Apparatus and method for determining a drilling mode to optimize formation evaluation measurements

• US 6,237,404 B1
• Filed: 02/27/1998
• Issued: 05/29/2001
• Est. Priority Date: 02/27/1998
• Status: Expired due to Term

• Current Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Original Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Inventors: Esmersoy, Cengiz, Poitzsch, Martin E., Heidler, Ralf, Crary, Steven F.
• Primary Examiner(s): Williams, Hezron
• Assistant Examiner(s): WIGGINS, JOHN DAVID
• Application Number:
  US09/031,926
• Time in Patent Office: 1,187 Days
• Field of Search: 73/152.01, 73/152.04, 73/152.03, 73/152.14, 73/152.05, 73/12.16, 73/152.44, 73/152.46, 73/152.54, 175/48, 175/50, 175/40
• US Class Current: 73/152.03
• 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: G01V 1/40 specially adapted for well-logging
• CPC Class Codes: G01V 3/18 specially adapted for well-logging

Abstract

There are many natural pauses during rotary drilling operations where a portion of the drill string remains stationary. Pauses include drill pipe connections, circulating time, and fishing operations. These pauses are used to obtain formation evaluation measurements that take a long time or that benefit from a quiet environment, as opposed to the naturally noisy drilling environment. Various techniques that are sensitive to the mud flow, weight-on-bit, or motion of the drill string may be used alone or in combination to identify the drilling mode and control the data acquisition sequence.

Claims

1. A method for using drilling pauses to perform formation evaluation measurements of an earth formation surrounding a borehole, comprising the steps of:

a) drilling the borehole into the formation using a drill string;

b) while drilling the borehole, detecting a pause where a portion of the drill string remains stationary with respect to the formation for a time interval; and

c) determining a characteristic of the formation during the time interval.

2. The method of claim 1 wherein step (b) further comprises the steps of detecting at least one current downhole condition;

and, identifying a type of pause using at least one current downhole condition and a history of the previously detected downhole conditions.

3. The method of claim 1 wherein step (b) further comprises the steps of detecting at least one current downhole condition, identifying a current drilling process mode;

and, identifying a type of pause using at least one current downhole condition and a history of the previously identified drilling process modes.

4. The method of claim 2 wherein the drill string further comprises a drill bit and the downhole condition comprises mud flow, acceleration of the drill string, bending of the drill string, weight-on-bit, or rotation of the drill string.

5. The method of claim 3 wherein the drill string further comprises a drill bit and the downhole condition comprises mud flow, acceleration of the drill string, bending of the drill string, weight-on-bit, or rotation of the drill string.

6. The method of claim 3 wherein the drilling process mode comprises drilling, sliding, tripping, circulating, fishing, a short trip, or a drill pipe connection.

7. The method of claim 1 wherein the formation characteristic is determined using a nuclear magnetic resonance tool.

8. The method of claim 7 further comprising the step of optimizing an NMR measurement obtained with the tool.

9. The method of claim 8 further comprising the step of tuning the tool during the time interval.

10. The method of claim 9 further comprising the steps of optimizing a pulse duration to obtain a maximum signal, determining a quality factor of an antenna, and, inverting a known radial dependence of B1 to obtain an effective radius and a volume of a region of investigation.

11. The method of claim 7 wherein the formation characteristic comprises the transverse relaxation time.

12. The method of claim 7 wherein the formation characteristic comprises the longitudinal relaxation time.

13. The method of claim 7 wherein the formation characteristic identifies the presence of hydrocarbons in the formation.

14. The method of claim 13 wherein the formation characteristic identifies the presence of oil in the formation.

15. The method of claim 13 wherein the formation characteristic identifies the presence of gas in the formation.

16. The method of claim 1 wherein the formation characteristic is determined using a seismic tool.

17. The method of claim 16 further comprising the step of transmitting seismic signals into the formation.

18. The method of claim 17 further comprising the steps of receiving the seismic signals from the formation and analyzing the received signals to determine the formation characteristic.

19. The method of claim 1 wherein the formation characteristic is determined using a sonic tool.

20. The method of claim 19 further comprising the step of transmitting acoustic signals into the formation.

21. The method of claim 20 further comprising the steps of receiving the acoustic signals from the formation and analyzing the received signals to determine the formation characteristic.

22. The method of claim 1 wherein the formation characteristic is determined using a resistivity tool.

23. The method of claim 22 further comprising the step of propagating electromagnetic energy into the formation.

24. The method of claim 23 further comprising the steps of receiving electromagnetic energy that has propagated through the formations and analyzing the received signals to determine the formation characteristic.

