Two sensor impedance estimation for uplink telemetry signals

• US 7,423,550 B2
• Filed: 12/19/2005
• Issued: 09/09/2008
• Est. Priority Date: 12/21/2004
• Status: Active Grant

• Current Assignee: Baker Hughes Incorporated (Baker Hughes Company)
• Original Assignee: Baker Hughes Incorporated (Baker Hughes Company)
• Inventors: Neubert, Michael, Wassermann, Ingolf, Reckmann, Hanno
• Primary Examiner(s): Wong; Albert K.
• Assistant Examiner(s): Dang; Hung Q
• Application Number:
  US11/311,196
• Publication Number:
  US 20060132328A1
• Time in Patent Office: 995 Days
• Field of Search: 340/853.2, 340/855.7, 340/854.3, 340/856.4, 340/855.4, 340/855.5, 340/855.6, 367/82, 367/83
• US Class Current: 340/855.7
• CPC Class Codes: E21B 47/18 through the well fluid , e.g. mud pressure pulse telemetry

Abstract

Measurements made with dual sensors (flow rate or pressure) are used to attenuate pump noise in a mud pulse telemetry system.

Claims

1. A method of communicating a signal through a fluid in a borehole between a first location and a second location, the method comprising:

(a) measuring signals in the fluid at at least two spaced apart positions at or near the second location in response to operation of at least one of (A) a noise source, and, (B) a message source;

(b) estimating from the signals at the at least two spaced apart positions a characteristic of a fluid channel between the at least two spaced apart positions;

(c) generating a message signal simultaneously with operation of the noise source;

(d) measuring additional signals at the at least two positions responsive to the message signal and the simultaneous operation of the noise source; and

(e) estimating the message signal from the additional signals and the estimated fluid characteristic.

2. The method of claim 1 wherein the signals at the at least two spaced apart locations comprise at least one of (i) pressure signals, and, (ii) flow rate signals.

3. The method of claim 1 wherein the noise source is on a side of the first and second positions opposite to the first location.

4. The method of claim 1 wherein the characteristic of the fluid comprises a transfer function between the at least two spaced apart positions.

5. The method of claim 1 wherein estimating the characteristic of the fluid further comprises performing a unitary transform of the signals at the at least two spaced apart locations.

6. The method of claim 1 wherein estimating the message signal further comprises performing a differential filtering based on one of (i) a zero forcing, and (ii) a least squares minimization.

7. The method of claim 1 wherein generating the message signal further comprises at least one of (i) Amplitude Shift Keying (ASK), (ii) Frequency Shift Keying (FSK), and, (iii) Phase Shift Keying (PSK).

8. The method of claim 1 wherein the message signal further comprises a swept frequency signal.

9. A system for communicating a signal through a fluid in a borehole between a bottomhole assembly (BHA) and a surface location, the system comprising:

(a) a message source on the bottomhole assembly (BHA) configured to generate a message signal;

(b) sensors at at least two spaced apart positions configured to measure signals in response to operation of at least one of (A) a noise source, and, (B) the message source; and

(c) a processor configured to estimate from the signals a characteristic of a fluid channel between the at least two spaced apart positions;

wherein the sensors at the at least two spaced apart positions are further configured to receive additional signals responsive to a message signal at the downhole location generated simultaneously with operation of the noise source; and

wherein the processor is further configured to estimate the message signal from the additional signals and the estimated fluid characteristic.

10. The system of claim 9 wherein the signals at the at least two spaced apart positions are selected from the group consisting of (i) pressure signals, and, (ii) flow rate signals.

11. The system of claim 9 wherein the noise source is on a side of the at least two spaced apart positions opposite to the message source.

12. The system of claim 9 wherein the characteristic of the fluid comprises a transfer function between the at least two spaced apart positions.

13. The system of claim 9 wherein in estimating the characteristic of the fluid the processor is further configured to perform a unitary transform of the signals at the at least two spaced apart positions.

14. The system of claim 13 wherein the unitary transform comprises a Fourier transform.

15. The system of claim 9 wherein in estimating the message signal the processor is further configured to perform a differential filtering based on one of (i) a zero forcing, and (ii) a least squares minimization.

16. The system of claim 9 wherein generating the message signal further comprises at least one of (i) Amplitude Shift Keying (ASK), (ii) Frequency Shift Keying (FSK), and, (iii) Phase Shift Keying (PSK).

17. The system of claim 9 wherein the message signal further comprises a swept frequency signal.

18. The system of claim 9 further comprising a drilling tubular configured to convey the BHA into the borehole.

19. The system of claim 9 wherein the message source comprises an oscillating valve.

20. A machine readable medium for use in conjunction with a bottomhole assembly (BHA), conveyed in a borehole in an earth formation, the medium encoded with instructions which enable:

(a) estimating from signals in a fluid at at least two spaced apart positions at or near a surface location in response to operation of at least one of (A) a noise source, and, (B) a message source at the downhole location, a characteristic of a fluid channel between the at least two spaced apart positions;

(b) estimating a value of a message signal generated at the BHA simultaneously with operation of the noise source from;

(A) additional signals measured at the at least two spaced apart positions responsive to operation of the message source and the simultaneous operation of the noise source, and

(B) the estimated fluid channel characteristic.

21. The machine readable medium of claim 20 further comprising at least one of (i) a ROM, (ii) an EPROM, (iii) an EAROM, (iv) a Flash Memory, and, (v) an Optical disk.

22. The machine readable medium of claim 20 further comprising instructions for performing a unitary transform of the first and second signals.

23. The machine readable medium of claim 20 further comprising instructions for performing a differential filtering.

24. The machine readable medium of claim 20 wherein generating the message signal further comprises at least one of (i) Amplitude Shift Keying (ASK), (ii) Frequency Shift Keying (FSK), and, (iii) Phase Shift Keying (PSK).

25. The machine readable medium of claim 20 further comprising instructions for generating the message signal in response to at least one of (i) a measurement of a parameter of the BHA, and, (ii) a measurement of a property of the earth formation.