Measurement-while-drilling assembly using real-time toolface oriented measurements

• US 7,000,700 B2
• Filed: 07/29/2003
• Issued: 02/21/2006
• Est. Priority Date: 07/30/2002
• Status: Active Grant

• Current Assignee: Baker Hughes Incorporated (Baker Hughes Company)
• Original Assignee: Baker Hughes Incorporated (Baker Hughes Company)
• Inventors: Estes, Robert A., Efremov, Sergey V., Bell, Samuel R., Dehlavi, Sassan, Cairns, Paul G., Schneider, David M.
• Primary Examiner(s): TSAY, FRANK
• Application Number:
  US10/629,268
• Publication Number:
  US 20040079526A1
• Time in Patent Office: 938 Days
• Field of Search: 166/250.11, 166/255.1, 166/66, 166/72, 166 40- 50, 166/255.2
• US Class Current: 166/255.2
• CPC Class Codes: E21B 44/00 Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions
• CPC Class Codes: E21B 47/002 by visual inspection
• CPC Class Codes: E21B 47/0025 generating an image of the borehole wall using down-hole measurements, e.g. acoustic or electric
• CPC Class Codes: E21B 47/024 of devices in the borehole determining slope or direction of the borehole E21B47/022
• CPC Class Codes: E21B 47/026 of penetrated ground layers
• CPC Class Codes: G01V 5/04 specially adapted for well-logging

Abstract

This invention provides a measurement-while-drilling (MWD) downhole assembly for use in drilling boreholes which utilizes directional formation evaluation devices on a rotating assembly in conjunction with toolface orientation sensors. The data from the toolface orientation sensors are analyzed by a processor and toolface angle measurements are determined at defined intervals. Formation evaluation sensors operate substantially independently of the toolface orientation sensors and measurements of the formation evaluation sensors are analyzed in combination with the determined toolface angle to obtain formation parameters.

Claims

1. A rotatable downhole assembly adapted for conveying in a borehole and determining a parameter of interest of a medium proximate to the borehole, the downhole assembly comprising:

(a) a navigation assembly which provides a measurement indicative of toolface angle of the downhole assembly, said navigation assembly associated with a first processor;

(b) a directional evaluation device which provides measurements indicative of the parameter of interest, said directional evaluation device associated with a second processor; and

(c) a common bus operatively connected to the first processor and the second processor.

2. The rotatable downhole assembly of claim 1 wherein navigation assembly further provides an indication of a location of the downhole assembly.

3. The rotatable downhole assembly of claim 1 wherein said directional evaluation device further comprises a formation evaluation device.

4. The rotatable downhole assembly of claim 3 wherein said directional evaluation device further comprises at least one of (I) at least one gamma ray, (II) a resistivity device, (III) a density logging device.

5. The rotatable downhole assembly of claim 4 wherein said at least one gamma ray detector further comprises a pair of gamma ray detectors on opposite sides of the rotatable downhole assembly.

6. The rotatable downhole assembly of claim 1 wherein said navigation assembly is conveyed one of (A) a drillstring, (B) a coiled tubing, and, (C) a wireline.

7. The rotatable downhole assembly of claim 1 wherein said navigation assembly is on a first housing and said directional evaluation device is on a second housing, said first and second housing encircling a drive shaft, said drive shaft having a mud motor at a first end and a drilling device at a second end.

8. The rotatable downhole assembly of claim 1 wherein said navigation assembly comprises a gyroscope selected from (A) a two-axis gyroscope and, (B) a three-axis gyroscope.

9. The rotatable downhole assembly of claim 1 wherein said navigation assembly comprises a three-component magnetometer.

10. The rotatable downhole assembly of claim 1 wherein:

(I) said first processor processes signals from said navigation assembly, while the rotatable downhole assembly is being rotated, to provide a value of an instantaneous tool face angle, said value being communicated on the common bus at specified intervals, and;

(II) wherein said second processor processes signals from the directional evaluation device, while the downhole assembly is being rotated, and provides a signal indicative of the parameter of interest, said signal being communicated on the common bus at specified intervals.

11. The rotatable downhole assembly of claim 10 further comprising at least one of (A) a telemetry device for transmitting information about the parameter of interest to an uphole device, and, (B) a memory for storing values of the instantaneous tool face angle and signal indicative of the parameter of interest.

