Programming method for controlling a downhole steering tool

• US 20060185900A1
• Filed: 02/18/2005
• Published: 08/24/2006
• Est. Priority Date: 02/18/2005
• Status: Active Grant

• Current Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Original Assignee: Pathfinder Energy Services LLC (Schlumberger NV)
• Inventors: Sugiura, Junichi, Jones, Stephen
• Granted Patent: US 7,222,681 B2
• Time in Patent Office: Days
• US Class Current: 175/26
• 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

Abstract

A method for communicating with a downhole tool located in a subterranean borehole is disclosed. Exemplary embodiments of the method include encoding data and/or commands in a sequence of varying drill string rotation rates and drilling fluid flow rates. The varying rotation rates and flow rates are measured downhole and processed to decode the data and/or the commands. In one exemplary embodiment, commands in the form of relative changes to current steering tool offset and tool face settings are encoded and transmitted downhole. Such commands may then be executed, for example, to change the steering tool settings and thus the direction of drilling. Exemplary embodiments of this invention advantageously provide for quick and accurate communication with a downhole tool.

Claims

1. A method for communicating with a downhole tool deployed in a subterranean borehole, the method comprising:

(a) deploying a drill string in a subterranean borehole, the drill string including a downhole tool connected thereto, the drill string being rotatable about a longitudinal axis, the drill string including a rotation measurement device operative to measure rotation rates of the drill string about the longitudinal axis, the drill string further including a flow measurement device operative to measure flow rates of drilling fluid in the drill string;

(b) predefining an encoding language comprising codes understandable to the downhole device, the codes represented in said language as predefined value combinations of drill string rotation variables and drilling fluid flow variables, the drill string rotation variables including rotation rate, the drilling fluid flow variables including flow rate;

(c) causing the drill string to rotate at a preselected rotation rate;

(d) causing the drilling fluid to flow in the drill string at a preselected flow rate;

(e) causing the rotation measurement device to measure the rotation rate and the flow measurement device to measure the flow rate; and

(f) processing downhole the rotation rate and the flow rate measured in (e) to acquire at least one code in said language at the downhole tool.

2. The method of claim 1, wherein

the downhole tool comprises a steering tool including extendable and retractable blades, the blades being operative to control a direction of drilling of the subterranean borehole;

and

at least one of the codes includes a command, the command causing the directional drilling tool to extend at least one of the blades to a desired extended position.

3. The method of claim 2, wherein the command ordains the steering tool to achieve a predefined tool setting, the command including at least one selected from the group consisting of:

(1) absolute offset;

(2) absolute tool face;

(3) relative change of offset from current;

(4) relative change of tool face from current;

4. The method of claim 1, wherein:

the downhole tool comprises a substantially non-rotating housing deployed about a drive shaft that rotates with the drill string; and

the rotation measurement device includes at least one marker deployed on the drive shaft and a sensor deployed on the substantially non-rotating housing, the sensor disposed to detect the at least one marker as it rotates by the sensor.

5. The method of claim 1, wherein the flow measurement device is selected from the group consisting of a turbine and an impeller.

6. The method of claim 1, wherein:

(c) further comprises causing the drill string to rotate at first and second preselected rotation rates;

(e) further comprises causing the rotation measurement device to measure the first and second rotation rates; and

(f) further comprises processing downhole a difference between the first and second rotation rates measured in (e) to acquire the at least one code at the downhole tool.

7. The method of claim 6, wherein:

(c) further comprises causing the drill string to rotate through a predefined sequence of varying rotation rates, the sequence including the second rotation rate, the drill string rotation variables in (b) further including a duration of rotation during a predetermined portion of the sequence; and

(f) further comprises processing the duration of rotation to acquire the at least one code at the downhole tool.

8. The method of claim 7, wherein the drill string is substantially non-rotating during a portion of the sequence of varying rotation rates.

9. The method of claim 6, wherein:

(d) further comprises causing the drilling fluid to flow in the drill string at first and second preselected flow rates; and

(e) further comprises causing the flow measurement device to measure the first and second flow rates.

