texture Heterogeneity (Russian)

2018 ◽  
Author(s):  
Gulnaz Minigalieva ◽  
Albina Nigmatzyanova ◽  
Tatyana Burikova ◽  
Olga Privalova ◽  
Ruslan Akhmetzyanov ◽  
...  
Keyword(s):  
Reservoir Characterization ◽  
Log Analysis ◽  
Well Log ◽  
Well Log Analysis

Assessment of gas hydrate using pre-stack seismic inversion in Mahanadi Basin, offshore eastern India

2021 ◽  
pp. 1-42
Author(s):  
Maheswar Ojha ◽  
Ranjana Ghosh
Keyword(s):  
Gas Hydrate ◽  
Rock Physics ◽  
Type Equation ◽  
Seismic Inversion ◽  
Log Analysis ◽  
Well Log ◽  
Seismic Section ◽  
Bottom Simulating Reflector ◽  
Hydrate Saturation ◽  
Well Log Analysis

The Indian National Gas Hydrate Program Expedition-01 in 2006 has discovered gas hydrate in Mahanadi offshore basin along the eastern Indian margin. However, well log analysis, pressure core measurements and Infra-Red (IR) anomalies reveal that gas hydrates are distributed as disseminated within the fine-grained sediment, unlike massive gas hydrate deposits in the Krishna-Godavari basin. 2D multi-channel seismic section, which crosses the Holes NGHP-01-9A and 19B located at about 24 km apart shows a continuous bottom-simulating reflector (BSR) along it. We aim to investigate the prospect of gas hydrate accumulation in this area by integrating well log analysis and seismic methods with rock physics modeling. First, we estimate gas hydrate saturation at these two Holes from the observed impedance using the three-phase Biot-type equation (TPBE). Then we establish a linear relationship between gas hydrate saturation and impedance contrast with respect to the water-saturated sediment. Using this established relation and impedance obtained from pre-stack inversion of seismic data, we produce a 2D gas hydrate-distribution image over the entire seismic section. Gas hydrate saturation estimated from resistivity and sonic data at well locations varies within 0-15%, which agrees well with the available pressure core measurements at Hole 19. However, the 2D map of gas hydrate distribution obtained from our method shows maximum gas hydrate saturation is about 40% just above the BSR between the CDP (common depth point) 1450 and 2850. The presence of gas-charged sediments below the BSR is one of the reasons for the strong BSR observed in the seismic section, which is depicted as low impedance in the inverted impedance section. Closed sedimentary structures above the BSR are probably obstructing the movements of free-gas upslope, for which we do not see the presence of gas hydrate throughout the seismic section above the BSR.

Conventional Well Log Analysis

1985 ◽  
pp. 19-29
Author(s):  
Mihir K. Sinha ◽  
Larry R. Padgett
Keyword(s):  
Log Analysis ◽  
Well Log ◽  
Well Log Analysis
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