Downhole triaxial electromagnetic ranging

• US 9,714,563 B2
• Filed: 12/05/2013
• Issued: 07/25/2017
• Est. Priority Date: 12/05/2013
• Status: Active Grant

• Current Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Original Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Inventors: Donderici, Burkay, Wilson, Glenn A.
• Primary Examiner(s): Ro, Yong-Suk (Philip)
• Application Number:
  US14/426,674
• Publication Number:
  US 20160047224A1
• Time in Patent Office: 1,328 Days
• CPC Class Codes: E21B 43/2406 Steam assisted gravity drainage [SAGD]
• CPC Class Codes: E21B 47/0228 using electromagnetic energy or detectors therefor
• CPC Class Codes: E21B 47/024 of devices in the borehole determining slope or direction of the borehole E21B47/022
• CPC Class Codes: E21B 47/092 by detecting magnetic anomalies
• CPC Class Codes: E21B 7/04 Directional drilling

Abstract

A ranging system calculates the distance, direction and orientation of a target well through rotationally invariant analysis of triaxial electric and magnetic field measurements from a bottom hole assembly (“BHA”) having electromagnetic sensors. The triaxial electric and magnetic field sensors can be deployed in any downhole device without explicitly needing to process or retrieve rotational information about the downhole BHA or wireline device. Also, the distance, direction and orientation of the target well can be retrieved from a single measurement position.

Claims

1. A method for downhole ranging, comprising:

drilling a first wellbore, the first wellbore comprising an elongated conductive body;

deploying an electric field sensor in a second wellbore;

inducing a current along the first wellbore that results in an electromagnetic field being emitted from the first wellbore;

receiving the electromagnetic field utilizing the electric field sensor, wherein an electric field of the electromagnetic field is measured; and

utilizing the measured electric field to thereby calculate;

an orientation of the first wellbore; and

a distance between the first and second wellbores;

or

a direction of the first wellbore in relation to the second wellbore.

2. The method as defined in claim 1, wherein the direction of the first wellbore is a direction of the measured electric field.

3. The method as defined in claim 1, further comprising calculating a gradient of the measured electric field.

4. The method as defined in claim 3, further comprising:

calculating a ratio of the measured electric field to the gradient of the measured electric field; and

calculating the distance between the first and second wellbores using the ratio.

5. The method as defined in claim 1, wherein a magnetic field sensor is also deployed in the second wellbore, the method further comprising:

measuring a magnetic field of the electromagnetic field; and

utilizing the measured electric field and measured magnetic field to thereby calculate;

the distance between the first and second wellbores;

or

the direction of the first wellbore in relation to the second wellbore.

6. The method as defined in claim 5, further comprising:

utilizing the measured electric and magnetic fields to calculate a Poynting Vector; and

utilizing the Poynting Vector to calculate;

the distance between the first and second wellbores;

or

the direction of the first wellbore in relation to the second wellbore.

7. The method as defined in claim 6, wherein the direction of the first wellbore is a direction of the Poynting Vector.

8. The method as defined in claim 6, further comprising calculating a gradient of the Poynting Vector.

9. The method as defined in claim 8, further comprising:

calculating a ratio of the Poynting Vector to the gradient of the Poynting Vector; and

calculating the distance between the first and second wellbores using the ratio.

10. The method as defined in claim 5, further comprising calculating an impedance of the measured electric and magnetic fields.

11. The method as defined in claim 10, further comprising calculating the distance between the first and second wellbores using the impedance.

12. The method as defined in claim 11, wherein calculating the distance comprises:

calculating a ratio of an imaginary component of the impedance at a radial frequency to a product of the radial frequency and magnetic permeability; and

calculating the distance between the first and second wellbores using the ratio.

13. The method as defined in claim 5, wherein the measured magnetic field is a triaxial magnetic field measurement.

14. The method as defined in claim 5, wherein:

the measured electric and magnetic fields are total electric and magnetic fields; and

the measured total electric and magnetic fields are rotationally invariant.

15. The method as defined in claim 6, wherein the calculated Poynting Vectors are rotationally invariant.

16. The method as defined in claim 1, wherein the measured electric field is a triaxial electric field measurement.

17. The method as defined in claim 1, wherein the distance or direction calculations are conducted in real-time.

18. The method as defined in claim 1, wherein the electric field sensor in the second wellbore in deployed on a bottom hole assembly.

19. The method as defined in claim 18, wherein the bottom hole assembly is a drilling assembly, logging assembly, or wireline assembly.

20. The method as defined in claim 18, further comprising steering the bottom hole assembly deployed along the second wellbore using the distance or direction calculations.

21. The method as defined in claim 18, wherein an axis of the bottom hole assembly is not parallel with an axis of the first wellbore.

22. The method as defined in claim 18, wherein inducing the current along the first wellbore comprises inducing the current using:

a time-varying current source at a wellhead of the first well;

a time-varying current source at a surface location;

or

a time-varying current source along the bottom hole assembly.

23. The method as defined in claim 1, wherein:

the first wellbore is a producer well; and

the second wellbore is an injector well, wherein the method is utilized in a Steam Assisted Gravity Drainage operation.

24. The method as defined in claim 1, wherein:

the first wellbore is a blow out well; and

the second wellbore is a relief well.

25. The method as defined in claim 1, further comprises avoiding the first wellbore using the distance calculation.

30. The relative positioning system as defined in claim 26, wherein the processing circuitry is further configured to implement any of the methods of claims 3-15.

26. A relative positioning system for downhole ranging, comprising:

a bottom hole assembly to be positioned along a monitoring well;

one or more triaxial electric and magnetic field sensors positioned along the bottom hole assembly; and

processing circuitry coupled to the sensors and configured to implement a method comprising;

measuring an electric field emitted from a target well; and

utilizing the measured electric field to thereby calculate;

an orientation of the first wellbore; and

a distance between the monitoring well and the target well;

or

a direction of the target well in relation to the monitoring well.

27. The relative positioning system as defined in claim 26, further comprising an electromagnetic transmitter positioned along the bottom hole assembly.

28. The relative positioning system as defined in claim 26, wherein the sensors are:

three collocated, orthogonal magnetic coils oriented at an angle of 45 degrees relative to an axis of the bottom hole assembly;

at least four electrodes positioned radially positioned around the bottom hole assembly;

or

at least two electrodes axially separated along the bottom hole assembly.

29. The relative positioning system as defined in claim 26, wherein the bottom hole assembly is a drilling assembly, logging assembly or wireline assembly.