Communication methods and apparatuses for downhole logging tools

• US 10,436,021 B2
• Filed: 01/05/2016
• Issued: 10/08/2019
• Est. Priority Date: 01/08/2015
• Status: Active Grant

• Current Assignee: Reeves Wireline Technologies Limited (Weatherford International PLC)
• Original Assignee: Reeves Wireline Technologies Limited (Weatherford International PLC)
• Inventors: Ash, Simon Christopher, Sheriff, Edward
• Primary Examiner(s): Hall, Kristyn A
• Application Number:
  US14/988,461
• Publication Number:
  US 20160208596A1
• Time in Patent Office: 1,372 Days
• CPC Class Codes: E21B 47/18 through the well fluid , e.g. mud pressure pulse telemetry

Abstract

Logging tool communication apparatus (10), for carrying out a downhole communication method, comprises rotatable and/or longitudinally reciprocable drill pipe (12) including fixed or capable of being fixed in a co-rotative and/or co-reciprocable relationship at an in-use downhole end an in-use downhole logging tool (27). The logging tool (27) includes a movement sensor (33); and the apparatus (10) includes a motor, at a location remote from the logging tool (27), for causing rotation and/or reciprocation of the drill pipe (12) in a borehole or wellbore (18). The apparatus (10) includes one or more control elements for selectively controlling operation of the motor so as to cause selective rotation and/or reciprocation of the drill pipe (12) which causes movement of the logging tool (27), when fixed to the drill pipe (12), in a manner that is detectable by the movement sensor (33).

Claims

1. A communication method for a downhole logging tool that (a) is configured to energize rock surrounding a well or borehole and receive emitted energy that has passed through the rock;

(b) is fixed to a drill pipe in the well or borehole and (c) includes a logging tool movement sensor, the drill pipe being connected at a location remote from the downhole logging tool to one or more motors that are capable of controlledly rotating and/or longitudinally reciprocating the drill pipe in the well or borehole, the method including the steps of;

causing rotation and/or longitudinal reciprocation of the drill pipe under the influence of the motor;

detecting, using the logging tool movement sensor, rotation of the downhole logging tool caused by rotation of the drill pipe; and

generating a first signal of the logging tool movement sensor that is indicative of rotation of the downhole logging tool,

wherein the logging tool movement sensor comprises an angular rate sensor that detects rotation of the logging tool and generates the first signal indicative of such rotation;

wherein the step of detecting rotation of the downhole logging tool includes the step of assessing whether the average rate of rotation of the downhole logging tool in one or more predetermined time periods exceeds a predetermined threshold; and

wherein the predetermined threshold is distinct from a drilling rate of rotation.

2. The method according to claim 1, including the further step of causing the first signal of the angular rate sensor to command a control action of the logging tool.

3. The method according to claim 2, wherein commanding of the control action of the logging tool causes alteration of the status, operation or configuration of the downhole logging tool.

4. The method according to claim 3, wherein alteration of the status, operation or configuration of the downhole logging tool is or includes causing deployment of the downhole logging tool from a non-deployed to a deployed configuration.

5. The method according to claim 1, including the further step of causing the first signal of the angular rate sensor to cause transmission of a further signal, from the downhole logging tool to a remote location, that is indicative of the status of the downhole logging tool.

6. The method according to claim 1, wherein the logging tool is rigidly fixed to the drill pipe.

7. The method according to claim 1, including the step of using a binary gate device that is operatively connected to the logging tool to determine whether generation of the first signal should occur.

8. The method according to claim 1, including the further step of inducing one or more pressure pulses in fluid in the vicinity of the downhole logging tool;

commanding of a control action in the downhole logging tool; and

using the combination of one or more said pressure pulses and commanding of the control action to effect a command action in the downhole logging tool.

9. The method according to claim 8, wherein the step of inducing includes operating or causing operation of a pump to induce one or more said pressure pulses.

10. The method according to claim 1, wherein the downhole logging tool is capable of altering the rate of flow of fluid in a vicinity of the downhole logging tool;

and wherein the method includes causing the downhole logging tool to reduce the rate of flow of fluid in the vicinity to generate a pressure pulse, that is detectable at a location remote from the downhole logging tool, to signify commanding of a control action at the downhole logging tool.

11. The method according to claim 10, wherein the downhole logging tool includes a fluid flow path having an adjustable flow restriction;

and wherein the method includes the step of causing the flow restriction to reduce the flow of fluid in the vicinity of the downhole logging tool.

12. The method according to claim 1, wherein the motor is at or near a surface location.

13. The method according to claim 1, wherein the motor is one or more selected from the list including a rotary drive, a top drive, a drill string drive including a drill pipe elevator or a drill string drive including a draw works.