10. The method of claim 9, wherein

the flow rate measured in (e) is measured as a binary variable including high and low flow levels;

and

the at least one code is acquired at the downhole tool in (f) when, and only when, the flow rate measured in (e) is detected to be at a preselected one of the high and the low flow levels.

11. The method of claim 9, wherein (f) further comprises processing a difference between the first and second flow rates to acquire the at least one code at the downhole tool.

12. The method of claim 11, wherein:

(d) further comprises causing the drill fluid to flow in a predefined sequence of varying flow rates, the sequence including the second flow rate, the drilling fluid flow variables in (b) further including a duration of flow during a predetermined portion of the sequence; and

(f) further comprises processing the duration of flow to acquire the at least one code at the downhole tool.

13. The method of claim 1, further comprising:

(g) receiving, at the surface, sensor data acquired by a sensor deployed in the drill string; and

(h) responsive to the sensor data received at the surface in (g), repeating (c), (d), (e), and (f), to acquire further codes in said language at the downhole device.

14. A method for communicating with a downhole tool deployed in a subterranean borehole, the method comprising:

(a) deploying a drill string in a subterranean borehole, the drill string including a downhole tool connected thereto, the drill string being rotatable about a longitudinal axis, the drill string including a rotation measurement device operative to measure rotation rates of the drill string about the longitudinal axis;

(b) predefining an encoding language comprising codes understandable to the steering tool, the codes represented in said language as predefined value combinations of drill string variables including drill string rotation variables, said drill string rotation variables including rotation rate;

(c) causing the drill string to rotate at a preselected rotation rate;

(d) causing the rotation measurement device to measure the rotation rate; and

(e) processing downhole the rotation rate measured (d) to acquire at least one code in said language at the downhole tool, the downhole tool recognizing at least one of said acquired codes as a command to make a predetermined relative change to at least one of its current tool settings.

15. The method of claim 14, wherein:

the downhole tool comprises a steering tool; and

said acquired codes in (e) are recognized as a command to make a predetermined relative change to at least one tool setting selected from the group consisting of (i) offset and (ii) tool face.

16. The method of claim 14, wherein

the downhole tool comprises a steering tool having extendable and retractable blades, the blades being operative to control a direction of drilling of the subterranean borehole;

and

at least one of the codes includes a command, the command causing the steering tool to change an extended position of at least one of the blades.

17. The method of claim 14, wherein:

(c) further comprises causing the drill string to rotate through a predefined sequence of varying rotation rates, the sequence including first and second rotation rates, the drill string rotation variables in (b) including (i) a difference between the first and second rotation rates and (ii) a duration of rotation during a predetermined portion of the sequence; and

(e) further comprises processing downhole (i) the difference between the first and second rotation rates and (ii) the duration to acquire the at least one code at the downhole tool.

18. A method for communicating with a downhole tool deployed in a subterranean borehole, the method comprising:

(a) deploying a drill string in a subterranean borehole, the drill string including a downhole tool connected thereto, the drill string being rotatable about a longitudinal axis, the drill string including a rotation measurement device operative to measure rotation rates of the drill string about the longitudinal axis, the drill string further including a flow sensing device operative to measure flow of drilling fluid in the drill string;

(b) predefining an encoding language comprising codes understandable to the downhole device, the codes represented in said language as predefined value combinations of drill string rotation variables and drilling fluid flow variables, the drill string rotation variables including rotation rate;

(c) causing the drill string to rotate at a preselected rotation rate;

(d) causing the drilling fluid to flow in the drill string at a preselected flow rate;

(e) causing the rotation measurement device to measure the rotation rate of the drill string;

(f) causing the flow sensing device to measure the flow of the drilling fluid, the flow measured as a binary variable including high and low flow levels; and

(g) processing downhole the rotation rate measured in (e) and the flow measured in (f) to acquire at least one code in said language at the downhole tool, the at least one code acquired at the tool only when the flow measured in (f) is detected to be at a preselected one of the high and low flow levels.

19. The method of claim 18, wherein there is substantially no flow of drilling fluid in the drill string at the low flow level.

