Analysis of drillstring dynamics using an angular rate sensor

• US 10,480,304 B2
• Filed: 10/12/2012
• Issued: 11/19/2019
• Est. Priority Date: 10/14/2011
• Status: Expired due to Fees

• Current Assignee: Weatherford Technology Holdings, LLC (Weatherford International PLC)
• Original Assignee: Weatherford Technology Holdings, LLC (Weatherford International PLC)
• Inventors: Mauldin, Charles Lee, Bartel, Roger P., Berns, Richard
• Primary Examiner(s): Hutton, Jr., William D
• Assistant Examiner(s): MacDonald, Steven A
• Application Number:
  US13/651,138
• Publication Number:
  US 20130092439A1
• Time in Patent Office: 2,594 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 44/005 Below-ground automatic control systems

Abstract

Downhole drilling vibration analysis uses an angular rate sensor on a drilling assembly. During drilling operations, the sensor measures the angular rate of the drilling assembly. Processing circuitry is operatively coupled to the angular rate sensor and is configured to determine whether torsional type vibrations are occurring during drilling based on the angular rate data. Drilling operations can then be modified to overcome or mitigate the torsional type vibrations.

Claims

1. A downhole drilling vibration analysis method, comprising:

drilling a borehole with a drilling assembly having at least one angular rate sensor;

determining angular positions of the drilling assembly about a circumference of the borehole while drilling downhole;

measuring instantaneous angular rates of the drilling assembly with the at least one angular rate sensor while drilling downhole;

analyzing changes of the measured instantaneous angular rates occurring at least at a plurality of the determined angular positions of the drilling assembly about the circumference of the borehole by determining, at which of the angular positions of the drilling assembly about the circumference of the borehole, decrease in the instantaneous angular rates occurs, the decrease being indicative of a sticking of the drilling assembly at the determined angular position; and

determining that torsional vibration is occurring during drilling based on the analysis.

2. The method of claim 1, wherein measuring the instantaneous angular rates of the drilling assembly with the at least one angular rate sensor while drilling downhole comprises measuring the instantaneous angular rates with an angular rate gyroscope responsive to Coriolis acceleration.

3. The method of claim 1, wherein analyzing the changes of the measured instantaneous angular rates occurring at least at the plurality of the determined angular positions of the drilling assembly about the circumference of the borehole comprises determining, from the changes, a pattern of vibration per one or more revolutions of the drilling assembly.

4. The method of claim 3, wherein determining that torsional vibration is occurring during drilling based on the analysis comprises determining a severity measure of the torsional vibration based on one or more aspects of the determined pattern.

5. The method of claim 1, wherein analyzing the changes of the measured instantaneous angular occurring at least at the plurality of the determined angular positions of the drilling assembly about the circumference of the borehole comprises determining, from the changes, one or more cycles of increased angular rate of the measured instantaneous angular rates per one or more revolutions of the drilling assembly.

6. The method of claim 5, wherein determining that torsional vibration is occurring during drilling based on the analysis comprises calculating a torsional vibration measure, indicative of the torsional vibration, based on a number of the one or more cycles.

7. The method of claim 5, wherein determining that torsional vibration is occurring during drilling based on the analysis comprises calculating a torsional vibration measure, indicative of the torsional vibration, based on an amplitude of the one or more cycles.

8. The method of claim 1, wherein analyzing the changes of the measured instantaneous angular rates occurring at least at the plurality of the determined angular positions of the drilling assembly about the circumference of the borehole comprises determining, from the changes, vibration over revolutions over time of the drilling assembly.

9. The method of claim 8, wherein determining that torsional vibration is occurring during drilling based on the analysis comprises calculating a torsional vibration measure, indicative of the torsional vibration, based on a frequency of the vibration over the revolutions over time of the drilling assembly.

10. The method of claim 1, wherein determining that torsional vibration is occurring during drilling based on the analysis further comprises augmenting the determination by calculating a dimensionless measure relating a maximum revolutions over time, a minimum revolutions over time, and an average revolutions over time.

11. The method of claim 1, wherein the at least one angular rate sensor comprises at least two angular rate sensors displaced along the drilling assembly.

12. The method of claim 11, wherein measuring the instantaneous angular rates comprises measuring the instantaneous angular rates about a same axis with the at least two angular rate sensors downhole while drilling with the drilling assembly.

13. The method of claim 11, wherein analyzing the measured instantaneous angular rates comprises comparing the instantaneous angular rates from the at least two angular rate sensors.

14. The method of claim 13, wherein determining that torsional vibration is occurring during drilling based on the analysis comprises determining an aspect of at least one of bending and twisting of the drilling assembly based on the comparison.

15. The method of claim 1, further comprising changing one or more operating parameters of the drilling assembly based on the determined torsional vibration.

16. The method of claim 15, wherein changing the one or more operating parameters of the drilling assembly comprises changing one or more of weight on bit, rotational speed, torque, pump rate, mud flow rate, and mud motor operation.

17. The method of claim 15, wherein changing the one or more operating parameters comprises operating a drilling interrupting mechanism on the drilling assembly based on the determined torsional vibration.

