Method for in-situ calibration of electromagnetic corrosion detection tools

Patent metadata

Field	Value
Publication number	US-10670563-B2
Application number	US-201615533956-A
Country	US
Kind code	B2
Filing date	Aug 12, 2016
Priority date	Aug 12, 2016
Publication date	Jun 2, 2020
Grant date	Jun 2, 2020

Abstract

A calibration system for an electromagnetic (EM) tool includes a processor. The processor employs the EM tool to measure responses at each of a plurality of channels. The processor records the measured responses at each of the channels in an EM data log for the channel. The processor determines a nominal value of each of the channels, as being equal to a histogram peak of the EM data log. The processor selects one or more calibration points from the EM data log for a particular channel, based on a difference between the nominal value of the particular channel and the measured response at the calibration point being greater than a particular threshold. The processor determines a plurality of parameters by reducing a misfit between synthetic data and both the nominal values of the channels and the measured responses of the channels at the selected one or more calibration points.

First claim

What is claimed is:

1. A method of determining properties of a tubing string of one or more tubing strings in a subterranean formation, comprising:
obtaining a plurality of measurements using a device positioned in the tubing string at a particular location,
wherein the plurality of measurements correspond to either a plurality of transmitter signal frequencies or a plurality of measurement time slots measured by at least one receiver, and
wherein a thickness and a diameter of the tubing string at the particular location are known;

determining a plurality of calibration coefficients based on the plurality of measurements, the known thickness, and the known diameter,
wherein determining the plurality of calibration coefficients comprises:
assigning calibration coefficients of an equal magnitude to measurements corresponding to at least two frequencies of the plurality of transmitter signal frequencies; or
assigning calibration coefficients of an equal value to measurements corresponding to at least two slots of the plurality of measurement time slots; And

obtaining a plurality of second measurements using the device positioned in the tubing string at a second location different from the particular location; and
estimating at least one of a thickness or a diameter of the tubing string at the second location based on the plurality of calibration coefficients and the obtained plurality of second measurements.

2. The method of claim 1 , wherein the at least two frequencies comprise two lowest frequencies of the plurality of transmitter signal frequencies.

3. The method of claim 1 , wherein the at least two slots comprise two latest slots of the plurality of measurement time slots.

4. The method of claim 1 , further comprising: determining that corrosion of the tubing string has occurred at the second location, if the estimated thickness of the tubing string at the second location is less than a threshold value.

5. The method of claim 1 , wherein estimating the thickness of the tubing string at the second location comprises using a radial 1-dimensional (1D) model.

6. The method of claim 1 , further comprising: determining an estimate of an effective magnetic permeability of the tubing string at the particular location; and determining an estimate of an effective magnetic permeability of the tubing string at the second location based at least on the determined estimate of the effective magnetic permeability of the tubing string at the particular location.

7. The method of claim 1 , wherein the device comprises an electromagnetic (EM) induction tool including at least one transmitter coil and at least one receiver coil.

8. The method of claim 1 , wherein at least one of the plurality of measurements is based on either an average of two or more measurements collected over a length of a section of the tubing string, or a histogram peak of the two or more measurements.

9. A system for determining properties of a tubing string of one or more tubing strings in a subterranean formation, the system comprising:
a measurement device that obtains a plurality of measurements of the tubing string at a particular location,
wherein the plurality of measurements correspond to either a plurality of transmitter signal frequencies or a plurality of measurement time slots measured by at least one receiver of the measurement device,
wherein a thickness and a diameter of the tubing string at the particular location are known; and
wherein the measurement device obtains a plurality of second measurements of the tubing string at a second location different from the particular location; and

a processor that determines a plurality of calibration coefficients based on the plurality of measurements, the known thickness, and the known diameter by:
assigning calibration coefficients of an equal magnitude to measurements corresponding to at least two frequencies of the plurality of transmitter signal frequencies; or
assigning calibration coefficients of an equal value to measurements corresponding to at least two slots of the plurality of measurement time slots; and
the processor estimates at least one of a thickness or a diameter of the tubing string at the second location based on the plurality of calibration coefficients and the obtained plurality of second measurements.

10. The system of claim 9 , wherein the at least two frequencies comprise two lowest frequencies of the plurality of transmitter signal frequencies.

11. The system of claim 9 , wherein the at least two slots comprise two latest slots of the plurality of measurement time slots.

12. The method of claim 9 , wherein the processor further determines that corrosion of the tubing string has occurred at the second location, if the estimated thickness of the tubing string at the second location is less than a threshold value.

13. The method of claim 9 , wherein the processor estimates the thickness of the tubing string at the second location by using a radial l-dimensional (1D) model.

14. The method of claim 9 , wherein the processor further: determines an estimate of an effective magnetic permeability of the tubing string at the particular location; and determines an estimate of an effective magnetic permeability of the tubing string at the second location based at least on the determined estimate of the effective magnetic permeability of the tubing string at the particular location.

15. The system of claim 9 , wherein the device comprises an electromagnetic (EM) induction tool including at least one transmitter coil and at least one receiver coil.

16. The system of claim 9 , wherein at least one of the plurality of measurements is based on either an average of two or more measurements collected over a length of a section of the tubing string, or a histogram peak of the two or more measurements.

Assignees

• Halliburton Energy Services Inc

Inventors

• Fouda Ahmed E
• Donderici Burkay
• San Martin Luis Emilio
• Khalaj Amineh Reza

Classifications

• E21B47/0006

  Fixed Constructions · mapped topic

• G01N27/9073

  Recording measured data · CPC title

• G01V13/00 Primary

  Manufacturing, calibrating, cleaning, or repairing instruments or devices covered by groups G01V1/00 – G01V11/00 · CPC title

• E21B47/0905

  Fixed Constructions · mapped topic

• E21B47/00

  Survey of boreholes or wells (monitoring pressure or flow of drilling fluid E21B21/08) · CPC title