Downhole telemetry using adaptive feedback

• US 10,408,049 B2
• Filed: 12/03/2015
• Issued: 09/10/2019
• Est. Priority Date: 12/03/2015
• Status: Active Grant

• Current Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Original Assignee: Halliburton Energy Services Incorporated (Halliburton Company)
• Inventors: Bhongale, Satyan Gopal, Stark, Daniel Joshua
• Primary Examiner(s): Bolourchi, Nader
• Application Number:
  US15/304,415
• Publication Number:
  US 20180016893A1
• Time in Patent Office: 1,377 Days
• CPC Class Codes: E21B 47/12 Means for transmitting measuring-signals or control signals from the well to the surface, or from the surface to the well, e.g. for logging while drilling
• CPC Class Codes: E21B 47/135 using light waves, e.g. infrared or ultraviolet waves
• CPC Class Codes: H04B 10/50577 to control the phase of the modulating signal
• CPC Class Codes: H04B 10/63 Homodyne , i.e. coherent receivers where the local oscillator is locked in frequency and phase to the carrier signal
• CPC Class Codes: H04B 10/697 Arrangements for reducing noise and distortion

Abstract

Systems, methods, and computer-readable media for providing adaptive feedback in downhole telemetry in a wellbore. A feedback system includes a source assembly, which can be located on the surface or downhole, and a receiving assembly, which can likewise be located on the surface or downhole. The source assembly includes a source device that transmits a light signal having a first phase, and an encoder coupled to the source device. The receiving assembly comprising an oscillator that transmits an oscillator having a second phase, a coupler that couples the light signal with the oscillator signal, a detector and difference amplifier that detect and determine the difference between the first phase and second phase and a processor that receives the difference between the phases and provides the difference to an encoder so that the encoder can adjust the oscillator phase.

Claims

1. A feedback telemetry system, comprising:

at least one downhole tool comprising a source assembly, the source assembly further comprising;

a source device that transmits a light signal having a first phase,

wherein the source assembly utilizes dual-polarization redundancy in transmitting the light signal;

at least one telemetry unit coupled with the at least one downhole tool and operable to implement an adaptive feedback system; and

a receiving assembly communicatively coupled with the source assembly, the receiving assembly comprising;

an oscillator that transmits an oscillator signal having a second phase;

a coupler that mixes the light signal with the oscillator signal to produce a first interference signal and a second interference signal;

a detector that produces an output indicative of the first interference signal and the second interference signal;

a difference amplifier that receives the output from the detector and determines a difference between the first interference signal and the second interference signal;

a processor that receives the difference between the first interference signal and the second interference signal and estimates the first phase of the light signal based on the difference; and

an encoder that receives the estimate of the first phase of the light signal and adjusts the second phase of the oscillator signal,

wherein the difference between the first interference signal and the second interference signal is proportional to cos(Φ

(t)−

Θ

),

wherein Φ

(t) is the light signal transmitted from the source device and Θ

is the second phase of the oscillator signal.

2. The feedback system of claim 1, wherein the source assembly is located on a surface outside of a wellbore, and the receiving assembly is located downhole within the wellbore.

3. The feedback system of claim 2, wherein the source assembly comprises one or more of:

a diode laser, a dye laser, a gas laser, a chemical laser, a metal-vapor laser, a solid state laser, a frequency comb, a super-continuum light source, a fiber laser, and a broadband source coupled to a fiber Bragg grating.

4. The feedback system of claim 1, wherein the source assembly is located downhole within the wellbore, and the receiving assembly is located on a ground surface of the wellbore.

5. The feedback system of claim 4, wherein the source assembly comprises one or more of:

a quantum dot laser, a vertical-cavity surface-emitting laser, a cooled electroabsorption modulated laser, a frequency comb, a super-continuum light source, a fiber laser, and a broadband source coupled to a fiber Bragg grating.

6. The feedback system of claim 1, wherein the source assembly comprises a laser.

7. The feedback system of claim 1, further comprising a channel that connects the source assembly and the receiver assembly, wherein the channel is a fiber optic cable that transmits the light signal from the source assembly to the receiver assembly.

8. The feedback system of claim 1, wherein the detector is located on a ground surface of the wellbore or downhole within the wellbore.

9. The feedback system of claim 1, wherein the light source comprises a single light source, and the light source utilizes the dual-polarization redundancy by splitting the light signal from the single light source into two light signals and recombining the two light signals with a polarization rotation.

10. The feedback system of claim 1, wherein the light source utilizes the dual-polarization redundancy by transmitting a first light signal from a first source, and a second light signal from a second source, where the first light signal and the second light signal are approximately matched in frequency and combined at different polarizations.

11. A method of using adaptive feedback in downhole telemetry, the method comprising:

providing at least one downhole tool unit comprising a source assembly and coupled with a telemetry unit, the source assembly communicatively coupled with a receiving assembly;

mixing a source signal having an unknown phase with an oscillator signal having a known phase, the source signal transmitted from a light source of the source assembly, the oscillator signal coupled with the source signal at the receiving assembly at a surface outside a wellbore, the source signal and the oscillator signal having a same frequency; and

detecting a phase difference between the unknown phase of the source signal and the known phase of the oscillator signal,

wherein the phase difference between the unknown phase of the source signal and the known phase of the oscillator signal is proportional to cos(Φ

(t)−

Θ

),

wherein Φ

(t) is the light signal transmitted from the source device and Θ

is the second phase of the oscillator signal, and

wherein the light source utilizes dual-polarization redundancy in transmitting the source signal.

12. The method of claim 11, further comprising:

providing the phase difference to an encoder that modulates the known phase of the local oscillator so that the known phase is the sum of a constant and the unknown phase of the source signal.

13. The method of claim 11, further comprising:

providing the phase difference to the at least one downhole tool unit that resides downhole.

14. The method of claim 11, wherein detecting the phase difference comprises:

defining a scaled time as an integral of an envelope of a pulse of a light signal from a light source;

multiplying a photocurrent of the source signal by a function that is proportional to the inverse of the square root of the scaled time to provide a result;

integrating the result with respect to the scaled time to provide an integrated phase difference; and

providing the integrated phase difference to an encoder to produce a phase shift at a local oscillator.

15. A method of using adaptive feedback in downhole telemetry, the method comprising:

providing at least one downhole instrument comprising a source assembly and coupled with a telemetry unit, wherein the source assembly is further communicatively coupled with a receiving assembly;

utilizing dual-polarization redundancy to transmit a light signal from a light source at the source assembly;

receiving, at a detector of the receiver assembly, a first interference signal and a second interference signal from a mixing of an oscillator signal residing at the receiver assembly and the light signal;

providing the first interference signal and second interference signal to a differential amplifier to determine a difference between the first interference signal and second interference signal; and

estimating, by a processor, a phase difference between a first phase of the light signal and a second phase of the oscillator signal based on the difference between the first interference signal and the second interference signal,

wherein the difference between the first interference signal and the second interference signal is proportional to cos(Φ

(t)−

Θ

),

wherein Φ

(t) is the light signal transmitted from the source device and Θ

is the second phase of the oscillator signal.

16. The method of claim 15, further comprising:

outputting the phase difference to an encoder of the receiver assembly to modulate the oscillator signal so that the second phase of the oscillator signal is the first phase of the light signal plus π

/2.

17. The method of claim 15, further comprising:

outputting the phase difference to the at least one downhole instrument or storing the phase difference.

18. The method of claim 17, wherein the downhole instrument is a wireline tool disposed within a wellbore via a wireline.