Downhole tool dynamic and motion measurement with multiple ultrasound transducer

Patent metadata

Field	Value
Publication number	US-2020116005-A1
Application number	US-201916579793-A
Country	US
Kind code	A1
Filing date	Sep 23, 2019
Priority date	Oct 16, 2018
Publication date	Apr 16, 2020
Grant date	—

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:
taking a synchronous tool face measurement of the downhole tool; taking a synchronous pulse-echo acquisition to estimate a shape of a borehole; identifying a center trajectory for the downhole tool; identifying a rotational time and a position for the downhole tool; identifying one or more measurements 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 one or more measurements 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 one or more measurements are rate or 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; smoothing the time arrival; aligning a phase of the time arrival; and averaging the phase of the time arrival.

6 . The method of claim 5 , further comprising 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.

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.

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 , wherein identifying the center trajectory for the downhole tool comprises:
calculating an initial downhole tool location; calculating for a least-square error; calculating for a minimization of the least-square error; and determining a shift acquisition.

11 . The method of claim 10 , 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.

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

13 . A system comprising:
a downhole tool, wherein the downhole tool comprises:
at least two transducers and wherein the at least two transducers are configured to emit a pressure pulse and record an echo; and
an information handling system configured to:
identify a downhole tool center trajectory;
identify the downhole tool rotational information;
identify one or more measurements 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 one or more measurements 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.

14 . The system of claim 13 , wherein the one or more measurements are rate or penetration, weight on bit, revolutions per minute, or torque on bit.

15 . The system of claim 13 , wherein the information handling system is further configured to alter 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.

16 . The system of claim 13 , wherein to estimate a shape of a 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.

17 . The system of claim 16 , wherein the smoothing the time arrival is performed with a circular convolution.

18 . The system of claim 16 , wherein to identify the downhole tool center trajectory comprises:
calculating an initial downhole tool location; calculating for a least-square error; calculating for a minimization of the least-square error; and determining a shift acquisition.

19 . The system of claim 18 , 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.

20 . The system of claim 19 , further comprising reconstructing the trajectory of the downhole tool and the shape of the borehole.

Assignees

• Halliburton Energy Services Inc

Inventors

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

Classifications

• E21B47/085

  using radiant means, e.g. acoustic, radioactive or electromagnetic · 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

• E21B7/04

  Directional drilling · CPC title

• G01V1/50

  Analysing data · CPC title

• E21B45/00

  Measuring the drilling time or rate of penetration · CPC title