Downhole tool dynamic and motion measurement with multiple ultrasound transducer

Patent metadata

Field	Value
Publication number	US-11519255-B2
Application number	US-201916579793-A
Country	US
Kind code	B2
Filing date	Sep 23, 2019
Priority date	Oct 16, 2018
Publication date	Dec 6, 2022
Grant date	Dec 6, 2022

Abstract

A method and system method for determining motion of a downhole tool and feeding back drilling performance. The method may comprise taking a synchronous tool face measurement of the downhole tool, taking a synchronous pulse-echo acquisition to estimate a shape of a borehole, inputting at least the shape of the borehole, the center trajectory of the downhole tool, the rotational time of the downhole tool, the position of the downhole tool, and the one or more measurements of the downhole tool into an information fusion for drilling dynamics, identifying at least one of a whirl, a vibration, or a stick-slip of the downhole tool, and identifying one or more borehole condition and a drilling efficiency. A system may comprise a downhole tool, at least two transducers, and an information handling system.

First claim

What is claimed is:

1. A method for determining motion of a downhole tool and feeding back drilling performance comprising:
synchronously taking a tool face measurement of a downhole tool and a pulse-echo acquisition, wherein one or more transducers transmit an excitation at the same time, and wherein the pulse-echo acquisition creates pulse-echo acquisition data;
calculating an initial downhole tool location;
identifying a center trajectory for the downhole tool based at least in part from the initial downhole tool location, wherein identifying the center trajectory for the downhole tool comprises:
calculating a least-square error of the synchronous pulse-echo acquisition data;
minimizing the least-square error; and
determining an acquisition shift value of the center trajectory for the downhole tool;

identifying a rotational time and a position for the downhole tool;
identifying measurement data of the downhole tool;
inputting at least the shape of the borehole, the center trajectory of the downhole tool, the rotational time of the downhole tool, the position of the downhole tool, and the measurement data of the downhole tool into an information fusion for drilling dynamics;
identifying at least one of a whirl of the downhole tool, a vibration of the downhole tool, or a stick-slip of the downhole tool from the information fusion for drilling dynamics; and
identifying one or more borehole condition and a drilling efficiency based at least in part on the whirl of the downhole tool, the vibration of the downhole tool, and/or the stick-slip of the downhole tool.

2. The method of claim 1 , wherein the downhole tool is a bottom hole assembly.

3. The method of claim 1 , wherein the measurement data are rate of penetration, weight on bit, revolutions per minute, or torque on bit.

4. The method of claim 1 , further comprising altering the downhole tool based at least in part on the one or more borehole condition and the drilling efficiency.

5. The method of claim 1 , wherein the estimate the shape of the borehole comprises:
picking a time arrival of the acquired pulse-echo;
producing a time curve from the acquired pulse-echo;
smoothing the time curve;
aligning a phase of the time curve to create at least a phase-aligned time curve; and
averaging at least the phase-aligned time curve.

6. The method of claim 5 , further comprising converting the time curve into a distance versus tool angle curve.

7. The method of claim 6 , wherein the smoothing the time arrival is performed with a circular convolution.

8. The method of claim 7 , wherein the aligning the phase of the time arrival is performed by applying a mechanical offset based at least in part on location of at least two transducers of the one or more transducers.

9. The method of claim 1 , wherein the rotational time and the position for the downhole tool is found from a gyro or a magnetometer.

10. The method of claim 1 , further comprising comparing a trajectory of the downhole tool before the minimization of the least-square error and after the minimization of the least-square error.

11. The method of claim 10 , further comprising reconstructing the trajectory of the downhole tool and the shape of the borehole.

