Monitoring Drilling Performance in a Sub-Based Unit

• US 20100032210A1
• Filed: 09/14/2009
• Published: 02/11/2010
• Est. Priority Date: 06/07/2005
• Status: Active Grant

• Current Assignee: Baker Hughes Holdings LLC (Baker Hughes Company)
• Original Assignee: Baker Hughes Incorporated (Baker Hughes Company)
• Inventors: Meiners, Matthew, Sullivan, Eric C., Teodorescu, Sorin G., Evans, John G.
• Granted Patent: US 8,376,065 B2
• Time in Patent Office: Days
• US Class Current: 175/40
• CPC Class Codes: E21B 47/017 Protecting measuring instruments

Abstract

In one aspect, a removable module or sub is provided for use in drilling a wellbore, which sub in one embodiment may include a body having a pin end and a box end configured for coupling between two members of a drill string, the body having a bore therethrough for flow of a fluid, and a sensor disposed in a pressure-sealed chamber in one of the pin end and the box end and configured to provide measurements relating to a downhole condition.

Claims

1. An apparatus for use in a wellbore, the apparatus comprising:

a bottomhole assembly (BHA) coupled to drilling tubular conveyable into the wellbore, the BHA including a drillbit configured to drill an earth formation; and

at least one removable sub in the drill string, the sub including a body having a pin end, a box end, and at least one sensor configured to make a measurement indicative of a downhole condition, the at least one sensor being disposed in a pressure-sealed chamber in the body.

2. The apparatus of claim 1, wherein the at least one sub includes a processor configured to process signals from the at least one sensor.

3. The apparatus of claim 1, wherein the pressure-sealed chamber is one of:

a chamber in the pin end and a chamber in the box end.

4. The apparatus of claim 1, wherein the downhole condition is one of:

(i) acceleration, (ii) rotational speed (RPM), (iii) weight-on-bit (WOB), (iv) torque, (v) vibration, (vi) oscillation, (vii) acceleration, (viii) stick-slip, (xi) whirl, (x) strain, (xi) bending, (xii) temperature, and (xiii) pressure.

5. The apparatus of claim 1, wherein the at least one removable sub includes an additional sub disposed at a selected location on the drilling tubular, the additional sub including an additional sensor configured to provide additional measurements indicative of the downhole condition at the selected location.

6. The apparatus of claim 1 further comprising a processor configured to:

process measurements from the at least one sensor using a model to identify a drilling dysfunction; and

alter a drilling parameter in response to the identified dysfunction.

7. The apparatus of claim 1, wherein:

the pin end includes external threads and the box end includes internal threads, each end configured to be coupled to at least one of a;

(i) drilling tubular;

(ii) sub;

(iii) drill bit, and (iv) tool in the BHA.

8. The apparatus of claim 1 further comprising a communication link configured to communicate data using one of:

an electromagnetic coupling;

an acoustic transducer;

a slip ring; and

a wired pipe.

9. A method for estimating a downhole condition, the method comprising:

providing a removable sub at a selected location in a drilling apparatus, wherein the removable sub includes a sensor in a pressure-sealed chamber, the removable sub further including a bore for flow of a fluid therethrough;

making measurements using the sensor indicative of a downhole condition; and

and processing the measurements from the sensor to estimate the downhole condition.

10. The method of claim 9, wherein the pressure-sealed chamber is disposed at one of:

a pin end of the sub and a box end of the sub.

11. The method of claim 9, wherein making the measurements comprises making measurements relating to one of:

(i) acceleration, (ii) rotational speed (RPM), (iii) weight-on-bit (WOB), (iv) torque, (v) vibration, (vi) oscillation, (vii) acceleration, (viii) stick-slip, (ix) whirl, (x) strain, (xi) bending, (xii) temperature, and (xiii) pressure.

12. The method of claim 9 further comprising:

processing the measurements from the sensor using a model to identify a drilling dysfunction; and

altering a drilling parameter in response to the identified dysfunction.

13. The method of claim 9 further comprising:

communicating data to and/or from the removable sub using one of;

an electromagnetic coupling;

an acoustic transducer;

a slip ring; and

a wired pipe.

14. The method of claim 9 further comprising:

disposing at least one additional removable sub having an additional sensor on the drilling tubular at a elected location; and

identifying the downhole condition using measurements from the additional sensor.

15. The method of claim 14 further comprising altering a drilling parameter in response to the identified downhole condition.

16. The method of claim 12 further comprising providing power to the additional sub using at least one of:

(i) a battery, and (ii) a wired pipe.

17. A sub for use in a drill string for drilling a wellbore, comprising:

a body having a pin end and a box end, each end configured for coupling to a member of a drill string, the body having a bore therethrough for flow of a fluid;

a sensor disposed in a pressure-sealed chamber in one of (i) the pin end;

(ii) the box end, the sensor configured to provide measurements relating to a downhole condition.

19. The sub of claim 17, wherein the pressure sealed chamber further comprises a processor configured to process data relating to the sensor measurements.

18. The sub of claim 18, wherein the measurements relate to one of:

(i) acceleration, (ii) rotational speed (RPM), (iii) weight on bit (WOB), (iv) torque, (v) vibration, (vi) oscillation, (vii) acceleration, (viii) stick-slip, (ix) whirl, (x) strain, (xi) bending, (xii) temperature, and (xiii) pressure.