Abstract: A geological exploration method starts by obtaining measurements and calculating properties along boreholes in an area of interest to generate log data including plural curves. Anomalies are detected along at least one curve of one of the boreholes. A machine learning regressor is trained using one or more curves without anomaly values of the one of the boreholes and/or of another similar borehole among the boreholes, to predict a synthetic curve corresponding to the at least one curve. The synthetic curve is then blended into the at least one curve.

Abstract: A method and system for determination of hydrocarbon accumulations in a subsurface geological area are disclosed. The method comprises creating a structural framework of the subsurface geological area, calculation of a mechanical stress, identifying trapping mechanisms, predicting of a relative fold movement, and estimating of the formation of the hydrocarbon accumulations, and determining the location of the hydrocarbon accumulations in the subsurface geological area.

Abstract: A transmitter of a downhole tool inserted in a borehole of a geological formation transmits a first signal. A receiver of the downhole tool receives a second signal, where the second signal is induced by the first signal in the geological formation. A simple response matrix is determined based on the second signal, where the simple response matrix includes a plurality of response components. One or more of the response components are combined and a modified response matrix is formed by replacing one or more of the plurality of response components in the simple response matrix with a linear combination of the response components of the simple response matrix. The modified response matrix is inverted and an indication of formation properties in the geological formation is output.

Abstract: A downhole system has a plurality of telemetry systems and a control system configured to obtain information from one or more sensors and transmit that information on one or more of the plurality of telemetry systems. The configuration of a controller may be changed so as to change which information is transmitted on a given telemetry system and how the information is to be transmitted on the given telemetry system.

Abstract: A method for filling a gap of missing vibration data in a set of vibration data. At least one reference waveform on a first side of the gap is selected and at least one adjacent waveform on an opposing second side of the gap is selected. It is determined whether the gap is in a section of the vibration data where a frequency of the vibration data is one of increasing, decreasing, and steady state. Where the gap is in a section of the vibration data where the frequency of the vibration data is changing substantially linearly, an analytical method is applied to at least one of the at least one reference waveform and the at least one adjacent waveform to approximate the vibration data that is missing in the gap.

Abstract: Methods and apparatus for characterizing a subterranean formation traversed by a wellbore including collecting data from the formation using a tool wherein the tool collects data to form an azimuthal image, characterizing a section of the formation comprising data and images acquired in a high angle wellbore section or horizontal wellbore section using a parametric model, and performing an inversion using apparent densities and volumetric photoelectric factor images to build a formation model wherein the inversion is tailored for high angle wellbore sections and/or horizontal wellbore sections.

Abstract: A reduced order model of an integrally bladed turbine disk (IBD) is used with experimental vibrational test data to modify a finite element model (FEM) of the IBD so that the FEM more accurately predicts the vibrational mistuning of the disk. The refined FEM can be used to evaluate a proposed modification of the IBD before the hardware is actually modified, and to evaluate the actual modification if there is a difference between the proposed and actual modifications.

Abstract: A method of determining a rate of penetration of a downhole tool. The method comprises introducing a downhole tool including a drill bit configured to drill through a subterranean formation in a wellbore, the downhole tool comprising at least one reader configured to communicate with identification tags using electromagnetic radiation. The method includes advancing the wellbore with the drill bit and placing, with a component of a bottomhole assembly of the downhole tool, a first identification tag at a first location proximate the wellbore and at least a second identification tag at a second location proximate the wellbore and separated from the first location by a distance. An interrogation signal is transmitting from the at least one reader toward a wall of the wellbore and response signals from the identification tags are received by the at least one reader to determine proximity of the identification tags to the reader.

Abstract: A method for generating a phase envelope log to characterize a subsurface formation includes drilling the borehole with a drill string, circulating a drilling fluid in the borehole, drawing a fluid sample representing a fluid contained in the subsurface formation, estimating a PVT parameter indicative of an in-situ condition of the subsurface formation from the drawn fluid sample, determining at least two phase envelopes at different depths using the estimated PVT parameter, and creating a phase envelope log formed of a continuous series of phase envelopes using the phase envelopes. A related system includes a drill string, a fluid sampling system, and a processor that estimates a PVT parameter indicative of an in-situ condition of the subsurface formation, determines at least two phase envelopes at different depths using the PVT parameter, and creates the phase envelope log.

Abstract: The disclosed embodiments relate to a system that certifies provenance of time-series data in a time-series database. During operation, the system retrieves time-series data from the time-series database, wherein the time-series data comprises a sequence of observations comprising sensor readings for each signal in a set of signals. The system also retrieves multivariate state estimation technique (MSET) estimates, which were computed for the time-series data, from the time-series database. Next, the system performs a reverse MSET computation to produce reconstituted time-series data from the MSET estimates. The system then compares the reconstituted time-series data with the time-series data. If the reconstituted time-series data matches the original time-series data, the system certifies provenance for the time-series data.

