Halliburton Energy Services, Inc.

Ferhat Turker Celepcikay

Luis Emilio San Martin

Burkay Donderici

Junsheng Hou

Dagang Wu

John Andrew Quirein

Yi Zhou

James Michael Witkowsky

A system and method of correcting induction logging data for relative dip, wherein an induction logging tool is utilized to collect initial induction logging data at a plurality of frequencies. The initial induction logging data is then corrected for skin effect and borehole effect, after which, inversion is performed on the processed induction logging data to determine a dip effect correction. The dip effect correction is then applied to the initial induction logging data in order to yield induction logging data that is dip corrected to reflect a zero relative dip. Once dip corrected, the induction logging data can be used with resistivity methodologies generally designed for instances where no dip is present in the formation under analysis. In certain embodiments, the inversion step utilizes an additive correction for the dip effect correction.

Dip correction for array induction tool data

Disclosed embodiments include systems and methods of correcting induction logging data for relative dip. Initial induction logging data is measured at a plurality of frequencies. One example embodiment includes displaying dip corrected data for a plurality of different relative dip angles, which may further be displayed with a qualitative indicator displayed over many depth samples for selecting or validating a correct relative dip angle. The data may be iteratively processed using an automated relative dip correction algorithm and analyzed by the user to obtain and apply the best relative dip correction angle to induction logging data. Once dip corrected, the induction logging data can be used with resistivity methodologies generally designed for instances where no dip is present in the formation under analysis.

Systems and methods for relative dip correction

In some embodiments, an apparatus and a system, as well as a method and an article, may operate to calculate a map that transforms fast modeled measurement results into accurate modeled measurement results within a modeled data space, to make actual measurements using a tool disposed in a borehole, to transform a plurality of modeling parameter vectors into the fast modeled measurement results via modeling, to transform the fast modeled measurement results into the accurate modeled measurement results using the map, to locate a matching modeling parameter vector as one of the plurality of modeling parameter vectors that matches the accurate modeled measurement results to the actual measurement, and to display at least a portion of the matching modeling parameter vector to represent at least one property of a geological formation. Additional apparatus, systems, and methods are described.

Measurement correction apparatus, methods, and systems

Calibration tools and procedures that provide calibration to galvanic tools can include use of measurement tools to measure resistivity of a calibration box. The resistivity of the calibration box can also be measured by a galvanic tool of interest. The two sets of measurements can be used to calibrate the galvanic tool. Additional apparatus, systems, and methods are disclosed.

Precise calibration for galvanic tools

Various systems and methods for implementing and using a full tensor micro-impedance downhole imaging tool that includes downhole emitters that induce, at azimuthally-spaced positions on a borehole wall, fields having components in three different non-coplanar directions within a formation and directionally sensitive downhole sensors that sense the components caused by each emitter. The tool further includes a downhole controller that processes signals received from the directionally sensitive downhole sensors to provide a set of measurements representative of a 3&#xd7;3 impedance tensor at each position.

Full tensor micro-impedance imaging

Various systems and methods are disclosed for implementing and using a multi-axial induction borehole imaging tool that includes emitters that induce, at azimuthally-spaced positions on a borehole wall, a plurality of fields having components in three non-coplanar directions within a formation. The tool also includes directionally sensitive inductive sensors that sense the components caused by each of the one or more inductive emitters, and a downhole controller that processes signals received from the directionally sensitive inductive sensors to provide a set of measurements representative of an impedance tensor at each position.

Multi-axial induction borehole imager

In some embodiments, an apparatus and a system, as well as a method and an article, may operate to determine apparent resistivity values of the formation associated with each of several layers comprising a set of at least three layers; to determine a resistivity correction for a selected one of the layers based on at least one of the apparent resistivity value of the selected layer, the width of the selected layer, and the apparent resistivity values in layers of the set located above and below the selected layer in the set within which the apparent resistivity value was obtained; and to generate a dip corrected resistivity value associated with the selected layer, based on the resistivity correction. Methods described herein may operate without using inversion-based or filter-based methods of dip correction. Additional apparatus, systems, and methods are disclosed.

Dip correction using estimated formation layer resistivities

In some embodiments, an apparatus and a system, as well as a method and an article, may operate to obtain a dip angle in a formation; to generate a model, using a model generation algorithm, of the formation using the dip angle; to generate a dip correction based on the model using at least two dip correction methods, at least one of which is affected more by the presence of an invasion in the formation than the other of the at least two dip correction methods; to determine existence of a fluid invasion of the formation based on comparison of results of the at least two dip correction methods; and to correct a log of parameters associated with the formation based on the existence of the fluid invasion. Additional apparatus, systems, and methods are disclosed.

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Houston, TX, United States of America

Ferhat Turker Celepcikay