System, method and apparatus for petrophysical and geophysical measurements at the drilling bit

• US 7,743,654 B2
• Filed: 04/24/2007
• Issued: 06/29/2010
• Est. Priority Date: 12/22/2003
• Status: Active Grant

• Current Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Original Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Inventors: Rodney, Paul F., Spross, Ronald L.
• Primary Examiner(s): FITZGERALD, JOHN P
• Application Number:
  US11/739,581
• Publication Number:
  US 20070186639A1
• Time in Patent Office: 1,162 Days
• Field of Search: 731/520.3, 731/524.3, 175/61
• US Class Current: 73/152.03
• CPC Class Codes: E21B 45/00 Measuring the drilling time or rate of penetration
• 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 47/013 Devices specially adapted for supporting measuring instruments on drill bits
• CPC Class Codes: E21B 47/022 of the borehole, e.g. using geomagnetism
• CPC Class Codes: E21B 7/067 with means for locking sections of a pipe or of a guide for a shaft in angular relation, e.g. adjustable bent sub
• CPC Class Codes: G01V 11/00 Prospecting or detecting by methods combining techniques covered by two or more of main groups G01V1/00 - G01V9/00
• CPC Class Codes: G01V 2210/6163 Electromagnetic
• CPC Class Codes: G01V 2210/6165 Gravitational
• CPC Class Codes: G01V 2210/6167 Nuclear

Abstract

Measurement of petrophysical and geophysical data of formations in a wellbore using a long gauge bit having at least one sensor therewith. The at least one sensor may be installed in at least one flute of the long gauge bit and/or in the long gauge portion thereof. Data for creating images of the formations are obtained at or near the bottom of the borehole and proximate to the long gauge bit used for drilling the borehole. Orientation of the long gauge bit is also available on a real time basis. Magnetic and/or gravitational sensors may be used in determining bit orientation. The flutes of the long gauge bit and the long gauge portion thereof may have standard inserts to accommodate various types of different sensors and electronic packages therefor.

Claims

1. A method for determining at least one characteristic of a downhole formation, the method comprising:

disposing at least one sensor in a long gauge portion of a long gauge bit;

sampling data from the formation with the at least one sensor at rotation intervals of the long gauge bit;

determining the at least one formation characteristic based, at least in part, on the sampled data; and

wherein the at least one sensor is disposed in at least one insert in a long gauge portion of the long gauge bit.

2. The method according to claim 1, further comprising:

transferring one or more data samples to a logging-while-drilling tool.

3. The method according to claim 1, wherein the rotational intervals are divided into substantially equal segments based on predetermined variables.

4. The method according to claim 1, further comprising:

determining an azimuthal orientations of the long gauge bit.

5. The method of claim 1, wherein the long gauge bit is part of a bottom hole assembly, the method further comprising:

moving the bottom hole assembly using a rotary steerable system.

6. The method of claim 1, wherein the long gauge bit is part of a bottom hole assembly, the method further comprising:

moving the bottom hole assembly using a motor.

7. The method according to claim 1, further comprising:

correlating locations of the long gauge bit with the sampled data.

8. The method according to claim 7, wherein the correlated locations of the data samples are used to determine formation boundaries.

9. The method according to claim 1, wherein the rotational intervals are divided into unequal segments based on one or more predetermined variables.

10. The method according to claim 9, wherein the predetermined variables are selected from the group consisting of standard deviation of nuclear counting rates as a function of rotation of a tool, and measurement of standoff from a borehole wall as a function of rotation of a tool.

11. A method for determining at least one characteristic of a downhole formation, the method comprising:

disposing at least two axially spaced sensors on a long gauge bit;

taking a first pair of data samples of a formation with the at least two axially spaced sensors at a first time;

taking a second pair of data samples of the formation with the at least two axially spaced sensors at a second time; and

determining a distance traveled by the long gauge bit by comparing the first and second pairs of data samples; and

determining the formation characteristic based, at least in part, on a radial distance traveled by the long gauge bit.

12. The method of claim 11, wherein the long gauge bit is part of a bottom hole assembly, the method further comprising:

moving the bottom hole assembly using a rotary steerable system.

13. The method of claim 11, wherein the long gauge bit is part of a bottom hole assembly, the method further comprising:

moving the bottom hole assembly using a motor.

14. A formation characteristic measurement system, comprising:

a logging-while-drilling tool for coupling to a drill string;

a drive system coupled to the logging-while-drilling tool;

a long gauge bit; and

at least one sensor disposed in an insert of the long gauge portion of the long gauge bit, the sensor configured to sample data from a formation at rotation intervals of the long gauge bit;

a computer comprising at least one processor and a memory, wherein the memory includes executable instruction that cause the at least one processor to determine at least one formation characteristic base, at least in part, on the sampled data.

15. The formation characteristic measurement system of claim 14, further comprising:

a bend section coupled to the drive system.

16. The formation characteristic measurement system of claim 14, wherein the drive system comprises a rotary steerable system.

17. The formation characteristic measurement system of claim 14, wherein the drive system comprises a positive displacement motor.

18. The formation characteristic measurement system of claim 14, wherein the at least one sensor is disposed in at least one flute of the long gauge bit.

19. The formation characteristic measurement system of claim 14, wherein the at least one sensor is disposed in a long gauge portion of the long gauge bit.

20. The formation characteristic measurement system of claim 14, wherein at least two sensors are spaced apart axially.

21. The formation characteristic measurement system according to claim 14, wherein at least two sensors are spaced apart azimuthally.

22. The formation characteristic measurement system to claim 14, wherein the at least one sensor is sensitive to electromagnetic response of the formation.

23. The formation characteristic measurement system according to claim 14, wherein the at least one sensor is a gamma sensor.