GEOSTEERING BOREHOLES USING DISTRIBUTED ACOUSTIC SENSING

• US 20150159478A1
• Filed: 12/09/2013
• Published: 06/11/2015
• Est. Priority Date: 12/09/2013
• Status: Active Grant

• Current Assignee: Baker Hughes Incorporated (Baker Hughes Company)
• Original Assignee: Baker Hughes Incorporated (Baker Hughes Company)
• Inventors: Georgi, Daniel T., Csutak, Sebastian
• Granted Patent: US 9,556,723 B2
• Time in Patent Office: Days
• US Class Current: 1/1
• CPC Class Codes: E21B 47/0224 using seismic or acoustic means
• CPC Class Codes: E21B 7/046 horizontal drilling drilling with mechanical conveying means E21B7/003

Abstract

A method of estimating position of a borehole includes: disposing an acoustic sensor in a first borehole in an earth formation, the acoustic sensor including a plurality of measurement locations disposed along a length of the first borehole; drilling a portion of a second borehole in the earth formation using a drilling assembly; taking distributed acoustic measurement data over a time period during the drilling by the plurality of measurement locations, the acoustic measurement data based at least in part due to an acoustic signal generated by the drilling assembly and detected by the plurality of measurement locations; processing the measurement data to estimate a distance between the drilling assembly and the acoustic sensor; and controlling directional parameters of the drilling based on the distance.

Claims

1. A method of estimating position of a borehole, comprising:

disposing an acoustic sensor in a first borehole in an earth formation, the acoustic sensor including a plurality of measurement locations disposed along a length of the first borehole;

drilling a portion of a second borehole in the earth formation using a drilling assembly;

taking distributed acoustic measurement data over a time period during the drilling by the plurality of measurement locations, the acoustic measurement data based at least in part due to an acoustic signal generated by the drilling assembly and detected by the plurality of measurement locations;

processing the measurement data to estimate a distance between the drilling assembly and the acoustic sensor; and

controlling directional parameters of the drilling based on the distance.

2. The method of claim 1, wherein the acoustic signal is generated by contact between a drill bit of the drilling assembly and the formation.

3. The method of claim 1, wherein processing the measurement data includes calculating a direction to the second borehole associated with the distance.

4. The method of claim 1, wherein processing the measurement data includes estimating the distance based on a travel time of the acoustic signal between the drilling assembly and the acoustic sensor.

5. The method of claim 4, wherein processing the measurement data includes estimating the distance based on the travel time and a compressional wave velocity associated with the formation.

6. The method of claim 1, wherein the measurement data includes a plurality of traces collected over the time period, each of the plurality of traces associated with one of the plurality of measurement locations.

7. The method of claim 6, wherein processing the measurement data includes cross-correlating the plurality of traces and calculating a cross-correlation maximum associated with each trace.

8. The method of claim 7, wherein processing the measurement data includes performing a fit of the cross-correlation maximum associated with each trace with a hyperbolic function, and calculating a time origin of the acoustic signal based on the fit.

9. The method of claim 8, wherein processing the measurement data includes selecting a trace associated with an apex of the hyperbolic function, and calculating the distance based on the time of receipt of the acoustic signal at the selected trace and a compressional wave velocity associated with the formation.

10. The method of claim 1, wherein the first borehole is one of an injection borehole and a production borehole of a steam assisted gravity drainage (SAGD) system, and the second borehole is another of the injection borehole and the production borehole.

11. A system for estimating a position of a borehole, comprising:

an acoustic sensor disposed in a first borehole in an earth formation, the acoustic sensor including a plurality of measurement locations disposed along a length of the first borehole;

a processor configured to perform;

receiving acoustic measurement data from the plurality of measurement locations over a time period during drilling by a drilling assembly of a portion of a second borehole in the earth formation, the acoustic measurement data based at least in part on an acoustic signal generated by the drilling assembly and detected by the plurality of measurement locations; and

processing the measurement data to estimate a distance between the drilling assembly and the acoustic sensor.

12. The system of claim 11, wherein the acoustic signal is generated by contact between a drill bit of the drilling assembly and the formation.

13. The system of claim 11, wherein the acoustic sensor includes at least one distributed acoustic sensing (DAS) optical fiber.

14. The system of claim 11, wherein the acoustic sensor includes an array of discrete multi-axial acoustic sensors arrayed along the length of the first borehole.

15. The system of claim 11, wherein processing the measurement data includes estimating the distance based on a travel time of the acoustic signal between the drilling assembly and the acoustic sensor, and a compressional wave velocity associated with the formation.

16. The system of claim 11, wherein the measurement data includes a plurality of traces collected over the time period, each of the plurality of traces associated with one of the plurality of measurement locations.

17. The system of claim 16, wherein processing the measurement data includes cross-correlating the plurality of traces and calculating a cross-correlation maximum associated with each trace.

18. The system of claim 17, wherein processing the measurement data includes performing a fit of the cross-correlation maximum associated with each trace with a hyperbolic function, and calculating a time origin of the acoustic signal based on the fit.

19. The system of claim 18, wherein processing the measurement data includes selecting a trace associated with an apex of the hyperbolic function, and calculating the distance based on the time of receipt of the acoustic signal at the selected trace and a compressional wave velocity associated with the formation.

20. The system of claim 11, wherein the first borehole is one of an injection borehole and a production borehole of a steam assisted gravity drainage (SAGD) system, and the second borehole is another of the injection borehole and the production borehole.