20. The method of claim 18, wherein the flow sensing device comprises a drilling fluid pressure sensor.

21. The method of claim 18, wherein

the downhole tool comprises a steering tool including extendable and retractable blades, the blades being operative to control a direction of drilling of the subterranean borehole;

and

at least one of the codes includes a command, the command causing the directional drilling tool to extend at least one of the blades to a desired extended position.

22. The method of claim 21, wherein the command ordains the steering tool to achieve a predefined tool setting, the command including at least one selected from the group consisting of:

(1) absolute offset;

(2) absolute tool face;

(3) relative change of offset from current;

(4) relative change of tool face from current;

23. The method of claim 18, wherein:

(c) further comprises causing the drill string to rotate at first and second preselected rotation rates;

(e) further comprises causing the rotation measurement device to measure the first and second rotation rates; and

(f) comprises processing downhole a difference between the first and second rotation rates measured in (e) to acquire the at least one code at the downhole tool.

24. The method of claim 23, wherein:

(c) further comprises causing the drill string to rotate through a predefined sequence of varying rotation rates, the sequence including the second rotation rate, the drill string rotation variables in (b) further including a duration of rotation during a predetermined portion of the sequence; and

(f) further comprises processing the duration of rotation to acquire the at least one code at the downhole tool.

25. A method for communicating with a downhole steering tool deployed in a subterranean borehole, the method comprising:

(a) deploying a drill string in a subterranean borehole, the drill string including a downhole tool connected thereto, the drill string being rotatable about a longitudinal axis, the drill string including a rotation measurement device operative to measure rotation rates of the drill string about the longitudinal axis, the drill string further including a flow sensing device operative to measure flow of drilling fluid in the drill string;

(b) predefining an encoding language comprising codes understandable to the downhole device, the codes represented in said language as predefined value combinations of drill string rotation variables and drilling fluid flow variables, the drill string rotation variables including rotation rate;

(c) causing the drill string to rotate at a preselected rotation rate;

(d) causing the drilling fluid to flow in the drill string at a preselected flow rate;

(e) causing the rotation measurement device to measure the rotation rate of the drill string;

(f) causing the flow sensing device to measure the flow of the drilling fluid, the flow measured as a binary variable including high and low flow levels; and

(g) processing downhole the rotation rate measured in (e) and the flow measured in (f) to acquire at least one code in said language at the downhole tool, the at least one code acquired at the tool only when the flow measured in (f) is detected to be at a preselected one of the high and low flow levels, the downhole tool recognizing at least one of said acquired codes as a command to make a predetermined relative change to at least one of its current tool settings.

26. The method of claim 25, wherein said acquired codes in (g) are recognized as a command to make a predetermined relative change to at least one tool setting selected from the group consisting of (i) offset and (ii) tool face.

27. The method of claim 25, wherein

the steering tool comprises extendable and retractable blades, the blades being operative to control a direction of drilling of the subterranean borehole;

and

at least one of the codes includes a command, the command causing the steering tool to change an extended position of at least one of the blades.

28. The method of claim 25, wherein there is substantially no flow of drilling fluid in the drill string at the low flow level.

29. The method of claim 25, wherein:

(c) further comprises causing the drill string to rotate through a predefined sequence of varying rotation rates, the sequence including a second rotation rate, the drill string rotation variables in (b) further including a duration of rotation during a predetermined portion of the sequence;

(e) further comprises causing the rotation measurement device to measure the first and second rotation rates; and

(f) comprises processing downhole (i) a difference between the first and second rotation rates measured in (e) and (ii) the duration of rotation to acquire the at least one code at the steering tool

30. The method of claim 29, wherein the drill string is substantially non-rotating during a portion of the sequence of varying rotation rates.

31. The method of claim 25, further comprising:

(h) receiving, at the surface, sensor data acquired by a sensor deployed in the drill string; and

(i) responsive to the sensor data received at the surface in (g), repeating (c), (d), (e), (f), and (g) to acquire further codes in said language at the downhole device.