Downhole downlinking system employing a differential pressure transducer

• US 8,746,366 B2
• Filed: 04/01/2013
• Issued: 06/10/2014
• Est. Priority Date: 01/08/2010
• Status: Expired due to Fees

• Current Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Original Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Inventors: Patwa, Ruchir S., Das, Pralay, Sugiura, Junichi
• Primary Examiner(s): WRIGHT, GIOVANNA COLLINS
• Application Number:
  US13/854,719
• Publication Number:
  US 20130220602A1
• Time in Patent Office: 435 Days
• Field of Search: 166/65.1, 166/66, 175/40, 175/48, 175/38, 731/522.2
• US Class Current: 175/48
• CPC Class Codes: E21B 47/017 Protecting measuring instruments
• CPC Class Codes: E21B 47/06 Measuring temperature or pressure
• CPC Class Codes: E21B 47/18 through the well fluid , e.g. mud pressure pulse telemetry
• CPC Class Codes: Y10T 29/49002 Electrical device making

Abstract

A downhole tool includes a downlinking system deployed in a downhole tool body having an internal through bore. The downlinking system includes a differential pressure transducer configured to measured a pressure difference between drilling fluid in the internal through bore and drilling fluid external to the tool (in the borehole annulus). The differential transducer is electrically connected with an electronic controller (deployed substantially anywhere in the drill string) that is configured to receive and decode pressure waveforms.

Claims

1. A method comprising:

deploying a differential transducer in a longitudinal bore in a pressure housing to form a downlinking system;

disposing the downlinking system in a downhole tool body such that the differential transducer is disposed to measure a pressure difference between fluid internal to the tool body and fluid external to the tool body;

forming a pressure tight seal with a bulkhead deployed in the longitudinal bore; and

electrically connecting the bulkhead with the differential transducer.

2. The method of claim 1, further comprising:

sealingly deploying the downlinking system in a chassis slot of the downhole tool body.

3. The method of claim 1, further comprising:

fully assembling the downlinking system prior to disposing the downlinking system in the downhole tool body.

4. The method of claim 1, further comprising:

testing the downlinking system prior to disposing the downlinking system in the downhole tool body.

5. The method of claim 1, further comprising:

disposing the downhole tool in a borehole;

measuring a differential pressure with the differential transducer; and

receiving and decoding a differential pressure waveform from the differential transducer.

6. The method of claim 5, further comprising at least one of:

controlling a second downhole tool based on the decoded differential pressure waveform; and

transmitting the decoded commands to a device in electronic communication with the downlinking system.

7. The method of claim 5, further comprising:

servicing the downhole tool.

8. The method of claim 7, wherein the servicing comprises at least one:

removing the downlinking system from the downhole tool;

replacing the downlinking system in the downhole tool; and

repairing the downlinking system.

9. The method of claim 5, further comprising:

propagating a pressure pulse through the borehole.

10. The method of claim 9, wherein the propagating, measuring, receiving, and decoding are performed while drilling.

11. The method of claim 9, wherein the propagating, measuring, receiving, and decoding are performed while a drill bit connected directly or indirectly to the downhole tool is off-bottom.

12. The method of claim 1, further comprising:

electronically connecting the downlinking system with at least one of a controller and a second downhole tool.

13. The method of claim 1, further comprising:

deploying and sealingly engaging a compensating piston in a second longitudinal bore in the pressure housing.

14. The method of claim 13, further comprising:

disposing a fluid in the second longitudinal bore.

15. A method, comprising:

deploying a pressure housing on a tool body including an internal through bore;

deploying a differential transducer in the pressure housing, the differential transducer having first and second sides, the first side of the differential transducer being in fluid communication with the through bore;

deploying a compensating piston in a cavity in the pressure housing, the piston and the cavity defining first and second fluid chambers, the first fluid chamber being in fluid communication with external portion of the tool, the second fluid chamber being in fluid communication with the second side of the differential transducer; and

forming a first bore in the tool body and a second bore in the pressure housing to provide fluid communication between the through bore in the first side of the differential transducer.

16. The method of claim 15, further comprising:

forming at least one bore in the pressure housing to provide fluid communication between the second fluid chamber and the second side of the differential transducer.

17. The method of claim 15, wherein the deploying a differential transducer in the pressure housing comprises deploying the differential transducer in a longitudinal bore formed in the pressure housing.

18. The method of claim 17, further comprising:

deploying a pressure tight bulkhead and the longitudinal bore; and

electrically connecting the bulkhead to the differential transducer.

19. The method of claim 18, further comprising:

deploying a sealed locknut at a longitudinal end of the longitudinal bore, the bulkhead being deployed between the differential transducer and the locknut.

20. The method of claim 15, further comprising:

filling the second fluid chamber with a fluid.

21. The method of claim 15, further comprising:

electrically connecting the differential transducer with an electronic controller; and

configuring the controller to receive and decode a differential pressure waveform from the differential transducer.

22. The method of claim 21, further comprising:

receiving and decoding a differential pressure waveform from the differential transducer with the controller.

23. The method of claim 22, further comprising at least one of:

controlling a second downhole tool based on the decoded differential pressure waveform; and

transmitting the decoded commands to a device in electronic communication with the downlinking system.

24. The method of claim 23 wherein the second downhole tool or the device comprises at least one of a steering tool, a telemetry system, a sensor for sensing downhole characteristics of the borehole and surrounding formation, and microcontrollers deployed in the measurement tool.

25. The method of claim 24, further comprising at least one of:

steering a drill string based on the decoded waveform; and

measuring a characteristic of at least one of the borehole and the surrounding formation based on the decoded waveform.