Homogeneous inversion for multi-component induction tools

Patent metadata

Field	Value
Publication number	US-10416339-B2
Application number	US-201314890390-A
Country	US
Kind code	B2
Filing date	Sep 10, 2013
Priority date	Sep 10, 2013
Publication date	Sep 17, 2019
Grant date	Sep 17, 2019

Abstract

Various embodiments include apparatus and methods that perform a homogeneous inversion processing to data or signals acquired from a multicomponent induction tool operating in a wellbore. The homogeneous inversion processing can be used to provide a quality check of results from radial one dimensional borehole correction processing. Also, the homogeneous inversion processing may be employed as a dip indicator of conventional array induction logging processing. Additional apparatus, systems, and methods are disclosed.

First claim

What is claimed is:

1. A method comprising:
lowering a multi-component induction tool into a well, wherein the multi-component induction tool comprises,
a housing,
a triad of transmitter coils in the housing, wherein each of the triad of transmitter coils are non-parallel with respect to each other, and
a plurality of receiver coils, wherein the plurality of receiver coils comprises a triad of receiver coils;

activating the triad of transmitter coils at a frequency to generate an induced electromagnetic signal from a surrounding formation;
acquiring a plurality of measurements from the plurality of receiver coils, wherein the plurality of measurements comprises measurements from the triad of receiver coils, and wherein the plurality of measurements is collected from the induced electromagnetic signal;
performing a homogenous inversion based on the plurality of measurements to generate a first formation property value and performing a nonhomogeneous inversion based on the plurality of measurements to generate a second formation property value, the homogenous inversion being a zero dimensional inversion;
generating a quality metric for the plurality of measurements, wherein the quality metric is based on a comparison between the first formation property value and the second formation property value;
selecting a selected value based on the quality metric; and
determining a formation parameter based on the selected value.

2. The method of claim 1 , wherein the plurality of receiver coils comprises a plurality of receiver arrays.

3. The method of claim 1 , wherein acquiring the plurality of measurements comprises acquiring measurements corresponding to different frequencies of operation of the multi-component induction tool.

4. The method of claim 1 , wherein the nonhomogenous inversion comprises a radial one dimensional inversion with borehole correction.

5. The method of claim 1 , wherein generating the quality metric comprises setting a range limit to resistivity determined by the homogeneous inversion for a frequency of operation of the multi-component induction tool or an array of the multi-component induction tool.

6. The method of claim 1 , further comprising performing an iterative error analysis process by injecting noise at an input of homogenous inversion based on the plurality of measurements in each iteration of a set of iterations, the noise different in each iteration, and analyzing variations in results of the homogenous inversion of the set of iterations.

7. The method of claim 1 , wherein:
the plurality of receiver coils comprises a plurality of receiver arrays;
acquiring the plurality of measurements comprises acquiring the plurality of measurements from the plurality of receiver arrays at a plurality of logging points, the plurality of measurements comprising receiver measurements for each of the plurality of receiver arrays operating at a plurality of frequencies;
generating the quality metric comprises generating a quality metric for each of the plurality of receiver arrays at each frequency at each logging point; and
selecting the selected value comprises selecting an optimal frequency of operation for each of the plurality of receiver arrays from among the plurality of frequencies based on the quality metric for each of the plurality of receiver arrays at each logging point.

8. The method of claim 1 , further comprising:
determining if a dip is greater than a threshold for dip based on the first formation property value; and
modifying induction processing based on the plurality of measurements in response to the dip being greater than the threshold for dip.

9. The method of claim 1 , wherein the quality metric is correlated with a first difference, wherein the first difference is a difference between the first formation property value and the second formation property value, and wherein the first difference is smaller than a second difference, wherein the second difference is a difference between a second homogeneous inversion result based on a second plurality of measurements and a second nonhomogeneous inversion result based on the second plurality of measurements.

10. The method of claim 1 , further comprising displaying the formation parameter on a display device.

11. The method of claim 4 , wherein:
the plurality of receiver coils comprises a plurality of receiver arrays; and
generating the quality metric comprises generating at least one quality metric for each receiver array of the plurality of receiver arrays, generating at least one of quality metric for each frequency of operation of the multi-component induction tool, or generating at least one of quality metric for each frequency of operation at each receiver array of the plurality of receiver arrays.

12. The method of claim 4 , further comprising generating a signal indicating a problem with a quality of at least one of the plurality of measurements or presence of a formation characteristic that deviates from an inversion model.

13. The method of claim 4 , wherein generating each quality metric comprises identifying the quality metric as being unreliable if the quality metric is greater than a threshold, or if a resistivity determined from nonhomogeneous inversion based on the plurality of measurements is greater than a resistivity limit.

14. The method of claim 4 , wherein the quality metric is a quality metric for dip.

15. The method of claim 11 , further comprising transmitting to a display device an identification of the receiver array, frequency, or receiver array and frequency correlated to the selected value.

16. The method of claim 14 , wherein generating the quality metric for dip comprises identifying measurements used to generate the quality metric for dip as being unreliable if,
a difference between a dip generated by radial one dimensional inversion and a dip generated by homogeneous inversion is greater than a dip threshold,
a horizontal resistivity generated by radial one dimensional inversion with borehole correction based on the plurality of measurements is greater than a horizontal resistivity limit,
a vertical resistivity generated by radial one dimensional inversion with borehole correction based on the plurality of measurements is greater than a vertical resistivity limit, or
a ratio of vertical resistivity to horizontal resistivity generated by radial one dimensional inversion with borehole correction based on the plurality of measurements is less than a threshold for the ratio of vertical resistivity to horizontal resistivity.

17. A non-transitory machine-readable storage device having instructions stored thereon, which, when performed by a machine operating a processor, cause the machine to perform operations, the operations comprising:
lowering a multi-component induction tool into a well, wherein the multi-component induction tool comprises,
a housing,
a triad of transmitter coils in the housing, wherein each of the triad of transmitter coils are non-parallel with respect to each other, and
a plurality of receiver coils, wherein the plurality of receiver coils comprises a triad of receiver coils;

activating the triad of transmitter coils at a frequency to generate an induced electromagnetic signal from a surrounding formation;
acquiring a plurality of measurements from the plurality of receiver coils, wherein the plurality of measurements comprises measurements from the triad of receiver coils, and wherein the plurality of measurements is collected from the induced electromagnetic signal;
performing a homogenous inversion based on the p

Assignees

• Halliburton Energy Services Inc

Inventors

• Wu Dagang
• San Martin Luis Emilio
• Donderici Burkay

Classifications

• G01V3/108 Primary

  the emitter and the receiver coils or loops being uncoupled by positioning them perpendicularly to each other · CPC title

• G01V3/38 Primary

  Processing data, e.g. for analysis, for interpretation, for correction · CPC title

• G01V3/104

  using several coupled or uncoupled coils (G01V3/101 takes precedence) · CPC title

• G01V3/28

  using induction coils · CPC title

• E21B47/00 Primary

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