Determining borehole corrected formation properties

Patent metadata

Field	Value
Publication number	US-9223056-B2
Application number	US-201314065152-A
Country	US
Kind code	B2
Filing date	Oct 28, 2013
Priority date	May 8, 2007
Publication date	Dec 29, 2015
Grant date	Dec 29, 2015

Abstract

A method for correcting formation properties due to effects of a borehole is disclosed. The method includes obtaining voltage measurements using a logging tool disposed in a borehole penetrating a subsurface formation. The method further includes using a processor to: determine a tensor for the formation using the voltage measurement. For a given set of parameters, the processor determines, based upon the voltage measurements, a parameter value for each parameter in a subset of the set of parameters. The method further uses the processor to compute a borehole-inclusive modeled tensor that includes the effects of the borehole using the parameter values, optimize the parameter values using the determined tensor and the borehole-inclusive tensor, compute an optimized tensor using the optimized parameter values, compute a borehole corrected tensor using the optimized tensor, and determine at least one borehole corrected formation property using at least one of the borehole corrected tensor or the optimized parameter values.

First claim

The invention claimed is:

1. A method for correcting formation properties due to effects of a borehole comprising:
obtaining voltage measurements using a logging tool disposed in a borehole penetrating a subsurface formation;
using a processor to:
determine a tensor for the formation using the voltage measurements;
for a given set of parameters, determine, based upon the voltage measurements, a parameter value for each parameter in a subset of the set of parameters;
compute a borehole-inclusive modeled tensor that includes the effects of the borehole using the parameter values;
optimize the parameter values using the determined tensor and the borehole-inclusive tensor;
compute an optimized tensor using the optimized parameter values;
compute a borehole corrected tensor using the optimized tensor; and
determine at least one borehole corrected formation property using at least one of the borehole corrected tensor or the optimized parameter values.

2. The method of claim 1 , wherein the formation properties include at least one of horizontal resistivity, vertical resistivity, relative dip angle, dip azimuth angle, saturation, porosity, or formation conductivity tensor.

3. The method of claim 1 , wherein the parameters include at least one of tool eccentering azimuth angle, tool eccentering distance, mud conductivity, or borehole diameter.

4. The method of claim 1 , wherein determining the parameter values of the parameters in the subset comprises computing at least of a dip azimuth angle or a tool eccentering azimuth angle using one or more components of the determined tensor.

5. The method of claim 1 , wherein the logging tool comprises at least one transmitter antenna and at least one receiver antenna, and wherein the voltage measurements are obtained using the at least one transmitter and receiver antenna.

6. The method of claim 1 , wherein the determined tensor is at least one of an apparent conductivity tensor or a transmitter-to-receiver coupling voltage tensor.

7. The method of claim 1 , wherein the determining the parameter value for each parameter in the subset includes equating the value of a tool eccentering azimuth angle to the value of an angle of rotation that rotates the determined tensor to a frame in which a relation between certain components of the determined tensor is optimized.

8. The method of claim 1 , wherein the computing of the borehole-inclusive tensor comprises:
using a forward model to compute a grid-point specific borehole-inclusive tensor at each grid point of a multidimensional space; and
performing a multidimensional interpolation between grid points to compute the borehole-inclusive tensor.

9. The method of claim 1 , wherein the logging tool comprises an electromagnetic resistivity logging tool.

10. The method of claim 7 , wherein the electromagnetic resistivity logging tool comprises a tri-axial resistivity logging tool.

11. A method to determine a conductivity tensor for an earth formation, comprising:
providing one or more input parameters and a pre-computed forward model database to a multidimensional interpolator;
using a processor to perform a multidimensional interpolation; and
using the processor to determine the conductivity tensor using an azimuthal expansion, wherein the azimuthal expansion is constrained by using only one tool eccentering azimuth angle value and three dip azimuth angle values.

12. The method of claim 11 , wherein the input parameters comprise one or more of horizontal resistivity, vertical resistivity, dip angle, dip azimuth angle, eccentering azimuth angle, mud resistivity, hole diameter, and eccentering distance.

13. The method of claim 11 , wherein the interpolation comprises linear or quadratic interpolation.

14. The method of claim 11 , wherein the tool eccentering angle is zero degrees and the three dip azimuth angles are zero, forty-five, and ninety degrees, respectively.

15. The method of claim 11 , wherein the azimuthal expansion is a series expansion in terms of a tool eccentering azimuth angle and a dip azimuth angle.

16. A method for determining formation properties comprising:
determining a measured tensor using voltage measurements obtained using an electromagnetic logging tool disposed in a borehole penetrating a subsurface formation;
providing an initial guess for each formation parameter of a set of formation parameters of interest;
providing as inputs to a forward engine the initial guesses for the formation parameters of interest and a pre-computed borehole model database;
using the forward engine to obtain a modeled tensor;
providing as inputs to an iterative inversion the modeled tensor, the measured tensor, and error statistics associated with the voltage measurements; and
using the iterative inversion to determine a value for at least a subset of the set of formation parameters of interest based on a cost function.

17. The method of claim 16 , wherein the cost function applies a weighting function to an expression that is based on the difference between the measured tensor and the modeled tensor.

18. The method of claim 17 , wherein the expression based on the difference between the measured tensor and the modeled tensor comprises at least one of:
(a) the square of the difference between the measured tensor and the modeled tensor;
(b) the magnitude of the difference between the measured tensor and the modeled tensor raised to a power of n, wherein n >0; or
(c) the magnitude of the difference between the measured tensor and the modeled tensor raised to a power of m, wherein m is an even integer.

19. The method of claim 16 , wherein the set of formation parameters of interest comprises horizontal resistivity, vertical resistivity, dip angle, eccentering distance, borehole diameter, dip azimuth angle, or azimuth; and
wherein the subset of the set of formation parameters comprises eccentering distance, horizontal resistivity, vertical resistivity, and dip angle.

20. The method of claim 11 , wherein the three dip azimuth angle values comprise 0°, 45°, and 90°.

Assignees

• Schlumberger Technology Corp

Inventors

• Wu Peter T
• Wang Hanming
• Minerbo Gerald N

Classifications

• G01V13/00 Primary

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

• G01V1/50

  Analysing data · CPC title

• G01V3/38 Primary

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