25. The method of claim 1 wherein before step (b), the method further comprises the step of triggering an event which interrupts the drilling process.

26. The method of claim 1 wherein the formation characteristic is determined using a nuclear tool.

27. The method of claim 26 wherein the formation characteristic identifies gamma ray density.

28. The method of claim 26 wherein the formation characteristic identifies neutron porosity.

29. The method of claim 26 wherein the formation characteristic identifies pulsed neutron porosity.

30. The method of claim 26 further comprising the step of obtaining a pulsed neutron spectroscopic measurement.

31. An apparatus for performing formation evaluation measurements of an earth formation surrounding a borehole, comprising:

a) a drill string;

b) drilling means attached to the drill string for drilling the borehole into the formation;

c) means for rotating the drilling means;

d) means for rotating the drill string; and

,

e) means for detecting a pause where a portion of the drill string remains stationary with respect to the formation for a time interval and,

f) means for determining a characteristic of the formation during the time interval.

32. The apparatus of claim 31 wherein the formation characteristic is determined using a nuclear magnetic resonance tool.

33. The apparatus of claim 32 further comprising means for optimizing an NMR measurement obtained with the tool.

34. The apparatus of claim 33 wherein the optimizing means further comprises means for tuning the tool during the time interval.

35. The apparatus of claim 34 wherein the means for tuning the tool further comprises means for optimizing a pulse duration to obtain a maximum signal, means for determining a quality factor of an antenna, and, means for inverting a known radial dependence of B1 to obtain an effective radius and a volume of a region of investigation.

36. The apparatus of claim 32 wherein the formation characteristic comprises the transverse relaxation time.

37. The apparatus of claim 32 wherein the formation characteristic comprises the longitudinal relaxation time.

38. The apparatus of claim 32 wherein the formation characteristic identifies the presence of hydrocarbons in the formation.

39. The apparatus of claim 38 wherein the formation characteristic identifies the presence of oil in the formation.

40. The apparatus of claim 38 wherein the formation characteristic identifies the presence of gas in the formation.

41. The apparatus of claim 31 wherein the formation characteristic is determined using a seismic tool.

42. The apparatus of claim 41 further comprising means for transmitting seismic signals into the formation.

43. The apparatus of claim 42 further comprising means for receiving the seismic signals from the formation and analyzing the received signals to determine the formation characteristic.

44. The apparatus of claim 31 wherein the formation characteristic is determined using a sonic tool.

45. The apparatus of claim 44 further comprising means for transmitting acoustic signals into the formation.

46. The apparatus of claim 45 further comprising means for receiving the acoustic signals from the formation and analyzing the received signals to determine the formation characteristic.

47. The apparatus of claim 31 wherein the formation characteristic is determined using a resistivity tool.

48. The apparatus of claim 47 further comprising means for propagating electromagnetic energy into the formation.

49. The apparatus of claim 48 further comprising means for receiving electromagnetic energy that has propagated through the formations and analyzing the received signals to determine the formation characteristic.

50. The apparatus of claim 31 wherein the formation characteristic is determined using a nuclear tool.

51. The apparatus of claim 50 wherein the formation characteristic identifies gamma ray density.

52. The apparatus of claim 50 wherein the formation characteristic identifies neutron porosity.

53. The apparatus of claim 50 wherein the formation characteristic identifies pulsed neutron porosity.

54. The apparatus of claim 50 further comprising a means for obtaining a pulsed neutron spectroscopic measurement.

55. A method for modifying a data acquisition sequence, comprising the steps of:

a) drilling a borehole into an earth formation using a drill string;

b) while drilling the borehole, detecting a current downhole condition;

c) identifying a current drilling process mode;

d) selecting a data acquisition sequence based upon the current drilling process mode; and

e) modifying a current data acquisition sequence based upon the selected data acquisition sequence.

56. The method of claim 55 wherein a plurality of current downhole conditions and a history of the previously detected downhole conditions are used to identify the current drilling process mode.

57. The method of claim 55 wherein a plurality of current downhole conditions and a history of the previously identified drilling process modes are used to identify the current drilling process mode.

58. The method of claim 55 wherein the drill string further comprises a drill bit and the downhole condition comprises mud flow, acceleration of the drill string, bending of the drill string, weight-on-bit, or rotation of the drill string.

59. The method of claim 55 wherein the drilling process mode comprises drilling, sliding, tripping, circulating, fishing, a short trip, or a drill pipe connection.