14. The method of claim 1, further comprising:

detecting, using the logging tool movement sensor, longitudinal reciprocation of the downhole logging tool caused by longitudinal reciprocation of the drill pipe; and

generating a second signal of the logging tool movement sensor that is indicative of longitudinal reciprocation of the downhole logging tool.

15. The method according to claim 14, wherein the logging tool movement sensor is an accelerometer that detects longitudinal movement of the logging tool and generates the second signal indicative of such movement.

16. The method according to claim 15, including the further step of causing the second signal of the accelerometer to command a control action of the logging tool.

17. The method according to claim 15, including the further step of causing the second signal of the accelerometer to cause transmission of a further signal, from the downhole logging tool to a remote location, that is indicative of the status of the downhole logging tool.

18. The method according to claim 14, wherein the step of detecting longitudinal reciprocation of the downhole logging tool includes the step of assessing whether axial movement of the downhole tool occurs in one or more predetermined time periods.

19. The method according to claim 14, wherein the step of detecting longitudinal reciprocation of the downhole logging tool includes the step of assessing whether a predetermined sequence of axial movements of the downhole logging tool occurs in one or more programmable time gates.

20. The method according to claim 14, wherein the step of detecting longitudinal reciprocation of the downhole logging tool includes the step of assessing the extent of movement of the drill pipe out of the hole, or detecting in one or more predetermined time gates a predetermined sequence of axial or rotational movements of the downhole logging tool occurs in one or more programmable time gates.

41. Logging tool communication apparatus, for performing a method according to claim 1, comprising:

drill pipe being rotatable and/or longitudinally reciprocable;

an in-use downhole logging tool being fixed or capable of being fixed in a co-rotative and/or co-reciprocable relationship at an in-use downhole end of the drill pipe, the logging tool being configured to energize rock surrounding a borehole or wellbore and receiving emitted energy that has passed through the rock, the logging tool including a movement sensor;

a motor disposed at a location remote from the logging tool and being operable to cause rotation and/or reciprocation of the drill pipe in the borehole or wellbore; and

one or more control elements in communication with the motor and selectively controlling operation of the motor so as to cause selective rotation and/or reciprocation of the drill pipe, the rotation and/or reciprocation of the drill pipe causing movement of the logging tool, when fixed to the drill pipe, the rotation being detectable by the movement sensor that generates a first signal indicative of the rotation,

wherein the movement sensor comprises an angular rate sensor that detects rotation of the logging tool and generates the first signal indicative of such rotation;

wherein detection of the rotation by the movement sensor includes assessing whether the average rate of rotation of the downhole logging tool in one or more predetermined time periods exceeds a predetermined threshold; and

wherein the predetermined threshold is distinct from a drilling rate of rotation.

42. The apparatus according to claim 41, wherein the one or more control elements is or includes a potentiometer connected to control operation of the motor to control rotation of the drill pipe.

43. The apparatus according to claim 1, wherein the one or more control elements is or includes a programmable device.

44. The apparatus according to claim 41, wherein the logging tool includes one or more processors for processing one or more signals of the movement sensor and generating therefrom one or more commands of control actions.

21. A communication method for a downhole logging tool that (a) is configured to energize rock surrounding a well or borehole and receive emitted energy that has passed through the rock;

(b) is fixed to a drill pipe in the well or borehole and (c) includes a logging tool movement sensor, the drill pipe being connected at a location remote from the downhole logging tool to one or more motors that are capable of controlledly rotating and/or longitudinally reciprocating the drill pipe in the well or borehole, the method including the steps of;

causing rotation and/or longitudinal reciprocation of the drill pipe under the influence of the motor;

detecting, using the logging tool movement sensor, rotation of the downhole logging tool caused by rotation of the drill pipe, and

generating a first signal of the logging tool movement sensor that is indicative of rotation of the downhole logging tool,

wherein the logging tool movement sensor comprises an angular rate sensor that detects rotation of the logging tool and generates the first signal indicative of such rotation;

wherein the step of detecting rotation of the downhole logging tool includes the step of (ii)(a) assessing whether the average rate of rotation of the downhole logging tool in one or more predetermined time periods is less than a predetermined threshold; and

wherein the predetermined threshold is distinct from a drilling rate of rotation.

22. The method of claim 21, further comprising:

detecting, using the logging tool movement sensor, longitudinal reciprocation of the downhole logging tool caused by longitudinal reciprocation of the drill pipe; and

generating a second signal of the logging tool movement sensor that is indicative of longitudinal reciprocation of the downhole logging tool.

23. The method according to claim 22, wherein the logging tool movement sensor is an accelerometer that detects longitudinal movement of the logging tool and generates the second signal indicative of such movement.