18. The method of claim 1, wherein analyzing the changes and determining the torsional vibration comprises at least partially processing the measured angular rate data downhole at the drilling assembly.

19. The method of claim 18, wherein analyzing the changes and determining the torsional vibration comprises communicating the at least partially processed angular rate data from the drilling assembly to the surface.

20. The method of claim 19, wherein analyzing the changes and determining the torsional vibration comprises completing processing of the measured angular rate data downhole at the surface.

21. The method of claim 1, wherein determining the angular positions of the drilling assembly about the circumference of the borehole while drilling downhole comprises measuring orientations of magnetometers with respect to the earth'"'"'s magnetic field and calculating the angular positions from the measured orientations.

22. The method of claim 1, wherein determining the angular positions of the drilling assembly about the circumference of the borehole while drilling downhole comprises measuring orientations of accelerometers with respect to the earth'"'"'s gravitational field and calculating the angular positions from the measured orientations.

23. The method of claim 1, wherein measuring the instantaneous angular rates of the drilling assembly with the at least one angular rate sensor while drilling downhole comprises measuring magnitudes related to tangential speed, per angular position, per time.

24. The method of claim 1, wherein determining the angular positions of the drilling assembly about the circumference of the borehole while drilling downhole comprises at least periodically determining a geometric reference of the angular positions of the drilling assembly within the borehole during drilling.

25. The method of claim 1, further comprising at least periodically determining bias of the at least one angular rate sensor when rotation of the drilling assembly is stopped, wherein measuring the instantaneous angular rates comprises correcting the measurements for the determined bias.

26. The method of claim 1, wherein analyzing the changes of the measured instantaneous angular rates occurring at least at the plurality of the determined angular positions of the drilling assembly about the circumference of the borehole further comprises determining, at which of the angular positions of the drilling assembly about the circumference of the borehole, increase in the instantaneous angular rates occurs, the increase being indicative of a slipping of the drilling assembly at the determined angular position.

27. The method of claim 1, wherein determining that the torsional vibration is occurring during drilling based on the analysis comprises determining the torsional vibration selected from the group consisting of stick-slip, bit whirl, precessional movement, forward whirl, backward whirl, torsional variation, elastic deformation, bending, twisting, and combinations thereof.

28. A downhole drilling vibration analysis method, comprising:

drilling a borehole with a drilling assembly having an angular rate sensor;

determining rotational positions of the drilling assembly about a circumference of the borehole while drilling downhole;

measuring instantaneous rotational speeds of the drilling assembly with the angular rate sensor while drilling downhole;

analyzing changes of the measured instantaneous rotational speeds occurring at least at a plurality of the determined rotational positions of the drilling assembly about the circumference of the borehole by determining, at which of the determined rotational positions, decrease and/or increase in the instantaneous rotational speeds occurs, the decrease being indicative of a sticking of the drilling assembly at the determined rotational position, the increase being indicative of a slipping of the drilling assembly at the determined rotational position; and

determining that torsional vibration is occurring during drilling based on the analysis.

29. A drilling assembly for drilling a borehole, the assembly comprising:

a drill collar disposed on a drill string;

a drill bit disposed on the drill collar;

a sensor element disposed on the drill collar and determining angular positions of the drilling assembly about a circumference of the borehole while drilling downhole, the sensor element including at least one angular rate sensor measuring instantaneous angular rates downhole while drilling with the drilling assembly; and

processing circuitry in communication with the sensor element, the processing circuitry is configured to;

analyze changes of the measured instantaneous angular rates occurring at least at a plurality of the determined angular positions of the drilling assembly about the circumference of the borehole to determine, at which of the angular positions of the drilling assembly about the circumference of the borehole, decrease in the instantaneous angular rates occurs, the decrease being indicative of a sticking of the drilling assembly at the determined angular position, and

determine that torsional vibration is occurring during drilling based on the analysis.

30. The assembly of claim 29, wherein the at least one angular rate sensor comprises an angular rate gyroscope responsive to Coriolis acceleration.

31. The assembly of claim 29, wherein the processing circuitry comprises first circuitry disposed on the drill collar.

32. The assembly of claim 29, wherein the processing circuitry comprises second circuitry disposed at the surface.

33. The assembly of claim 29, further comprising telemetry unit communicating information indicative of the torsional vibration from the drill collar to the surface.

34. The assembly of claim 29, further comprising a mechanism disposed on the drilling assembly and operable to interrupt drilling by the drill bit.

35. The system of claim 29, wherein to analyze the changes of the measured instantaneous angular rates occurring at least at a plurality of the determined angular positions of the drilling assembly about the circumference of the borehole, the processing circuitry is configured to:

determine, at which of the angular positions of the drilling assembly about the circumference of the borehole, increase in the instantaneous angular rates occurs, the increase being indicative of a slipping of the drilling assembly at the determined angular position.

