Amplitude preserved VSP reverse time migration for angle-domain CIGs extraction

Sun, Wenbo; Sun, Zandong; Zhu, Xinjian

doi:10.1007/s11770-011-0277-1

Cited by 5 publications

(3 citation statements)

References 14 publications

(31 reference statements)

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“…3 and 4). This kind of artifacts has also been noted when applying the RTM method to vertical seismic profile system, which is mostly caused by the limited spatial coverage of the observation system and can be alleviated by the increase of sensor spatial coverage (Sun et al, 2011).…”

Section: Synthetic Test Of Downhole Microseismic Migration Methodsmentioning

confidence: 90%

“…In this case, the configuration of seismic sensors and sources is similar to the vertical seismic profile (VSP) system except the sources are located around reservoirs for microseismic monitoring while they are located on surface for VSP. For this reason, we can adapt the VSP RTM method (Sun et al, 2011;Xiao and Leaney, 2010) to downhole microseismic monitoring. The conventional reverse time migration method consists of four generalized steps:…”

Section: Microseismic Reverse Time Migration Methodsmentioning

confidence: 99%

“…Here, we formulate the RTM method based on a 2D acoustic wave equation (Zhang and Sun, 2008;Sun et al, 2011). For the borehole array, we need to compute forward-propagating wavefield p F with event originating at ðx…”

Section: Microseismic Reverse Time Migration Methodsmentioning

confidence: 99%

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Imaging hydraulic fractures by microseismic migration for downhole monitoring system

Lin

Zhang

2016

SEG Technical Program Expanded Abstracts 2016

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It has been a challenge to accurately characterize fracture zones created by hydraulic fracturing from microseismic event locations. This is because generally detected events are not complete due to the associated low signal to noise ratio and some fracturing stages may not produce microseismic events even if fractures are well developed. As a result, spatial distribution of microseismic events may not well represent fractured zones by hydraulic fracturing. Here, we propose a new way to characterize the fractured zones by reverse time migration (RTM) of microseismic waveforms from some events. This is based on the fact that fractures filled with proppants and other fluids can act as strong scatterers for seismic waves. Therefore, for multi-stage hydraulic fracturing, recorded waveforms from microseismic events induced in a more recent stage may be scattered by fractured zones from previous stages. Through RTM of microseismic waveforms in the current stage, we can determine fractured zones created in previous stages by imaging area of strong scattering. We test the feasibility of this method using synthetic models with different configurations of microseismic event locations and borehole sensor positions for a 2D downhole microseismic monitoring system. Synthetic tests show that with a few events fractured zones can be directly imaged and thus the stimulated reservoir volume (SRV) can be estimated. Compared to the conventional location-based SRV estimation method, the proposed new method does not depend on the completeness of detected events and only a limited number of detected and located events are necessary for characterizing fracture distribution. For simplicity, the 2D model is used for illustrating the concept of microseismic RTM for imaging the fracture zone but the method can be adapted to real cases in the future.

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Section: Synthetic Test Of Downhole Microseismic Migration Methodsmentioning

confidence: 90%

Section: Microseismic Reverse Time Migration Methodsmentioning

confidence: 99%