Methods for deconvolution of unknown source signatures from unknown waveform data

Claim 2

In a process for obtaining a vertical seismic profile from seismic data obtained from a source located in a borehole and a plurality of receivers located above the source, the source having an unknown, time-extended signature, a method of estimating said source signature, said method comprising the steps of: activating the source so as to produce said source signature; receiving, at the plurality of receivers, seismic waveforms generated as a result of said source signature; calculating a dominating moveout of said received seismic waveforms based on local coherency analysis; calculating a time-shift value for each received waveform based on said calculated moveout; applying said time-shift values to said received waveforms, thereby aligning a dominating copy of said source signature; and stacking said time-shifted waveforms, thereby producing an estimation of said source signature.

Claim 3

The method of claim 1, said method further comprising the step of: deconvolving said time-shifted waveforms, thereby reducing said time-shifted waveforms to waveforms which would substantially result from said source characterized as an impulse.

Claim 4

The method of claim 2, wherein the step of deconvolving said time-shifted waveforms comprises the step of: obtaining a deconvolution function based on dividing the complex conjugate of said estimated source signature at a given frequency by the amplitude squared of said estimated source signature at the given frequency; and applying said deconvolution function to said time-shifted waveforms.

Claim 5

The method of claim 3, wherein the step of obtaining said deconvolution function further includes the steps of: calculating the energy of the estimated source signature at the given frequency; calculating the average energy of the received waveforms at the given frequency; and multiplying said quotient by the ratio of said energy of the estimated source signature to said average energy of the received waveforms; and multiplying said product by a factor related to said time-shift values.

Claim 6

The method of claim 4, said method further comprising the step of: multiplying said estimated source signature by said deconvolution function, thereby characterizing said estimated source signature as an impulse.

Claim 7

The method of claim 1, said method further comprising the step of: deconvolving said received waveforms, thereby reducing said received waveforms to waveforms which would substantially result from said source characterized as an impulse.

Claim 8

The method of claim 6, wherein the step of deconvolving said received waveforms comprises the step of: obtaining a deconvolution function based on dividing the complex conjugate of said estimated source signature at a given frequency by the amplitude squared of said estimated source signature at the given frequency; and applying said deconvolution function to said received waveforms.

Claim 9

The method of claim 7, wherein the step of obtaining said deconvolution function further includes the steps of: calculating the energy of the estimated source signature at the given frequency; calculating the average energy of the received waveforms at the given frequency; and multiplying said quotient by the ratio of said energy of the estimated source signature to said average energy of the received waveforms.

Claim 10

The method of claim 8, said method further comprising the step of: multiplying said estimated source signature by said deconvolution function, thereby characterizing said estimated source signature as an impulse.

Claim 11

The method of claim 1, wherein the step of calculating the moveout of the received seismic waveforms comprises the steps of: calculating a local slant stack for each received waveform; calculating a local energy content for each local slant stack; and calculating said moveout based on the calculated local energy content.

Claim 12

The method of claim 1, wherein the step of calculating said moveout of said received seismic waveforms comprises the steps of: calculating the cross-correlation between adjacent received waveforms; and calculating said moveout based on the calculated cross-correlation.

Claim 13

The method of claim 1, wherein the step of stacking said time-shifted waveforms comprises the steps of: weighting said time-shifted waveforms; and stacking said weighted time-shifted waveforms.

Claim 14

The method of claim 12, wherein the step of weighting said time-shifted waveforms comprises the step of: weighting each of said time-shifted waveforms by a factor related to an expected difference in moveout between wavefronts from direct arrivals and wavefronts due to subsurface reflections.

Claim 15

The method of claim 13, wherein said factor is w m , wherein ##EQU19## wherein (x O , z O ) represents the horizontal and vertical position, respectively, of the source; and (x m , z m ) represents the horizontal and vertical position, respectively, of the receiver corresponding to its respective time-shifted waveforms.

Claim 16

The method of claim 1, wherein said source includes noise emanating from a drill bit while the drill bit is in operation in the borehole.

Claim 17

The method of claim 1, wherein the steps of calculating the moveout of the received seismic waveforms and calculating a time-shift value for each received waveform comprises the steps of: determining a time-shift curve from a family of time-shift curves such that the stacking coherency along said determined curve is maximum, relative to the other curves in said family of curves; applying said time shifts associated with said determined curve to said received waveforms, thereby approximately aligning a dominating copy of said source signature; stacking said time-shifted waveforms, thereby producing an initial estimation of said source signature; deconvolving said time-shifted waveforms, thereby reducing said time-shifted waveforms to an initial estimate of waveforms which would substantially result from said source characterized as an impulse; determining, at each offset, the time at which the peak amplitude occurs in said initial estimate, thereby obtaining an improved estimate of the time-shift curve associated with said dominating moveout; and calculating a time-shift value for each received waveform based on said improved estimate of the time-shift curve.

Claim 18

The method of claim 16, wherein said family of time-shift curves are a function of depth and velocity.

Claim 19

The method of claim 17, wherein said family of time-shift curves are based on the following equation: ##EQU20## where z represents depth; c represents velocity; t(x) represents the curve; and x represents the receiver offset location.

Claim 20

The method of claim 16, wherein, in said step of determining a time-shift curve from a family of time-shift curves, said stacking coherency is based on the following stacking equation: ##EQU21## where N represents the number of frequencies in the Fourier Transform of said received waveforms; M represents the number of receivers; s m represents the waveform at receiver m after Fourier transformation; and x m represents offset location x of receiver m.

Claim 21

In a method of deconvolving waveforms of seismic data obtained from a source located in a borehole and a plurality of receivers located above the source, the source having a time-extended signature, the method of obtaining a deconvolution function therefor, said method comprising the steps of: dividing the complex conjugate of said source signature at a given frequency by the amplitude squared of said source signature at a given frequency; calculating the energy of the source signature at the given frequency; calculating the average energy of the seismic waveforms at the given frequency; and multiplying said quotient by the ratio of said energy of the source signature to said average energy of the seismic waveforms, thereby obtaining said deconvolution function.

Claim 22

In a method of deconvolving waveforms of seismic data obtained from a source located in a borehole and a plurality of receivers located above the source, the source having a time-extended signature, the method of obtaining a deconvolution function therefor, said method comprising the steps of: dividing the complex conjugate of said source signature at a given frequency by the amplitude squared of said source signature at a given frequency; calculating the energy of the source signature at the given frequency; calculating the average energy of the seismic waveforms at the given frequency; and multiplying said quotient by the ratio of said energy of the source signature to said average energy of the seismic waveforms, thereby obtaining said deconvolution function.

Claim 23

The method of claim 20, said method further comprising the steps of: calculating a dominating moveout of said seismic waveforms; calculating a time-shift value for each seismic waveform based on said calculated moveout; and multiplying said deconvolution function by a factor related to said time-shift values.