Methods for positioning a well for optimal fluid production
Provided are methods of locating a well bore to optimize fluid extraction from a region of interest. In this manner, well production may be better predicted without having to go through the time and effort of drilling exploratory-type wells. The methods analyze semblance values of voxels within a full activity volume, and identify near well activity (NWA) voxels based on voxels that exceed the mean semblance value by a cut-off value. For example, the cut-off value may correspond to one or two standard deviations greater than the mean semblance value. Optimal fluid recovery corresponds to a well bore location at or near the putative location corresponding to the maximum number of NWA voxels in the region of interest.
1. A method for locating a well bore for fluid recovery, the method comprising the steps of:
acquiring a full activity volume (FAV) for a reservoir of interest from seismic energy generated by a country rock within the reservoir of interest, wherein the FAV comprises a plurality of voxels;
calculating a characteristic semblance value for all the voxels and a user-selected semblance statistical value of the characteristic semblance value over all the voxels, thereby obtaining a measure of a permeability field for the reservoir of interest;
determining a threshold semblance value (TSV) by identifying all voxels having a semblance value that is greater than or equal to the user-selected semblance statistical value above the characteristic semblance value, thereby mapping the permeability field;
identifying near well activity (NWA) voxels corresponding to the TSV voxels identified in the mapped permeability field;
wherein the NWA voxels correspond to a putative well bore location, thereby locating the well for fluid recovery from the mapped permeability field; and
wherein the semblance value is a time-varying semblance value.
2. The method of claim 1 , further comprising the step of determining a maximum number of NWA voxels in direct and/or indirect contact with the putative well bore location.
3. The method of claim 2 , wherein the maximum number of NWA voxels further comprises voxels directly adjacent to the voxels in direct contact with the putative well location or that is connected indirectly to the putative well location via an one or more intervening voxel.
4. The method of claim 2 , further comprising the steps of:
determining the maximum number of NWA voxels for a plurality of putative well bore locations; and
identifying an optimal well bore location corresponding to the putative well bore location having a highest maximum number of NWA voxels.
5. The method of claim 1 , wherein the fluid is a liquid and the liquid recovery of the well bore positioned at the putative well bore location is proportional to a total number of NWA voxels.
6. The method of claim 1 , wherein the acquiring the FAV step comprises using one or more of:
a 3D seismic survey;
a geophone surface array;
a geophone buried array; or
any combination thereof;
for a reservoir of interest.
7. The method of claim 1 , wherein the user-selected semblance statistical value is one standard deviation or greater.
8. The method of claim 1 , wherein the determining the TSV step is by identifying all voxels having the semblance value that are greater than two standard deviations of the characteristic semblance value, wherein the characteristic semblance value is a mean semblance value.
9. The method of claim 1 , wherein the fluid recovery is for recovery of hydrocarbon or water.
10. The method of claim 1 , wherein each voxel has a volume of between 5 m 3 and 12 m 3 .
11. The method of claim 1 , wherein the reservoir of interest has a volume of between 1 km 3 and 1000 km 3 .
12. The method of claim 1 , further comprising the step of populating a 3D volume representation of the reservoir of interest with the NWA voxels and not populating the 3D volume with voxels having a semblance value less than the semblance value of the NWA voxels, thereby visualizing the NWA voxels.
13. The method of claim 1 , further comprising the step of drilling a well bore in the reservoir of interest at a location corresponding to the putative well bore location having the highest maximum number of NWA voxels.
14. The method of claim 1 , wherein the semblance value is determined for multiple time periods.
15. The method of claim 1 , wherein the step of acquiring the FAV comprises: imaging the reservoir of interest for a period of time, the period of time ranging up to 24 hours and at a sampling rate of between 100 Hz and 2 KHz.
16. The method of claim 1 , wherein the FAV is obtained for a time range that is between 0.5 s and 100 days.