Pump noise reduction and cancellation

Patent metadata

Field	Value
Publication number	US-9249793-B2
Application number	US-201213548906-A
Country	US
Kind code	B2
Filing date	Jul 13, 2012
Priority date	Jul 13, 2012
Publication date	Feb 2, 2016
Grant date	Feb 2, 2016

Abstract

A method for transmitting data from a downhole component includes: measuring a borehole fluid pressure by a receiver at a selected sampling rate and estimating a pressure signal transmitted through the fluid based on the sampled fluid pressures; measuring, by at least one pump stroke sensor, operation of a pump configured to advance fluid through the borehole; identifying individual stroke events from the pump stroke sensor measurement; generating a digital pump stroke signal in response to detecting one or more stroke events, each pump stroke signal including a digital time value associated with each of one or more stroke events; and transmitting the pump stroke signal to the receiver.

First claim

What is claimed is:

1. A method for transmitting data from a downhole component, the method comprising:
receiving a fluid pulse telemetry signal at a receiver, wherein receiving includes measuring a borehole fluid pressure by the receiver at a selected sampling rate and estimating the telemetry signal transmitted through the fluid based on the sampled fluid pressures;
measuring, by at least one pump stroke sensor, operation of a pump configured to advance at least a portion of the borehole fluid through the borehole, wherein measuring includes detecting one or more individual events related to movement of one or more components of the pump;
generating a digital pump stroke signal for each of the one or more individual events, each digital pump stroke signal including a digital time value associated with one of the one or more individual events; and
transmitting the telemetry signal and each digital pump stroke signal to a signal processing unit, the signal processing unit configured to remove a pump signature from the telemetry signal.

2. The method of claim 1 , wherein generating the digital pump stroke signal includes generating an individual digital signal for each of a plurality of individual stroke events and storing a plurality of individual digital pump stroke signals, and transmitting includes transmitting an array of the plurality of individual digital signals to the signal processing unit as a signal transmission.

3. The method of claim 1 , wherein generating the digital pump stroke signal includes sampling the pump stroke sensor measurement at a sampling rate that is less than the selected sampling rate of the receiver.

4. The method of claim 1 , wherein generating the digital pump stroke signal includes triggering an event signal associated with each individual event based on a time-based change in the pump stroke sensor measurement.

5. The method of claim 4 , wherein the time-based change is a polarity change in the pump stroke sensor measurement.

6. The method of claim 1 , wherein the stroke event is at least one of a full pump cycle and one or more strobes.

7. The method of claim 1 , wherein the pump stroke signal includes a calibration factor relating to a number of strobes associated with the full pump cycle.

8. The method of claim 1 , wherein the digital pump stroke signal includes only the time value and an identifier that identifies the pump stroke sensor.

9. The method of claim 1 , wherein transmitting the pump stroke signal includes sending one pump stroke signal for each of the one or more stroke events, each pump stroke signal having only a digital indication of the time value of the stroke event and a pump identification.

10. The method of claim 1 , wherein generating the digital pump stroke signal includes sampling the pump stroke sensor measurement at the selected sampling rate, and disregarding data from the sampled pump stroke signal that does not indicate a stroke event.

11. The method of claim 1 , further comprising removing pump artifacts from the pressure signal using the pump stroke signal.

12. The method of claim 11 , wherein removing pump artifacts includes applying the pump signature to the pressure signal, the pump signature representing a pressure variation due to the pump during a full pump cycle.

13. The method of claim 12 , wherein removing pump artifacts includes subtracting the pump signature from the pressure signal over a time interval calculated based on the pump stroke signal.

14. A telemetry system comprising:
a transmitter disposed in a borehole in an earth formation, the transmitter configured to generate a pressure signal in a borehole fluid representing a communication from a downhole component;
a receiver configured to measure a borehole fluid pressure at a selected sampling rate and estimate the pressure signal transmitted through the fluid based on the sampled fluid pressures;
a pump stroke sensor configured to measure operation of a pump configured to advance at least a portion of the borehole fluid through the borehole, wherein measuring includes detecting one or more individual events related to movement of one or more components of the pump;
a processor configured to:
generate a digital pump stroke signal for each of the one or more individual events, each digital pump stroke signal including a digital time value associated with one of the one or more individual events; and
transmit the pressure signal and each digital pump stroke signal to a signal processing unit, the signal processing unit configured to remove a pump signature from the telemetry signal.

15. The system of claim 14 , wherein each digital pump stroke signal includes a pump identification.

16. The system of claim 14 , wherein the processor is configured to send one digital pump stroke signal for each of the one or more individual events, each pump stroke signal having only a digital indication of the time value of the stroke event and a pump identification.

17. The system of claim 14 , wherein the processor is configured to generate the digital pump stroke signal by sampling the pump stroke sensor measurement at the selected sampling rate, and disregarding data from the sampled pump stroke signal that does not indicate a stroke event.

18. The system of claim 14 , wherein the processor is configured to remove pump artifacts from the pressure signal using the pump stroke signal.

19. The system of claim 14 , wherein the processor is connected to the receiver by one of a wired network and a wireless network.

20. The system of claim 14 , wherein the processor is connected to the receiver via a field instrumentation bus.

Assignees

• Brackel Hans-Uwe
• Baker Hughes Inc

Inventors

• Brackel Hans-Uwe

Classifications

• E21B47/20 Primary

  by modulation of mud waves, e.g. by continuous modulation · CPC title

• F04B49/08

  Regulating by delivery pressure · CPC title

• F04B49/06

  Control using electricity (regulating by means of floats actuating electric switches F04B49/04) · CPC title

• F04B47/02 Primary

  the driving mechanisms being situated at ground level (F04B47/12 takes precedence) · CPC title

• E21B49/08

  Obtaining fluid samples or testing fluids, in boreholes or wells · CPC title