Converted-wave seismic imaging: Amplitude-balancing source-independent imaging conditions

Shabelansky, Andrey Hanan; Malcolm, Alison; Fehler, Michael

doi:10.1190/geo2015-0167.1

Cited by 20 publications

(8 citation statements)

References 29 publications

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“…In principle, using different types of wave phases (e.g. primary and converted-waves) is possible to map the discontinuity interface, which has been demonstrated by several authors (Nihei et al 2000;Xiao & Schuster 2009;Shang et al 2012;Shabelansky et al 2017). This is because the fracture serving as secondary sources can generate converted waves when primary waves pass through the fracture.…”

Section: Converted-wave Effectsmentioning

confidence: 99%

“…Recent development of using the interference between different types of wave phases (Nihei et al 2000;Xiao & Schuster 2009;Shang et al 2012;Shabelansky et al 2017) may give us another solution. However, all those imaging approaches involving processing converted S-wave pose restrictions to demand not only P-wave velocity model but also S-wave velocity model which is rarely available for imaging.…”

Section: Introductionmentioning

confidence: 99%

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Passive seismic imaging of subsurface natural fractures: application to Marcellus shale microseismic data

Huang

Zhu

2019

Geophysical Journal International

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Imaging and characterizing subsurface natural fractures that are common in the Earth crust has been a long-sought goal in seismology. We present an application of a 3-D passive seismic fracture imaging method applied to Marcellus shale microseismic data for mapping natural fractures. Unlike conventional seismic imaging methods that need source information, the proposed imaging method does not require source information and is flexible enough to apply to any passive seismic data where the source location is unknown or inaccurate. We first test our imaging approach using surface microseismic monitoring array data in 3-D synthetic examples. The finite-aperture fractures are designed by an open-source discrete fracture network software. Compared to conventional source-dependent fracture imaging, the proposed source-independent imaging approach produces superior images of fractures with less ambiguity. These tests also illustrate that the proposed method is less sensitive to the accuracy of background velocity and less affected by the sparse and irregular acquisition geometry which often cause acquisition-footprint issues in convention imaging methods. The final test in the field microseismic data from the Marcellus Shale (Pennsylvania) demonstrates the applicability of the proposed imaging method. Field data results indicate two clusters of east-northeast fractures existed above and below the hydraulic fracturing zone, which corroborates previous work that found two main types of faults in the study area.

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Section: Converted-wave Effectsmentioning

confidence: 99%

Section: Introductionmentioning

confidence: 99%

Passive seismic imaging of subsurface natural fractures: application to Marcellus shale microseismic data

Huang

Zhu

2019

Geophysical Journal International

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“…Shang et al (2012) and Shabelansky et al (2015) argued that passive seismic without location information can be used to achieve the source-free subsurface image. Based on the relationship between the P-wavefield and converted S-wavefield in the receiver extrapolation, Shabelansky et al (2017) demonstrated a source-free converted-wave RTM imaging condition, which only uses the back-propagation Pand S-waves to perform cross-correlation imaging. As a result, it does not require source extrapolation, thereby saving In this study, we apply the vector imaging condition to the RTM of the first-order velocity-dilatation-rotation elastic wave equations.…”

Section: Imaging Conditionmentioning

confidence: 99%

“…Then, based on the idea of vector dot product cross-correlation, we present a more precise source-free P-SV converted-wave imaging condition. Shabelansky et al (2017) gave a source-free converted-wave imaging condition:…”

Section: Imaging Conditionmentioning

confidence: 99%

Source-Free P-SV Converted-Wave Reverse-Time Migration Using First-Order Velocity-Dilatation-Rotation Equations

Yao

Shao

2022

Front. Earth Sci.

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The cross-correlation imaging condition between source- and receiver-wavefields is often used in the elastic wave reverse-time migration (RTM) to utilize P- and S-waves. However, it cannot be applied in the absence of source information (e.g., source location, and source wavelet), which is quite common in passive source exploration. We employ a source-free P-SV converted-wave imaging condition, which only requires the back-propagating receiver-wavefield to utilize the P-SV converted waves in imaging the subsurface structures. The imaging condition is independent of source information, which can avoid the extrapolation and reconstruction of the source-wavefield. As a result, the computational cost is decreased to about one-third of conventional RTM that uses source-wavefield reconstruction strategies, e.g., random boundaries. The memory requirement could be also reduced by avoiding the calculation of source-wavefield. Because our imaging condition uses the vector P-wavefield and vector S-wavefield to utilize the P-SV waves, it is necessary to decouple P-wavefield and S-wavefield during the reverse-time extrapolation of receiver-wavefield. We use the first-order velocity-dilatation-rotation elastic wave equations to realize the reverse-time propagation of vector receiver-wavefield, where the vector P-wavefield and vector S-wavefield can be obtained directly. Based on the above methods, a source-free P-SV converted-wave RTM of multi-component seismic data is realized. The model tests show that this method can generate promising subsurface images and can be complementarily used when conventional cross-correlation imaging conditions are not suitable.

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“…Following the same idea, Shabelansky et al (2015) developed a velocity analysis method using reflection/transmission waves and converted waves using both active and passive seismic data. Shabelansky et al (2017) further elaborated the source-independent converted wave imaging condition for better amplitude balancing with the deconvolutional forms.…”

Section: Introductionmentioning

confidence: 99%

Passive seismic imaging of subwavelength natural fractures: theory and 2-D synthetic and ultrasonic data tests

Zhu

2018

Geophysical Journal International

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I present a source-independent fracture imaging method to use passive seismic data for mapping subwavelength natural fractures. Unlike conventional source-dependent imaging that often adopts reflection-type seismic imaging with known source that is not available in passive seismic surveys, the proposed fracture imaging approach relies on the transmission and diffraction data without the need for source information. I assume that passive seismic data can be decomposed into two types of data: primary transmission wave data and diffraction (coda) wave data. The imaging formula states that primary waves should coincide with coda waves at scatterer points at the time of scattering. Instead of generating source wavefields in the conventional imaging method, the proposed method only need to propagate transmission wave data and diffraction wave data from the receiver arrays and apply an imaging condition to produce an image of fractures. This imaging procedure can be used for processing P wave or S wave. In synthetic examples, I evaluate the proposed method in several aspects: inaccurate source location, inaccurate velocity model, sparse receivers and irregular receiver spacing, elastic data and joint surface and borehole acquisitions. I found that the proposed approach performed well (or even better) comparable to source-dependent fracture imaging when assuming exact source information is known. With perturbed source locations with random shifts (e.g. estimated source location with errors), however, fractures were missing in the source-dependent fracture imaging results but the proposed approach was not influenced. In the presence of velocity errors and sparse and irregular receiver spacing, the proposed method produces better fracture images than the source-dependent imaging results.

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Converted-wave seismic imaging: Amplitude-balancing source-independent imaging conditions

Cited by 20 publications

References 29 publications

Passive seismic imaging of subsurface natural fractures: application to Marcellus shale microseismic data

Passive seismic imaging of subsurface natural fractures: application to Marcellus shale microseismic data

Source-Free P-SV Converted-Wave Reverse-Time Migration Using First-Order Velocity-Dilatation-Rotation Equations

Passive seismic imaging of subwavelength natural fractures: theory and 2-D synthetic and ultrasonic data tests

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