Azimuthal reflectivity and quantitative evaluation of anisotropic parameters from seismic data: a feasibility study

Mallick, Subhashis; Gillespie, Diana; Sen, Mrinal K.

doi:10.1190/1.2144294

Cited by 5 publications

(1 citation statement)

References 6 publications

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“…Note that if we assume a certain principal direction, then this requirement is not needed. However, it is also important to note that the recovery of the high-order terms is difficult, as many times the far offsets are contaminated by noise and in many cases, the resolution of the seismic inversion to the higher-order terms is limited (Mallick, Gilespie and Sen 2005).…”

Section: Practical Angle and Azimuth Limitation For Amplitude Versus mentioning

confidence: 99%

Reconstruction of the layer anisotropic elastic parameters and high‐resolution fracture characterization from P‐wave data: a case study using seismic inversion and Bayesian rock physics parameter estimation

Bachrach

Sengupta

Salama

et al. 2009

Geophysical Prospecting

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A B S T R A C TWide-azimuth seismic data can be used to derive anisotropic parameters on the subsurface by observing variation in subsurface seismic response along different azimuths. Layer-based high-resolution estimates of components of the subsurface anisotropic elastic tensor can be reconstructed by using wide-azimuth P-wave data by combining the kinematic information derived from anisotropic velocity analysis with dynamic information obtained from amplitude versus angle and azimuth analysis of wide-azimuth seismic data. Interval P-impedance, S-impedance and anisotropic parameters associated with anisotropic fracture media are being reconstructed using linearized analysis assuming horizontal transverse anisotropy symmetry. In this paper it is shown how additional assumptions, such as the rock model, can be used to reduce the degrees of freedom in the estimation problem and recover all five anisotropic parameters. Because the use of a rock model is needed, the derived elastic parameters are consistent with the rock model and are used to infer fractured rock properties using stochastic rock physics inversion. The inversion is based on stochastic rock physics modelling and maximum a posteriori estimate of both porosity and crack density parameters associated with the observed elastic parameters derived from both velocity and amplitude versus angle and azimuth analysis. While the focus of this study is on the use of P-wave reflection data, we also show how additional information such as shear wave splitting and/or anisotropic well log data can reduce the assumptions needed to derive elastic parameter and rock properties.

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Section: Practical Angle and Azimuth Limitation For Amplitude Versus mentioning

confidence: 99%

Reconstruction of the layer anisotropic elastic parameters and high‐resolution fracture characterization from P‐wave data: a case study using seismic inversion and Bayesian rock physics parameter estimation

Bachrach

Sengupta

Salama

et al. 2009

Geophysical Prospecting

View full text Add to dashboard Cite

show abstract

Reconstruction of the layer anisotropic elastic parameters using kinematic and dynamic information derived from wide‐azimuth data

Bachrach¹,

Sengupta²,

Salama³

et al. 2006

SEG Technical Program Expanded Abstracts 2006

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Azimuthal anisotropy analysis of P-wave seismic data and estimation of the orientation of the in situ stress fields: An example from the Rock-Springs uplift, Wyoming, USA

Mallick

Mukherjee²,

Shafer

et al. 2017

GEOPHYSICS

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Estimating the orientation and magnitude of maximum and minimum horizontal in situ stress is important for characterizing naturally fractured, unconventional, and carbon-sequestered reservoirs. For naturally fractured reservoirs, they are needed to guide directional drilling; for unconventional reservoirs, they are used for optimal placements of hydraulic fractures; and for carbon-sequestered reservoirs, they are used to avoid fracturing of overlying seal rocks. In addition, a knowledge of stress fields can be used to induce fractures within the target reservoirs and enhance additional storage for carbon-sequestration experiments. The orientation and magnitude of in situ stress can be calculated at the well locations. For locations, away from the wells, analysis of the azimuthal dependence of the amplitude-variation-with-angle gradient or azimuthal angle stacks are used to quantify anisotropy, which are then related with well data and other geologic information for stress estimation. Such azimuthal analysis requires accurate conversion of offset-domain seismic data into angles. We use isotropic prestack waveform inversion for an accurate offset-to-angle transformation along different source-to-receiver azimuths followed by azimuthal analysis. Applying our method to the real seismic data from the Rock-Springs uplift, Wyoming, USA, and relating the results to the well data, we find that our results are favorably related to the orientation of the maximum in situ horizontal stress field measured at the well location.

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Azimuthal reflectivity and quantitative evaluation of anisotropic parameters from seismic data: a feasibility study

Cited by 5 publications

References 6 publications

Reconstruction of the layer anisotropic elastic parameters and high‐resolution fracture characterization from P‐wave data: a case study using seismic inversion and Bayesian rock physics parameter estimation

Reconstruction of the layer anisotropic elastic parameters and high‐resolution fracture characterization from P‐wave data: a case study using seismic inversion and Bayesian rock physics parameter estimation

Reconstruction of the layer anisotropic elastic parameters using kinematic and dynamic information derived from wide‐azimuth data

Azimuthal anisotropy analysis of P-wave seismic data and estimation of the orientation of the in situ stress fields: An example from the Rock-Springs uplift, Wyoming, USA

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