Method for evaluating and improving drilling operations

• US 7,899,658 B2
• Filed: 02/28/2006
• Issued: 03/01/2011
• Est. Priority Date: 10/11/2000
• Status: Expired due to Term

• Current Assignee: Smith International Incorporated (SLB)
• Original Assignee: Smith International Incorporated (SLB)
• Inventors: Oliver, Stuart, Paez, Luis C., Huang, Sujian J., Aslaksen, Halle
• Primary Examiner(s): JONES, HUGH M
• Application Number:
  US11/365,065
• Publication Number:
  US 20060149518A1
• Time in Patent Office: 1,827 Days
• Field of Search: 703/2, 703 6- 7, 703/10, 175/331, 175/375
• US Class Current: 703/10
• CPC Class Codes: E21B 10/00 Drill bits specially adapted for deflecting the direction of boring E21B7/064; with means for collecting substances E21B27/00
• CPC Class Codes: E21B 10/16 characterised by tooth form or arrangement
• 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: G06F 30/17 Mechanical parametric or variational design

Abstract

A method for improving drilling performance of a drilling tool assembly is disclosed. The method includes identifying a drilling performance parameter to be improved. One or more potential solutions are defined to improve the drilling performance parameter. A drilling simulation is performed to determine the dynamic response of the drilling tool assembly during a drilling operation. Determining the dynamic response includes determining the interaction of a cutting element of a drill bit with an earth formation. Improvement in the drilling performance parameter is determined based upon the drilling simulation.

Claims

1. A method of controlling a directional aspect of a drilling tool assembly comprising:

(a) identifying a desired wellbore trajectory;

(b) defining at least one potential solution to obtain the desired wellbore trajectory;

(c) performing a drilling simulation of the at least one potential solution;

(d) determining, based on the performing the drilling simulation, whether the simulated potential solution achieves the identified desired wellbore trajectory;

(e) repeating steps (b)-(d) until the desired wellbore trajectory is achieved; and

(f) outputting the solution that achieves the desired wellbore trajectory.

2. The method of claim 1, wherein the desired wellborn trajectory is defined by at least one of a build angle, a dogleg severity, and a walk rate.

3. The method of claim 1, further comprising calculating an anisotropy index of an earth formation and inputting the anisotropy index in the drilling simulation.

4. The method of claim 1, wherein the outputting comprises a graphical visualization of at least one of the drilling tool assembly, the earth formation, and the wellbore trajectory.

5. The method of claim 4, wherein the graphical visualization is a three-dimensional representation.

6. The method of claim 1, further comprising controlling a drilling tool assembly comprising the outputted solution.

7. The method of claim 6, wherein the controlling comprises using the drilling tool assembly to drill a well.

8. The method of claim 7, further comprising:

obtaining post-run drilling information collected during the using the solution; and

determining a degree to which the drilling performance parameter has improved.

9. A method for improving control of a drilling tool assembly drilling an earth formation comprising:

simulating the drilling tool assembly drilling the earth formation;

calculating, based on the simulating, at least one of a dogleg severity, a build angle, and a walk rate;

determining a force required to generate the build angle, the dogleg severity, or the walk rate for the drilling tool assembly;

determining controllability of the drilling tool assembly based on the force required to generate the build angle, the dogleg severity, or the walk rate for the drilling tool assembly;

adjusting a component of the drilling tool assembly;

repeating the simulating, calculating, and determining for the adjusted drilling tool assembly;

comparing the controllability of the drilling tool assembly and the adjusted drilling tool assembly; and

outputting a drilling tool assembly design based on the controllability.

10. The method of claim 9, wherein the outputting comprises a graphical visualization of drilling tool assembly.

11. The method of claim 10, further comprising outputting a graphical visualization of at least one of the drilling tool assembly drilling the earth formation and the wellbore trajectory.

12. The method of claim 9, wherein the simulating models the drilling tool assembly drilling the earth formation in increments of time.

13. The method of claim 12, wherein the simulating models the drilling tool assembly drilling the earth formation in increments of depth.

14. The method of claim 9, further comprising inputting geological information, wherein the geological information comprises well survey data from offset wells.

15. A method for designing a drilling tool assembly with a desired walk rate comprising:

simulating the drilling tool assembly drilling the earth formation;

calculating a walk rate of the drilling tool assembly;

comparing the calculated walk rate with a desired walk rate;

adjusting a component of a drilling tool assembly based on the comparing;

repeating the simulating, calculating, comparing, and adjusting until the calculated walk rate achieves the desired walk rate; and

outputting the drilling tool configuration that corresponds to the desired walk rate.

16. The method of claim 15, wherein the simulating comprises defining at least one of a rate of penetration and a revolution per minute of the drilling tool assembly in the earth formation.

17. The method of claim 15, wherein the adjusting a component comprises adjusting a location of a component of the drilling tool assembly on the drilling tool assembly.

18. The method of claim 15, further comprising modeling the drilling tool assembly and the earth formation.

19. The method of claim 18, wherein the modeling of the earth formation is generated in increments of depth.

20. The method of claim 18, wherein the modeling of the earth formation is generated in increments of time.