36. A downhole drilling vibration analysis method, comprising:

drilling a borehole with a drilling assembly having at least one angular rate sensor;

determining angular positions of the drilling assembly about a circumference of the borehole while drilling downhole;

measuring instantaneous angular rates of the drilling assembly with the at least one angular rate sensor while drilling downhole;

analyzing changes of the measured instantaneous angular rates occurring at least at a plurality of the determined angular positions of the drilling assembly about the circumference of the borehole by determining, at which of the angular positions of the drilling assembly about the circumference of the borehole, increase in the instantaneous angular rates occurs, the increase being indicative of a slipping of the drilling assembly at the determined angular position; and

determining that torsional vibration is occurring during drilling based on the analysis.

37. The method of claim 36, wherein measuring the instantaneous angular rates of the drilling assembly with the at least one angular rate sensor while drilling downhole comprises measuring the instantaneous angular rates with an angular rate gyroscope responsive to Coriolis acceleration.

38. The method of claim 36, wherein measuring the instantaneous angular rates of the drilling assembly with the at least one angular rate sensor while drilling downhole comprises measuring magnitudes related to tangential speed, per angular position, per time.

39. The method of claim 36, wherein analyzing the changes of the measured instantaneous angular rates occurring at least at the plurality of the determined angular positions of the drilling assembly about the circumference of the borehole comprises determining, from the changes, a pattern of vibration per one or more revolutions of the drilling assembly;

and wherein determining that torsional vibration is occurring during drilling based on the analysis comprises determining a severity measure of the torsional vibration based on one or more aspects of the determined pattern.

40. The method of claim 36, wherein analyzing the changes of the measured instantaneous angular occurring at least at the plurality of the determined angular positions of the drilling assembly about the circumference of the borehole comprises determining, from the changes, one or more cycles of increased angular rate of the measured instantaneous angular rates per one or more revolutions of the drilling assembly;

and wherein determining that torsional vibration is occurring during drilling based on the analysis comprises calculating a torsional vibration measure, indicative of the torsional vibration, based on a number of the one or more cycles and/or based on an amplitude of the one or more cycles.

41. The method of claim 36, wherein analyzing the changes of the measured instantaneous angular rates occurring at least at the plurality of the determined angular positions of the drilling assembly about the circumference of the borehole comprises determining, from the changes, vibration over revolutions over time of the drilling assembly;

and wherein determining that torsional vibration is occurring during drilling based on the analysis comprises calculating a torsional vibration measure, indicative of the torsional vibration, based on a frequency of the vibration over the revolutions over time of the drilling assembly.

42. The method of claim 36, wherein the at least one angular rate sensor comprises at least two angular rate sensors displaced along the drilling assembly;

wherein measuring the instantaneous angular rates comprises measuring the instantaneous angular rates about a same axis with the at least two angular rate sensors downhole while drilling with the drilling assembly;

wherein analyzing the measured instantaneous angular rates comprises comparing the instantaneous angular rates from the at least two angular rate sensors; and

wherein determining that torsional vibration is occurring during drilling based on the analysis comprises determining an aspect of at least one of bending and twisting of the drilling assembly based on the comparison.

43. The method of claim 36, further comprising changing one or more operating parameters of the drilling assembly based on the determined torsional vibration.

44. The method of claim 43, wherein changing the one or more operating parameters of the drilling assembly comprises:

changing one or more of weight on bit, rotational speed, torque, pump rate, mud flow rate, and mud motor operation; and

/or operating a drilling interrupting mechanism on the drilling assembly based on the determined torsional vibration.

45. The method of claim 36, wherein determining the angular positions of the drilling assembly about the circumference of the borehole while drilling downhole comprises:

measuring orientations of magnetometers with respect to the earth'"'"'s magnetic field and calculating the angular positions from the measured orientations;

or measuring orientations of accelerometers with respect to the earth'"'"'s gravitational field and calculating the angular positions from the measured orientations;

or at least periodically determining a geometric reference of the angular positions of the drilling assembly within the borehole during drilling.

46. The method of claim 36, further comprising at least periodically determining bias of the at least one angular rate sensor when rotation of the drilling assembly is stopped, wherein measuring the instantaneous angular rates comprises correcting the measurements for the determined bias.

47. A drilling assembly for drilling a borehole, the assembly comprising:

a drill collar disposed on a drill string;

a drill bit disposed on the drill collar;

a sensor element disposed on the drill collar and determining angular positions of the drilling assembly about a circumference of the borehole while drilling downhole, the sensor element including at least one angular rate sensor measuring instantaneous angular rates downhole while drilling with the drilling assembly; and

processing circuitry in communication with the sensor element, the processing circuitry is configured to;

analyze changes of the measured instantaneous angular rates occurring at least at a plurality of the determined angular positions of the drilling assembly about the circumference of the borehole to determine, at which of the angular positions of the drilling assembly about the circumference of the borehole, increase in the instantaneous angular rates occurs, the increase being indicative of a slipping of the drilling assembly at the determined angular position, and

determine that torsional vibration is occurring during drilling based on the analysis.

48. The assembly of claim 47, wherein the at least one angular rate sensor comprises an angular rate gyroscope responsive to Coriolis acceleration.

49. The assembly of claim 47, further comprising a mechanism disposed on the drilling assembly and operable to interrupt drilling by the drill bit.