12. A system comprising:
a downhole tool, wherein the downhole tool comprises:
at least two transducers, wherein the at least two transducers emit a pressure pulse synchronously and record an echo to create synchronous pulse-echo data; and
an information handling system to:
calculate an initial downhole tool location;
identify a center trajectory for the downhole tool based at least in part from the initial downhole tool location, wherein the identify the downhole tool center trajectory comprises:
calculate a least-square error of the synchronous pulse-echo acquisition data;
minimize the least-square; and
determine an acquisition shift value of the center trajectory for the downhole tool;

identify the downhole tool rotational information, wherein the downhole tool rotational information is identified synchronously with the pressure pulse emitted by the at least two transducers;
identify measurement data of the downhole tool; and
input at least a shape of a borehole, the downhole tool center trajectory; the downhole tool rotational information, and the measurement data of the downhole tool into an information fusion for drilling dynamics to identify at least one of a whirling of the downhole tool, a vibration of the downhole tool, or a stick slip of the downhole tool.

13. The system of claim 12 , wherein the measurement data are rate of penetration, weight on bit, revolutions per minute, or torque on bit.

14. The system of claim 12 , wherein the information handling system further alters the downhole tool based at least in part on the whirling of the downhole tool, the vibration of the downhole tool, or the stick slip of the downhole tool.

15. The system of claim 12 , further comprising comparing a trajectory of the downhole tool before the minimization of the least-square error and after the minimization of the least-square error.

16. The system of claim 15 , further comprising reconstructing the trajectory of the downhole tool and the shape of the borehole.

17. A method for determining motion of a downhole tool and feeding back drilling performance comprising:
taking a synchronous tool face measurement of the downhole tool;
taking a synchronous pulse-echo acquisition to estimate a shape of a borehole, wherein the estimate the shape of the borehole comprises:
picking a time arrival;
smoothing the time arrival;
aligning a phase of the time arrival; and
averaging the phase of the time arrival;

multiplying a mud speed and adding a radius of the downhole tool to produce a time curve and converting the time curve into a distance versus tool angle curve;
identifying a center trajectory for the downhole tool;
identifying a rotational time and a position for the downhole tool;
identifying measurement data of the downhole tool;
inputting at least the shape of the borehole, the center trajectory of the downhole tool, the rotational time of the downhole tool, the position of the downhole tool, and the measurement data of the downhole tool into an information fusion for drilling dynamics;
identifying at least one of a whirl of the downhole tool, a vibration of the downhole tool, or a stick-slip of the downhole tool from the information fusion for drilling dynamics; and
identifying one or more borehole condition and a drilling efficiency based at least in part on the whirl of the downhole tool, the vibration of the downhole tool, and/or the stick-slip of the downhole tool.

18. A method for determining motion of a downhole tool and feeding back drilling performance comprising:
taking a synchronous tool face measurement of the downhole tool;
taking a synchronous pulse-echo acquisition to estimate a shape of a borehole, wherein the estimate the shape of the borehole comprises:
picking a time arrival;
smoothing the time arrival, wherein the smoothing the time arrival is performed with a circular convolution;
aligning a phase of the time arrival; and
averaging the phase of the time arrival;

multiplying a mud speed and adding a radius of the downhole tool to produce a time curve and converting the time curve into a distance versus tool angle curve;
identifying a center trajectory for the downhole tool;
identifying a rotational time and a position for the downhole tool;
identifying measurement data of the downhole tool;
inputting at least the sh

Assignees

• Halliburton Energy Services Inc

Inventors

• Li Peng
• Weng Yu
• Chang Chung
• Marlow Rodney
• Wiecek Boguslaw

Classifications

• E21B49/003

  by analysing drilling variables or conditions (E21B49/005 takes precedence; systems specially adapted for monitoring a plurality of drilling variables or conditions E21B44/00) · CPC title

• E21B47/08

  Measuring diameters or related dimensions at the borehole · CPC title

• E21B47/024

  of devices in the borehole (determining slope or direction of the borehole E21B47/022) · CPC title

• E21B44/00 Primary

  Automatic control systems specially adapted for drilling operations, i.e. self-operating systems which function to carry out or modify a drilling operation without intervention of a human operator, e.g. computer-controlled drilling systems; Systems specially adapted for monitoring a plurality of drilling variables or conditions · CPC title

• E21B47/09 Primary

  Locating or determining the position of objects in boreholes or wells {, e.g. the position of an extending arm}; Identifying the free or blocked portions of pipes · CPC title