Downlinking communication system and method using signal transition detection

• US 8,792,304 B2
• Filed: 08/04/2011
• Issued: 07/29/2014
• Est. Priority Date: 05/24/2010
• Status: Active Grant

• Current Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Original Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Inventors: Sugiura, Junichi
• Primary Examiner(s): Phan, Hai
• Assistant Examiner(s): Benlagsir, Amine
• Application Number:
  US13/197,864
• Publication Number:
  US 20110286309A1
• Time in Patent Office: 1,090 Days
• Field of Search: 367/81, 367/83, 340/853.3, 340/853.6, 340/854.3, 340/855.55
• US Class Current: 367/83
• CPC Class Codes: E21B 47/18 through the well fluid , e.g. mud pressure pulse telemetry

Abstract

A downlinking signal is transmitted downhole from the surface using drilling fluid as the communications medium. The downlinking signal includes at least a synchronization phase and a command phase. The downlinking signal is differentiated upon reception such that attributes of the synchronization phase may be used to determine corresponding attributes of the command phase. Commands may be transmitted downhole while drilling and simultaneously while using mud-pulse telemetry uplinking techniques.

Claims

1. A method for transmitting a command from a surface location to a bottom hole assembly located in a borehole, the method comprising:

(a) pumping drilling fluid downhole through a drill string to the bottom hole assembly;

(b) changing a flow rate of the drilling fluid to encode a downlinking signal, the downlinking signal including at least a synchronization phase and a command phase, each of the synchronization phase and the command phase including at least one distinct pulse;

(c) detecting the downlinking signal at the bottom hole assembly;

(d) causing a downhole controller to differentiate the downlinking signal;

(e) causing the downhole controller to decode the synchronization phase to determine at least one of a bit length and a duration of the command phase; and

(f) causing the downhole controller to decode the command phase to determine the command based on at least one of the bit length and the duration determined in (e).

2. The method of claim 1, wherein at least one of (e) and (f) further comprises causing the downhole controller to locate a plurality of zero-crossings in said differentiated downlinking signal.

3. The method of claim 1, wherein the synchronization phase and the command phase each include at least one distinct negative flow rate pulse.

4. The method of claim 1, wherein the synchronization phase includes a negative pulse during a first time period and a return to a base level during a second time period.

5. The method of claim 1, wherein the bit length and the duration are computed from a time difference between first and second zero-crossings in said differentiated downlinking signal.

6. The method of claim 1, wherein the command phase comprises at least first and second distinct commands, each of the first and second distinct commands including at least four bits.

7. The method of claim 1, wherein the command is determined via computing at least one time difference between first and second zero-crossings in said differentiated downlinking signal.

8. The method of claim 1, wherein the command is determined via counting zero-crossings in a predetermined time period specified by the synchronization phase.

9. The method of claim 1, wherein the bottom hole assembly comprises a rotary steerable tool configured to execute the command, the rotary steerable tool including a plurality of extendable and retractable blades, the blades being operative to control a direction of drilling of the borehole, the method further comprising:

(g) executing the command, said execution of the command causing extension or retraction of at least one of the blades.

10. The method of claim 9, wherein the command is selected from the group consisting of absolute offset, absolute percentage force, absolute toolface angle, absolute target inclination, absolute target azimuth, absolute dogleg severity, change in offset, change in percentage force, change in toolface angle, change in inclination, change in azimuth, and change in dogleg severity.

11. The method of claim 1, wherein the flow rate is changed in (b) via actuating a bypass valve.

12. The method of claim 1, wherein the flow rate is changed in (b) via changing the rotation speed of a pump.

13. The method of claim 1, wherein the downlinking signal is detected using a differential pressure transducer configured to measured a pressure differential between drilling fluid in the drill string and drilling fluid in a borehole annulus.

14. The method of claim 1, wherein (a) further comprises rotary drilling the borehole.

15. A system for communicating at least one command from a surface location to a bottom hole assembly located in a borehole, the system comprising:

a pump for pumping drilling fluid from the surface through a drill string to the bottom hole assembly;

a flow control apparatus for controlling a flow rate of the drilling fluid, the flow rate encoding a downlinking signal, the downlinking signal including at least a synchronization phase and a command phase, each of the synchronization phase and the command phase including at least one distinct flow rate pulse;

a downhole detector configured to detect the downlinking signal; and

a downhole controller configured to decode the downlinking signal, the downhole controller configured to (i) differentiate the downlinking signal, (ii) decode the synchronization phase to determine at least one of a bit length and a duration of the command phase and (iii) decode the command phase to determine the command.

16. The system of claim 15, wherein the flow control apparatus is computer controlled.

17. The system of claim 15, wherein the flow control apparatus is further configured to selectively open and close a bypass valve, wherein opening the bypass valve reduces the flow rate in the drill string.

18. The system of claim 15, wherein the flow control apparatus is further configured to control the rotation rate of the pump.

19. The system of claim 15, wherein the downhole detector comprises a differential transducer configured to measure a pressure differential between drilling fluid in the drill string and drilling fluid in a borehole annulus.

20. The system of claim 15, wherein the downhole controller is further configured to compute at least one of the bit length and the duration of the command phase from a time difference between first and second zero-crossings in said differentiated downlinking signal.

21. The system of claim 15, wherein the downhole controller is further configured to determine the command from at least one time difference between first and second zero-crossings in said differentiated downlinking signal.

22. The system of claim 15, further comprising a rotary steerable tool configured to execute the command, the rotary steerable tool including a plurality of extendable and retractable blades, the extendable and retractable blades being operative to control a direction of drilling of the borehole, execution of the command causing extension or retraction of at least one of the extendable and retractable blades, the command being selected from the group consisting of absolute offset, absolute percentage force, absolute toolface angle, absolute target inclination, absolute target azimuth, absolute dogleg severity, change in offset, change in percentage force, change in toolface angle, change in inclination, change in azimuth, and change in dogleg severity.