Downhole Downlinking System Employing a Differential Pressure Transducer

• US 20110168445A1
• Filed: 01/08/2010
• Published: 07/14/2011
• Est. Priority Date: 01/08/2010
• Status: Active Grant

• Current Assignee: Schlumberger Technology Corporation (Schlumberger NV)
• Original Assignee: Smith International Incorporated (Schlumberger NV)
• Inventors: Patwa, Ruchir S., Das, Pralay
• Granted Patent: US 8,408,331 B2
• Time in Patent Office: Days
• 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 downhole tool comprising:

a downhole tool body including an internal through bore;

a downlinking system deployed in the tool body, the downlinking system including a differential transducer deployed in a pressure housing, the differential transducer disposed to measure a pressure difference between drilling fluid in the through bore and drilling fluid external to the tool in a borehole annulus.

2. The downhole tool of claim 1, wherein the downlinking system is configured as a stand alone assembly and sealing engages a chassis slot formed in an outer surface of the tool body.

3. The downhole tool of claim 1, wherein:

the differential transducer is deployed in a longitudinal bore in the pressure housing; and

the tool further comprises a pressure tight bulkhead deployed in the longitudinal bore, the bulkhead being electrically connected with the differential transducer.

4. The downhole tool of claim 1, further comprising a compensating piston deployed in a cavity in the pressure housing, the piston and cavity defining first and second fluid chambers, the first fluid chamber being in fluid communication with drilling fluid external to the tool in a borehole annulus.

5. The downhole tool of claim 4, wherein the differential transducer comprises first and second sides, the first side in fluid communication with drilling fluid in the through bore and the second side in fluid communication with hydraulic oil in the second fluid chamber.

6. The downhole tool of claim 1, being connected to a second downhole tool such that the differential transducer is electrically connected with an electronic controller deployed in the second downhole tool, the controller being configured to receive and decode a differential pressure waveform from the differential transducer.

7. A downhole tool comprising:

a downhole tool body including an internal through bore;

a pressure housing deployed on the tool body;

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

a compensating piston deployed 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 drilling fluid external to the tool in a borehole annulus, the second fluid chamber being in fluid communication with the second side of the differential transducer.

8. The downhole tool of claim 7, wherein a first bore formed in the tool body and a second bore formed in the pressure housing provide the fluid communication between the through bore and the first side of the differential transducer.

9. The downhole tool of claim 7, wherein at least one bore formed in the pressure housing provides the fluid communication between the second fluid chamber and the second side of the differential transducer.

10. The downhole tool of claim 7, wherein the differential transducer is deployed in a longitudinal bore formed in the pressure housing.

11. The downhole tool of claim 10, further comprising a pressure tight bulkhead deployed in the longitudinal bore, the bulkhead being electrically connected to the differential transducer.

12. The downhole tool of claim 11, further comprising a sealed locknut deployed at a longitudinal end of the longitudinal bore, the bulkhead being deployed between the differential transducer and the locknut.

13. The downhole tool of claim 7, wherein the differential transducer is electrically connected with an electronic controller, the controller being configured to receive and decode a differential pressure waveform from the differential transducer.

14. The downhole tool of claim 7, wherein the second fluid chamber is filled with hydraulic oil.

15. A string of downhole tools comprising:

a downhole steering tool including an electronic controller; and

a downhole sub connected to the steering tool, the sub including;

a downhole tool body including an internal through bore;

a pressure housing deployed on the tool body;

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

a compensating piston deployed 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 drilling fluid external to the tool in a borehole annulus, the second fluid chamber being in fluid communication with the second side of the differential transducer.

16. The string of tools of claim 15, wherein the controller is configured to receive a differential pressure waveform from the differential transducer.

17. The string of tools of claim 16, wherein the controller is further configured to decode the differential pressure waveform.

19. The string of tools of claim 15, wherein:

the differential transducer is deployed in a longitudinal bore in the pressure housing; and

the tool further comprises a pressure tight bulkhead deployed in the longitudinal bore, a first end of the bulkhead being connected with the differential transducer, a second end of the bulkhead being electrically connected with the controller.

20. The string of tools of claim 15, wherein the downlinking system is configured as a stand alone assembly and sealing engages a corresponding chassis slot formed in an outer surface of the tool body.

18. The string of tools of claim 18, wherein the controller is configured to decode the differential pressure waveform to a binary waveform such that a negative pressure pulse in the differential pressure waveform is decoded as a ‘

1’

.