Halliburton Energy Services, Inc.

Dagang Wu

Burkay Donderici

Luis Emilio San Martin

Junsheng Hou

Michael S Bittar

Shanjun Li

Hsu-Hsiang Wu

Baris Guner

Roland Edward Chemali

Yumei Tang

Ferhat Turker Celepcikay

Jim Taylor Hill

Neeraj Sethi

A method comprises obtaining measurement data of a subsurface formation while drilling a wellbore in the subsurface formation. The method comprises generating a horizontal resistivity model of the subsurface formation at respective depths along the wellbore based on the measurement data. The method comprises generating a vertical resistivity model of the subsurface formation at the respective depths along the wellbore based on the measurement data. The method comprises generating an effective resistivity at the respective depths along the wellbore based on the horizontal resistivity model and the vertical resistivity model to indicate a formation resistivity in each direction of the wellbore. The method comprises performing a drilling operation based on the effective resistivity.

Effective resistivity models for geosteering decisions

A system and method for determining formation parameters is provided. The system includes an induction logging tool having a plurality of transmitter coils. The induction logging tool further includes a plurality of receiver coils, each of the receiver coils being spaced apart from the transmitter coils by a predetermined distance and receiving a response signal from the formation. The system includes circuitry coupled to the induction logging tool, the circuitry determining voltages induced in the plurality of receiver coils by the response signal. The circuitry separates real or in-phase portions of the determined voltages from imaginary of ninety degrees out of phase portions of the determined voltages and determines formation parameters using imaginary portions of the measured voltages.

Method for estimating formation parameters from imaginary components of measured data

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

An example downhole tool incorporating aspects of the present disclosure may include a tool body and a first flexible material coupled to the tool body. A transmitter may be coupled to the first flexible material. A receiver may coupled to the first flexible material, with the receiver having at least two antenna windings positioned in different orientations. A control unit may be communicably coupled to the transmitter and the receiver, the control unit having a processor and a memory device coupled to the processor, the memory device containing a set of instruction that, when executed by the processor, cause the processor to generate an electromagnetic signal in a downhole element using the transmitter, and measure a response of the downhole element to the electromagnetic signal using the at least two antenna windings of the receiver.

Pipe and borehole imaging tool with multi-component conformable sensors

An estimated value for invasion depth of an invasion zone in a subsurface measurement zone is calculated in a one-dimensional optimization procedure based on multi-array laterolog measurement data. A one-dimensional optimization problem is defined as having the invasion depth as a sole variable measurement zone parameter. The one-dimensional optimization problem is then solved by automated, iterative modification of the invasion depth value. The one-dimensional optimization problem can be a function to minimize a misfit error between (a) multi-array measurement values for resistivity of the subsurface measurement zone, and (b) predicted measurement values calculated in accordance with a simulated measurement zone model based at least in part on the invasion depth. In one embodiment, the optimization function defines a misfit error between (1) normalized differences between respective measurements of neighboring measurement arrays of the multi-array laterolog tool, and (2) normalized differences between respective predicted measurement values for neighboring measurement arrays.

Estimating subsurface formation and invasion properties

A multi-string corrosion monitoring method includes using a first set of electromagnetic (EM) log data to calculate attributes of a first casing string while attributes of a second casing string are assigned a fixed value. The method also includes using a second set of EM log data to calculate attributes of a second casing string while attributes of the first casing string are assigned a fixed value.

Multi-string monitoring using electro-magnetic (EM) corrosion detection tool

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.

Homogeneous inversion for multi-component induction tools

Improved algorithm for estimating anisotropic formation resistivity profile using a multi-component induction tool are disclosed. A method for estimating anisotropic formation resistivity profile of a formation comprises obtaining borehole corrected log data and determining at an azimuth angle of the formation. One or more formation bed boundaries are located and initial formation properties are calculated. One of a plurality of inversion windows is sequentially selected and a one-dimensional inversion of each of the sequentially selected one of the plurality of inversion windows is performed.

