9-C time‐lapse VSP monitoring of steam injection at Cymric Oil Field

Winterstein, D. F.; Stefani, Joe; Johnson, Scott J.; Julander, Dale

doi:10.1190/1.1438006

Cited by 4 publications

(3 citation statements)

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“…Offset VSP data were processed in a manner similar to that outlined in Winterstein et al (1998) for offset VSP data from Cymric field. However, because the rocks at McElroy field were VTI, the processing assumptions that led to only rough approximations at Cymric were more appropriate here and gave accurate, easily interpretable results.…”

Section: Data Acquisition and Processingmentioning

confidence: 99%

“…The global minimum Alford rotation process (Winterstein et al, 1998) applied subsequently caused only small departures from the source and receiver alignments obtained from the preceding source and receiver rotations. This step caused the faster S-waves to always appear on the in-line receiver components and the slower on the cross-line components.…”

Section: Data Acquisition and Processingmentioning

confidence: 99%

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VTI documented

Winterstein¹,

2001

GEOPHYSICS

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Shear-wave (S-wave) seismic data indicate that rocks of McElroy oil field on the Central Basin Platform of West Texas are transversely isotropic with a vertical symmetry axis (VTI). Although geophysicists from time to time had anticipated or assumed that sedimentary rock was VTI, no one had shown that any sedimentary section actually was VTI. The proof at McElroy comes from a nine-component, near-offset vertical seismic profile (VSP) combined with a ring of 15 offset VSPs spaced about 24 • apart at offsets of about 460 m. S-wave splitting at VSP frequencies was negligible for vertical propagation to a depth of 885 m but reached about 12 ms for nonvertical propagation from the offset source locations. Crossed-dipole log data supported the VSP result for vertical propagation but found two layers of vertically birefringent rock at depth whose thicknesses were below VSP resolution.

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Section: Data Acquisition and Processingmentioning

confidence: 99%

Section: Data Acquisition and Processingmentioning

confidence: 99%

VTI documented

Winterstein¹,

2001

GEOPHYSICS

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“…In recent years, an increasing number of authors have reported on the application of time‐lapse geophysics to the monitoring of production effects on reservoir properties (see, for example, Jenkins, Waite and Bee 1997; Biondi et al 1998; Winterstein et al 1998). This was made possible by substantial progress in seismic acquisition, processing and imaging technology, which resulted in the possibility of detecting small (temporal) variations in the seismic velocities and amplitudes.…”

Section: Introductionmentioning

confidence: 99%

Fast repeat‐modelling of time‐lapse seismograms

Kirchner¹,

Shapiro²

2001

Geophysical Prospecting

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In order to plan surveys for seismic time‐lapse studies, seismograms are usually simulated for a set of earth models corresponding to different stages of the oil production process. This can be expensive because, for reasons of accuracy, finite‐difference (FD) modelling is very often applied.We present the Born repeat‐modelling technique (BRM), which is a combination of FD modelling and perturbation theory. Production effects are considered as small perturbations of the earth model, and the Born approximation is used to compute the change in the wavefield due to production‐induced modifications to the reservoir properties. This is very efficient in the situation described above.We give a detailed description of the proposed modelling scheme and discuss its applicability. The theoretical foundations of BRM are presented for onshore seismic experiments, and an extension to the case of marine (pressure) seismograms is derived. In addition, the performance of BRM is demonstrated with several numerical examples.

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