Reservoir mapping with fracture pulse signal

1. A method for determining a subsurface fluid seismic attribute comprising:

a) recording a signal at a wellhead related to pumping fracture stimulation fluid to obtain a pressure pulse pump signal;

b) determining a deconvolution operator from the obtained pressure pulse pump signal, the deconvolution operator determined using one or more of: i) cross-correlation of a plurality of pairs of seismic signals, ii) eigenstructure decomposition, and iii) semblance calculations;

c) acquiring seismic data from a plurality of sensors;

d) computing travel time differences for the seismic data between the plurality of sensor locations and the subsurface position;

e) deconvolving the seismic data with the deconvolution operator to obtain a plurality of deconvolution coefficients associated with the subsurface position; and

f) using the computed travel time differences to sum the plurality of deconvolution coefficients associated with the subsurface position to obtain a subsurface fluid seismic attribute at the subsurface position.

2. The method of claim 1 wherein computing travel times further comprises:

using velocities derived from at least one selected from the group consisting of i) a perforation shot, ii) a string shot, iii) surface seismic data, iv) a check shot and v) VSP data.

3. The method of claim 1 further comprising acquiring the seismic data while fluids are injected into subsurface formations through a port in a well bore.

4. The method of claim 1 wherein the plurality of sensors are three-component sensors.

5. The method of claim 1 further comprising storing the obtained coefficients associated with subsurface locations in a form for display.

6. A method of determining a pressure pulse seismic signal value in the subsurface comprising:

a) acquiring seismic data from a plurality of sensors;

b) acquiring a pressure reference signal from a pressure sensor associated with a pipe through which fluids are pumped into the earth;

c) computing a deconvolution output from seismic data associated with the plurality of sensors and the reference signal acquired from the pressure reference signal, the deconvolution output computed using one or more of: i) cross-correlation of a plurality of pairs of seismic signals, ii) eigenstructure decomposition, and iii) semblance calculations;

d) computing travel time differences for the seismic data between the plurality of sensor locations and the subsurface position;

e) summing the computed deconvolution output with the computed travel time differences to obtain a pressure pulse seismic signal value associated with the subsurface position.

7. The method of claim 6 wherein computing travel times further comprises:

using velocities derived from at least one selected from the group consisting of i) a perforation shot, ii) a string shot, iii) surface seismic data, iv) a check shot and v) VSP data.

8. The method of claim 6 further comprising acquiring the seismic data while fluids are injected into subsurface formations through a port in a well bore.

9. The method of claim 6 wherein the plurality of sensors are three-component sensors.

10. The method of claim 6 further comprising storing the obtained coefficients associated with subsurface locations in a form for display.

11. An information handling system for determining a subsurface fluid seismic attribute in the subsurface associated with pumping fracture stimulation fluid comprising:

a) a processor configured for computing travel time differences between a subsurface position and a plurality of sensors that acquired the seismic data;

b) a computer readable medium for storing travel time differences for the seismic data between the plurality of sensor locations and the subsurface position;

c) a processor configured for determining a deconvolution operator from a pressure pump signal associated with a wellhead related to pumping fracture stimulation fluid, the deconvolution operator determined using one or more of: i) cross-correlation of a plurality of pairs of seismic signals, ii) eigenstructure decomposition, and iii) semblance calculations;

d) a processor configured for using travel time differences to sum a plurality of deconvolution coefficients associated with the subsurface position to obtain a subsurface fluid seismic attribute at the subsurface position.