Method of estimating anisotropic formation resistivity profile using a multi-component induction tool

Fast-changing dip formation resistivity estimation methods and systems, including a formation resistivity estimation method that includes estimating an initial horizontal resistivity based upon acquired formation logging data and determining an initial value set of one or more value sets. The method further includes determining each additional value set of the one or more value sets using a 1-dimensional inversion initialized with a previously determined value set of the one or more value sets, and displaying a final value set of the one or more value sets. Each of the 1-dimensional inversions is performed using a cross-bedded formation model, and each of the one or more value sets includes one or more parameters selected from the group consisting of a horizontal resistivity, a vertical resistivity, a formation dip angle, a formation azimuth angle, a tool inclination angle, a tool azimuth angle and a depth.

Fast-changing dip formation resistivity estimation

Evaluation of formation and fracture characteristics based on multicomponent induction (MCI) log data includes automated calculation of inverted biaxial anisotropy (BA) parameters for the formation by performing an iterative BA inversion operation based on the MCI log data and using a BA formation model that accounts for transfers by axial formation anisotropy to resistivity. The BA inversion operation can be combined with a transversely anisotropic (TI) inversion based on the MCI log data and using a TI formation model, to calculate inverted TI parameters for the formation. The inverted BA parameters and the inverted TI parameters can be used, in combination, to calculate a quantified value for an identification function, to indicate estimated presence or absence of a fracture in the formation.

Log processing and fracture characterization in biaxially anisotropic formations

Device, system, and method embodiments provide fluid front monitoring via permanent, casing-mounted electromagnetic (EM) transducers. One or more casing strings have one or more transmit antennas that each encircle a casing string and one or more receive antennas that similarly encircle the casing string, with at least one receive antenna oriented differently from at least one transmit antenna to provide sensitivity to at least one cross-component signal. A processor unit derives an estimated distance to a fluid front, and may further determine a direction and orientation of the fluid front for display to a user. Signals from an array of transmit and receive antennas may be combined, optionally with signals from other boreholes, to locate and track multiple points on the fluid front. In response to the determined location and progress of the front, the processor unit may further provide control settings to adjust injection and/or production rates.

Cross-coupling based fluid front monitoring

At least some disclosed resistivity logging system embodiments include a logging tool and a processing system. The logging tool provides multi-component transmitter-receiver coupling measurements to the processing system. The processing system derives from the measurements initial formation parameter estimates based on a first formation model such as a radially-symmetric formation model having anisotropic, but otherwise homogenous dipping formation. The processing system further derives in one or more selected regions a second set of formation parameter estimates based on a second formation model such as a model having a dipping borehole through a series of horizontal formation layers, each having a vertical transverse isotropy. The processing system produces an output set of formation parameter estimates which, in the selected regions, depend on the second set of formation parameter estimates, and in at least some regions outside the selected regions, solely depend on the initial formation parameter estimates.

Multi-component induction logging systems and methods using blended-model inversion

Calibration tools and procedures that provide one or more calibration methods for multi-component induction tools can include use of a tilted elliptical loop and a circular loop. Measurement signals may be used for analytic calibration of a multicomponent induction tool. Additional apparatus, systems, and methods are disclosed.

Calibration method for multi-component induction tools

Various resistivity logging tools, systems, and methods are disclosed. At least some system embodiments include a logging tool and at least one processor. The logging tool provides transmitter-receiver coupling measurements that include at least direct coupling along the longitudinal tool axis (Czz), direct coupling along the perpendicular axis (Cxx or Cyy), and cross coupling along the longitudinal and perpendicular axes (Cxz, Cyz, Czx, or Czy). The processor combines a plurality of the coupling measurements to obtain inversion parameters. Based at least in part on the inversion parameter, the processor performs an inversion process to determine a vertical conductivity and, based in part on the vertical conductivity, determines borehole corrected values for said transmitter-receiver coupling measurements. One or more of the borehole corrected values can be provided as a function of borehole position.

Multi-component induction logging systems and methods using real-time OBM borehole correction

Various embodiments include apparatus and methods to utilize signals acquired from a multi-component induction tool operating in a wellbore. The acquired signals can be correlated to an apparent conductivity of a formation and mapped to components of the apparent conductivity tensor conductivity. A multi-stage inversion scheme can be implemented to determine three-dimensional formation parameters from operating the multi-component induction tool. Additional apparatus, systems, and methods are disclosed.

Growing community of inventors

Katy, TX, United States of America

Dagang Wu