Downhole whirl detection while drilling

• US 9,926,779 B2
• Filed: 05/01/2013
• Issued: 03/27/2018
• Est. Priority Date: 11/10/2011
• Status: Active Grant

• Current Assignee: Schlumberger Technology Corporation (SLB)
• Original Assignee: Schlumberger Technology Corporation (SLB)
• Inventors: Sugiura, Junichi
• Primary Examiner(s): Vargas, Manuel Rivera
• Assistant Examiner(s): Bermudez, Yaritza Perez
• Application Number:
  US13/874,814
• Publication Number:
  US 20130248247A1
• Time in Patent Office: 1,791 Days
• CPC Class Codes: E21B 44/00 Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
• CPC Class Codes: E21B 47/12 Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
• CPC Class Codes: G16Z 99/00 Subject matter not provided for in other main groups of this subclass

Abstract

A method for making downhole whirl measurements in a drill string includes rotating a sensor set in a borehole. The sensor set is deployed in the drill string and includes at least one cross-axial accelerometer and at least one cross-axial magnetometer. Sensor measurements, including a plurality of accelerometer measurements and a plurality of magnetometer measurements made at predetermined measurement intervals, may be obtained while drilling and used to compute a whirl magnitude.

Claims

1. A method for making downhole whirl measurements while drilling a subterranean borehole, the method comprising:

(a) deploying a drill string in the subterranean borehole, the drill string including a drill bit and a sensor set, the sensor set including at least one cross-axial accelerometer and at least one cross-axial magnetometer;

(b) rotating the drill string in the borehole such that the drill bit drills the borehole and the sensor set rotates and accelerates in the borehole;

(c) causing the at least one cross-axial accelerometer to make a plurality of acceleration measurements at predetermined measurement intervals while rotating the drill string in act (b);

(d) causing the at least one cross-axial magnetometer to make a plurality of magnetic field measurements at predetermined measurement intervals while rotating the drill string in act (b);

(e) processing the plurality of acceleration measurements made in act (c) and/or the plurality of magnetic field measurements made in act (d) to compute a rotation frequency of the drill string in act (b);

(f) multiplying the rotation frequency of the drill string computed in act (e) by (N+1) to compute a whirl frequency, wherein N represents a number of blades on the drill bit;

(g) processing the plurality of acceleration measurements made in act (c) to compute a whirl magnitude of the drill bit at the whirl frequency computed in act (f); and

(h) adjusting at least one drilling parameter based on the whirl magnitude of the drill bit, wherein the at least one drilling parameter is selected from the group consisting of weight on bit, drill string rotation rate, and drilling fluid flow rate.

2. The method of claim 1, wherein said processing in act (g) further comprises applying a digital band pass filter to the plurality of acceleration measurements made in act (c), the band pass filter having a center frequency substantially equal to the whirl frequency computed in act (f).

3. The method of claim 1, wherein said processing in act (g) further comprises transforming the plurality of acceleration measurements made in act (c) to a frequency domain and obtaining a signal amplitude of said transformed accelerometer measurements at a frequency substantially equal to the whirl frequency computed in act (f).

4. The method of claim 1, wherein said processing in act (e)-further comprises differentiating the plurality of magnetic field measurements made in act (d) to obtain the rotation frequency of the drill string.

5. The method of claim 1, further comprising:

(i) transmitting the whirl magnitude to a surface location; and

(j) processing the whirl magnitude at the surface location to automatically adjust the at least one drilling parameter.

6. A method for making downhole whirl measurements while drilling a subterranean borehole, the method comprising:

(a) deploying a drill string in the subterranean borehole, the drill string including a drill bit and a navigational sensor set, the navigational sensor set including at least a tri-axial accelerometer set and a tri-axial magnetometer set;

(b) rotating the drill string in the borehole such that the drill bit drills the borehole and the navigational sensor set rotates and accelerates in the borehole;

(c) causing the tri-axial accelerometer set to make a plurality of acceleration measurements at predetermined measurement intervals while rotating in act (b);

(d) causing the tri-axial magnetometer set to make a plurality of magnetic field measurements at predetermined measurement intervals while rotating in act (b);

(e) processing the plurality of acceleration measurements made in act (c) and/or the plurality of magnetic field measurements made in act (d) to compute a rotation frequency of the drill string in act (b);

(f) computing a bit whirl frequency according to the following equation;

ω

_whirl=ω

·

(N+1);

wherein ω

_whirl represents the bit whirl frequency, ω

represents the rotational frequency of the drill string computed in act (e), and N represents number of blades on the drill bit;

(g) processing the plurality of acceleration measurements made in act (c) to compute a whirl magnitude of the drill bit at the whirl frequency computed in act (f); and

(h) adjusting at least one drilling parameter based on the whirl magnitude of the drill bit, wherein the at least one drilling parameter is selected from the group consisting of weight on bit, drill string rotation rate, and drilling fluid flow rate.

7. The method of claim 6, wherein said processing in act (g) further comprises applying a digital band pass filter to the plurality of acceleration measurements made in act (c), the band pass filter having a center frequency substantially equal to the whirl frequency computed in act (f).

8. The method of claim 7, wherein the digital band pass filter is computed downhole based upon the bit whirl frequency computed in act (f).

9. The method of claim 7, wherein the digital band pass filter is selected from tool memory based upon the bit whirl frequency computed in act (f).

10. The method of claim 6, wherein said processing in act (g) further comprises transforming the plurality of acceleration measurements made in act (c) to a frequency domain and obtaining a signal amplitude of said transformed accelerometer measurements at a frequency substantially equal to the whirl frequency computed in act (f).

11. The method of claim 10, wherein the plurality of acceleration measurements are transformed to the frequency domain using a Fast Fourier Transform.

12. The method of claim 6, wherein said processing in act (e) further comprises differentiating the plurality of magnetic field measurements made in act (d) to obtain the rotation frequency of the drill string.

13. The method of claim 6, wherein the navigational sensor set is deployed in the drill string within two meters of the drill bit.

14. The method of claim 6, wherein the predetermined measurement interval is in the range from about 0.0001 to about 0.1 second.

15. The method of claim 6, further comprising:

(i) transmitting the bit whirl magnitude to a surface location.

16. The method of claim 15, further comprising:

(j) processing the whirl magnitude at the surface location to automatically adjust the at least one drilling parameter.

17. The method of claim 16, wherein act (j) further comprises processing a stick/slip measurement to automatically adjust the at least one drilling parameter.