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US 10,379,235 B2Granted
Deterministic phase correction and application
AssigneeConocoPhillips Company
InventorsPeter M. Eick, Joel D. Brewer, Shan Shan
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Abstract
A method of more accurate phase encoding of phase offset vibrators used in simultaneous-multiple-sourcing 3D seismic mapping. The method measures the actual input energy and the proxy energy thereby determining a bulk error and a frequency-dependent error, both to be applied to correct the proxy energy. The corrected proxy energy is then used to perform actual seismic survey, and the inversion is then performed using the corrected proxy energy to source separate each vibe where the error is minimized.
Claims8
A method of source separating composite seismic data, the method comprising:
- obtaining, via at least one seismic receiver, a baseline measurement of a source seismic energy signal, via two or more vibratory sources, at a plurality of predetermined frequencies within a predetermined frequency range, wherein the two or more vibratory sources operate at a same time but in offset phases;
- obtaining, via the at least one seismic receiver, a simultaneous proxy measurement of the source seismic energy signal, via the two or more vibratory sources, at the plurality of predetermined frequencies within the predetermined frequency range;
- measuring a bulk sweep-to-sweep phase variation between the baseline measurement and the simultaneous proxy measurement of an output source seismic energy to determine a bulk phase error;
- measuring a frequency dependent sweep-to-sweep phase variation between the baseline measurement and the simultaneous proxy measurement to determine a frequency dependent phase error;
- applying the bulk phase error and the frequency dependent phase error to a proxy source signal as an aux channel to create a corrected aux channel for each of the two or more vibratory sources for each of the bulk sweep-to-sweep phase variation and the frequency dependent sweep-to-sweep phase variation;
- inputting the corrected aux channel for the two or more vibratory sources and receiving and recording a composite seismic data with the at least one seismic receiver into an inversion program;
- and
- performing an inversion on the composite seismic data to source separate the composite seismic data for each of the two or more vibratory sources.
5 more elements
Dependencies are inferred from the claim text.