24. The method according to claim 23, including the further step of (iv)(b) causing the second signal of the accelerometer to command a control action of the logging tool.

25. The method according to claim 23, including the further step of (iv)(d) causing the second signal of the accelerometer to cause transmission of a further signal, from the downhole logging tool to a remote location, that is indicative of the status of the downhole logging tool.

26. The method according to claim 22, wherein the step of detecting longitudinal reciprocation of the downhole logging tool includes the step of assessing whether axial movement of the downhole tool occurs in one or more predetermined time periods.

27. The method according to claim 22, wherein the step of detecting longitudinal reciprocation of the downhole logging tool includes the step of assessing whether a predetermined sequence of axial movements of the downhole logging tool occurs in one or more programmable time gates.

28. The method according to claim 22, wherein the step of detecting longitudinal reciprocation of the downhole logging tool includes the step of assessing the extent of movement of the drill pipe out of the hole, or detecting in one or more predetermined time gates a predetermined sequence of axial or rotational movements of the downhole logging tool occurs in one or more programmable time gates.

29. The method according to claim 21, including the further step of causing the first signal of the angular rate sensor to command a control action of the logging tool.

30. The method according to claim 29, wherein commanding of the control action of the logging tool causes alteration of the status, operation or configuration of the downhole logging tool.

31. The method according to claim 30, wherein alteration of the status, operation or configuration of the downhole logging tool is or includes causing deployment of the downhole logging tool from a non-deployed to a deployed configuration.

32. The method according to claim 21, including the further step of causing the first signal of the angular rate sensor to cause transmission of a further signal, from the downhole logging tool to a remote location, that is indicative of the status of the downhole logging tool.

33. The method according to claim 21, wherein the logging tool is rigidly fixed to the drill pipe.

34. The method according to claim 21, including the step of using a binary gate device that is operatively connected to the logging tool to determine whether generation of the first signal should occur.

35. The method according to claim 21, including the further step of inducing one or more pressure pulses in fluid in the vicinity of the downhole logging tool;

commanding of a control action in the downhole logging tool; and

using the combination of one or more said pressure pulses and commanding of the control action to effect a command action in the downhole logging tool.

36. The method according to claim 35, wherein the step of inducing includes operating or causing operation of a pump to induce one or more said pressure pulses.

37. The method according to claim 21, wherein the downhole logging tool is capable of altering the rate of flow of fluid in a vicinity of the downhole logging tool;

and wherein the method includes causing the downhole logging tool to reduce the rate of flow of fluid in the vicinity to generate a pressure pulse, that is detectable at a location remote from the downhole logging tool, to signify commanding of a control action at the downhole logging tool.

38. The method according to claim 37, wherein the downhole logging tool includes a fluid flow path having an adjustable flow restriction;

and wherein the method includes the step of causing the flow restriction to reduce the flow of fluid in the vicinity of the downhole logging tool.

39. The method according to claim 21, wherein the motor is at or near a surface location.

40. The method according to claim 21, wherein the motor is one or more selected from the list including a rotary drive, a top drive, a drill string drive including a drill pipe elevator or a drill string drive including a draw works.

45. Logging tool communication apparatus, for performing a method according to claim 21, comprising:

drill pipe being rotatable and/or longitudinally reciprocable;

an in-use downhole logging tool being fixed or capable of being fixed in a co-rotative and/or co-reciprocable relationship at an in-use downhole end of the drill pipe, the logging tool being configured to energize rock surrounding a borehole or wellbore and receiving emitted energy that has passed through the rock, the logging tool including a movement sensor;

a motor disposed at a location remote from the logging tool and being operable to cause rotation and/or reciprocation of the drill pipe in the borehole or wellbore; and

one or more control elements in communication with the motor and selectively controlling operation of the motor so as to cause selective rotation and/or reciprocation of the drill pipe, the rotation and/or reciprocation of the drill pipe causing movement of the logging tool, when fixed to the drill pipe, the rotation being detectable by the movement sensor that generates a first signal indicative of the rotation,

wherein the movement sensor comprises an angular rate sensor that detects rotation of the logging tool and generates the first signal indicative of such rotation;

wherein detection of the rotation by the movement sensor includes assessing whether the average rate of rotation of the downhole logging tool in one or more predetermined time periods exceeds a predetermined threshold; and

wherein the predetermined threshold is distinct from a drilling rate of rotation.

46. The apparatus according to claim 45, wherein the one or more control elements is or includes a potentiometer connected to control operation of the motor to control rotation of the drill pipe.

47. The apparatus according to claim 45, wherein the one or more control elements is or includes a programmable device.

48. The apparatus according to claim 45, wherein the logging tool includes one or more processors for processing one or more signals of the movement sensor and generating therefrom one or more commands of control actions.