12. The rotatable downhole assembly of claim 10 wherein said processing of signals from the first sensing device by the first processor is independent of said processing of signals from the directional evaluation device by the second processor.

13. The rotatable downhole assembly of claim 12 wherein said first and second processors are spaced apart.

14. The rotatable downhole assembly of claim 12 wherein said first and second processors are not spaced apart.

15. The rotatable downhole assembly of claim 12 further comprising a processor which synchronizes said value of the tool face angle with the signal indicative of the parameter of interest.

16. The rotatable downhole assembly of claim 15 further comprising at least one of (A) a telemetry device for transmitting information about the parameter of interest to an uphole device, and, (B) a memory for storing values of the instantaneous tool face angle and signal indicative of the parameter of interest.

17. The rotatable downhole assembly of claim 15 wherein said processor which synchronizes is one of the first processor and the second processor.

18. The rotatable downhole assembly of claim 1 wherein said navigation assembly includes at least one of (i) a gyroscope, (ii) a magnetometer, and, (iii) an accelerometer.

19. A method of determining a parameter of interest of a medium proximate to a borehole using a rotating assembly in said borehole, the method comprising:

(a) obtaining information about a tool-face angle of the assembly during rotation thereof;

(b) using a directionally sensitive evaluation device for obtaining measurements indicative of the parameter of interest, said measurements being obtained separately over a plurality of specified time intervals;

(c) determining from said obtained information and said measurements of the directionally sensitive evaluation device, partially processed measurements indicative of the parameter of interest over a plurality of sectors of said tool face angle; and

(d) approximating said partially processed measurements by a series expansion that includes a sinusoidal variation with said tool face angle.

20. The method of claim 19 wherein obtaining said information about said tool face angle further comprises:

(i) using a navigation assembly including a first sensing device that is at least one of (A) a gyroscope, (B) a magnetometer, and, (C) an accelerometer, for providing a measurement indicative of said toolface angle; and

(ii) using a processor associated with the navigation assembly for determining said toolface angle over said time intervals.

21. The method of claim 20 wherein said rotating assembly further comprises a drill bit for penetrating a formation, the method further comprising using at least one of (I) said gyroscope, and, (II) an accelerometer, for determining a rate of penetration (ROP) of said downhole assembly.

22. The method of claim 19 wherein said series expansion further includes, a sinusoidal variation of twice said tool face angle.

23. The method of claim 19 wherein said directionally sensitive evaluation device further comprises at least one nuclear sensor.

24. The method of claim 23 wherein the at least one nuclear sensor further comprises a pair of nuclear sensors on substantially opposite sides of the downhole assembly.

25. The method of claim 24 further comprising using a drill bit coupled to the downhole assembly for penetrating a formation and using measurements from said pair of nuclear sensors for determining a relative inclination of the borehole to a formation boundary.

26. The method of claim 23 further comprising using a drill bit coupled to the downhole assembly for penetrating a formation and using measurements from said at least one nuclear sensor for determining a relative inclination of the borehole to a formation boundary.

27. The method of claim 23 wherein said at least one nuclear sensor comprises a gamma ray sensor.

28. The method of claim 19 wherein said directionally sensitive evaluation device comprises a resistivity device.

29. The method of claim 19 wherein said directionally sensritive evaluation device comprises a density measurement device.

30. The method of claim 19 further comprising using a processor for determining from said series expansion an indication of proximity to a bed boundary in the subsurface formation.

31. A method of obtaining a processed image of a borehole in an earth formation using a rotating downhole assembly in said borehole, the method comprising:

(a) obtaining information about a tool-face angle of the assembly during rotation thereof;

(b) using a directionally sensitive evaluation device for obtaining measurements indicative of a property of said earth formation at a plurality of tool-face angles;

(c) repeating (a) and (b) at a plurality of different times and obtaining a raw data set;

(d) fitting said raw data set at each of said plurality of different times with a fitting function to obtain a partially processed data set;

(e) applying a low pass filter to said partially processed data set at each of said plurality of tool-face angles and defining a fully processed data set; and

(f) displaying said fully processed data set as an image.

32. The method of claim 31 wherein said fitting function further comprises a sinusoidal function.

33. The method of claim 31 further comprising determining contours of an equal value of said fully processed data set.