Observation and analysis of frequency-dependent anisotropy from a multicomponent VSP at Bluebell-Altamont field, Utah

Liu, E.; Queen, John; Li, X.Y.; Chapman, Mark; Maultzsch, S.; Lynn, Heloise B.; Chesnokov, Evgeni M.

doi:10.1016/j.jappgeo.2003.01.004

Cited by 41 publications

(16 citation statements)

References 28 publications

(46 reference statements)

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“…Rumpker et al (1999) demonstrated the frequency‐dependent nature of splitting parameters from such seismic phases in layered anisotropic media. Similar observations were shown by Chesnokov et al (2001), Liu et al (2003) and Maultzsch et al (2003) using multicomponent VSP data and by Al‐Anboori et al (2006) using microseismic data. These observations were based on SWS analysis.…”

Section: Introductionsupporting

confidence: 84%

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Fracture characterization using frequency-dependent shear wave anisotropy analysis of microseismic data

Al-Harrasi

Kendall

Chapman

2011

Geophysical Journal International

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S U M M A R YThe presence of fractures in hydrocarbon reservoirs can enhance porosity and permeability, and consequently increase production. The use of seismic anisotropy to characterize fracture systems has gained much interest in the last two decades. However, estimating fracture sizes from observations of seismic anisotropy has not been possible. Recent work has shown that frequency-dependent anisotropy (FDA) is very sensitive to the length-scale of the causative mechanism for the anisotropy. In this study, we observe FDA in a microseismic data set acquired from a carbonate gas field in Oman. The frequency-dependent shear wave anisotropy observations are modelled using a poroelastic model, which considers fluid communication between grain size pore spaces and larger scale fractures. A grid search is performed over fracture parameters (radius, density and strike) to find the model that best fits the real data. The results show that fracture size varies from the microscale within the shale cap rocks, to the metre-scale within the gas reservoir, to the centimetre-scale within the non-producing part of the carbonate formation. The lateral variation in fracture density agrees with previous conclusions from ordinary shear wave splitting (SWS) analysis. Cumulatively, the results show the potential for characterizing fracture systems using observations of FDA.

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Section: Introductionsupporting

confidence: 84%

“…The two most likely mechanisms that can cause velocity dispersion and consequently FDA are scattering by inhomogenities and fluid flow in fractured porous rocks (Liu et al 2003). Anisotropy induced by scattering occurs only when the seismic wavelength is longer than the size of the inhomogenities.…”

Section: Introductionmentioning

confidence: 99%

Fracture characterization using frequency-dependent shear wave anisotropy analysis of microseismic data

Al-Harrasi

Kendall

Chapman

2011

Geophysical Journal International

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“…The Chapman model and the parameterization method are the basis for studying the effects of viscosity on elastic constants which can be used to calculate the Thomsen anisotropic parameters containing the fluid properties effects and thus help to find a solution for the discrimination of fl uid distribution in fractured reservoirs through seismic properties. There are some good examples in Maultzsch et al (2003) and Liu et al (2003).…”

Section: Detection Of Fl Uid Substitution and The Chapman Modelmentioning

confidence: 99%

Application of seismic anisotropy fluid detection technology in the Ken 71 well block of Shengli Oilfield

Li-fei

Qian²,

Zhang

et al. 2011

Appl. Geophys.

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On the basis of Chapman's (2003) model, as the seismic wave incidences angles vary from 0° to 45° while propagating in anisotropic media (HTI), the slow S-wave will sufferred by serious attenuation and dispersion and is sensitive to fl uid viscosity but the Pand fast S-waves don't. For slow S waves propagating normal to fractures, the amplitudes are strongly affected by pore fluid. So, the slow S-wave can be used to detect fractured reservoir fl uid information when the P-wave response is insensitive to the fl uid. In this paper, 3D3C seismic data from the Ken 71 area of Shengli Oilfi eld are processed and analyzed. The travel time and amplitude anomalies of slow S-waves are detected and correlated with well log data. The S-wave splitting in a water-bearing zone is higher than in an oil-bearing zone. Thus, the slow S-wave amplitude change is more signifi cant in water-bearing zones than in oil-bearing zones.

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“…Recent observational evidence suggests that the measured seismic anisotropy as inferred from time delays of split shear-waves actually depends on frequency (Marson-Pidgeon & Savage 1997;Chesnokov et al 2001;Tod & Liu 2002;Liu et al 2003a). These observations can be explained adequately and quantitatively modelled using newly developed multi-scale fracture models (Chapman 2003;.…”

mentioning

confidence: 99%

“…In particular, it is shown for the first time that it is possible to extract quantitative information about fracture sizes and spacing from seismic data (Liu et al 2003a;Maultzsch et al 2003). Finally, it is suggested that seismic fracture attribute maps can be used to constrain reservoir fracture models using the concept of a discrete fracture network (DFN) model (Rogers et aI.…”

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confidence: 99%

Quantitative determination of hydraulic properties of fractured rock using seismic techniques

Liu

Chapman

Hudson

et al. 2005

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There have been significant advances over the last ten years in the use of the seismic anisotropy concept to characterize subsurface fracture systems. Measurements of seismic anisotropy are now used to deduce quantitative information about the fracture orientation and the spatial distribution of fracture intensity. Analysis of the data is based upon various equivalent medium theories that describe the elastic response of a rock containing cracks or fractures in the long wavelength limit. Conventional models assume scale/ frequency independence and hence cannot distinguish between micro-cracks and macrofractures. The latter, however, control the fluid flow in many oil/gas reservoirs, as the fracture size and spacing (hence fracture storability) are essential parameters for reservoir engineers. Recently, a new equivalent medium theory for modelling of wave propagation in media with multi-scale fractures has been presented. The model predicts velocity dispersion and attenuation due to a squirt-flow mechanism at two different scales: the grain scale (micro-cracks and equant matrix porosity) and formation-scale fractures. Application of this model to field data shows that fracture density and fracture size can be inverted successfully from the frequency dependence of the time delay between split shear waves. The derived fracture length matches independent observations from borehole data. This paper presents the results of the latest development in the seismic characterization of natural fractures, with an emphasis on the quantitative determination of fracture sizes.

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Observation and analysis of frequency-dependent anisotropy from a multicomponent VSP at Bluebell-Altamont field, Utah

Cited by 41 publications

References 28 publications

Fracture characterization using frequency-dependent shear wave anisotropy analysis of microseismic data

Fracture characterization using frequency-dependent shear wave anisotropy analysis of microseismic data

Application of seismic anisotropy fluid detection technology in the Ken 71 well block of Shengli Oilfield

Quantitative determination of hydraulic properties of fractured rock using seismic techniques

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