Abstract: Apparatus and methods for assessing contamination of formation fluid. A downhole sampling tool is operated to draw fluid from a subterranean formation into a chamber of the downhole sampling tool. The downhole sampling tool is then operated to discharge the fluid from the chamber while monitoring pressure of the fluid and volume of the chamber. Contamination of the discharged fluid is assessed based on the monitored fluid pressure and the monitored chamber volume.

Abstract: A system and method for providing multivariate climate change forecasting are provided that obtain, from one or more climate model datasets, simulated historical and future climate model data, and from one or more climate observational datasets, historical observed climate data. A statistical distribution, using a Bayesian model, is provided of extremes or climate indices for one or more variable climate features using the simulated climate model data and the observed climate data. One or more metrics are determined, including a prediction of a future climate variable for a determined future time period, a confidence bound of the prediction of the future climate variable for the determined future time period, and a prediction bound for the future climate variable for the determined future time period. The metrics can be transmitted to a variety of applications in a variety of formats.

Abstract: Analysis evaluates formation fluid with a downhole tool disposed in a borehole. A plurality of possible constituents is defined for the formation fluid, and constraints are defined for the possible constituents. The constraints can include boundary constraints and constraints on the system's dynamics. The formation fluid is obtained from the borehole with the downhole tool over a plurality of time intervals, and density of the obtained formation fluid is obtained at the time intervals. To evaluate the fluid composition, a state probability distribution of the possible constituents of the obtained formation fluid at the current time interval is computed recursively from that at the previous time interval and by assimilating the current measured density of the obtained formation fluid in addition to the defined boundary/dynamic constraints.

Abstract: A modal analysis is performed on a blade and disk assembly of a turbomachine, including selecting a target vibration frequency at which a target amplitude of vibration has been measured for a target node during operation, and deriving modal velocity vectors from the target amplitude at the target node. A transient analysis is performed on a numerical model of the blade and disk assembly, including modeling the connection between the blade and disk such that the connection is characterized by a first degree of flexibility representative of a first set of actual operating conditions at the connection, and introducing a perturbation to the transient analysis at an initial steady state condition by applying the modal velocity vectors suddenly to a plurality of nodes of the numerical model while maintaining the initial steady state condition.

Abstract: 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.

Abstract: A data reduction method for transmission of a borehole image to the surface of the earth using restricted band widths of LWD telemetry systems. The data reduction method is based on the measurement physics rather than mathematical compression algorithms. Measured data from a sensor are fitted, within the logging tool, to a response function relating sensor response to a parameter of interest. The coefficients of the fitted response function are scaled and then telemetered to the surface. The measured data are reconstructed at the surface by combining the telemetered coefficients with the response function. A borehole image is formed by combining reconstructed reduced data. Parameters of dipping beds intersecting the borehole can be determined from the coefficients.

Abstract: A method for displaying exploration and production (E&P) data set during an E&P tool session of a field having a subterranean formation. The method includes generating, by an E&P tool executing on a computer processor during the E&P tool session, an E&P data set based on a subterranean formation field data set, displaying, to a user controlling the E&P tool session, the E&P data set as a multi-dimensional canvas, generating, by the computer processor and in response to a user input identifying a point in the multi-dimensional canvas, a strike&dip tool tip, and further displaying the strike&dip tool tip superimposing the multi-dimensional canvas, wherein the strike&dip tool tip is tagged to the point in the multi-dimensional canvas.

Abstract: A method for visualizing seismic data of a subterranean formation, including obtaining an estimated dip field of the subterranean formation, wherein the estimated dip field represents a measure of deviation of a stratigraphic layer from flat, extracting a matrix data item surrounding a voxel of the seismic data, wherein the matrix data item is extracted from the seismic data based on a value of the estimated dip field surrounding the voxel, generating modified seismic data by at least applying a matrix operator to the seismic data, wherein the matrix operator calculates a partial derivative of the seismic data using the matrix data item, and displaying the modified seismic data.

Abstract: The current application is directed to methods and systems for processing EM-survey data in order to extract accurate earth-response curves from the raw EM-survey data. The more accurate earth-response curves are obtained as a result of a generally non-linear decimation, or parameterization, of the earth-response curves, the non-linear parameterization generally applied to extraction of earth responses from raw EM-survey data collected by multiple EM sensors. Parameterization of the earth-response curves and data allows for greater accuracy in estimating the earth-response curves from raw EM-survey data due to use of estimation methods based on processing over-determined raw EM-survey data. In addition, parameterization of earth-response curves may lead to a decrease in computational complexity and an increase in computational efficiency in subsequent intermediate-stage and final-stage processing operations.

Abstract: Apparatus, Tool and Method for Look-Ahead Advance Formation Evaluation which investigates the formation or formation characteristic in advance of the drill-bit before the formation or formation feature of interest has been penetrated or traversed. A closed-loop real-time look-ahead formation evaluation tool which provides acoustic and/or electro-magnetic formation data beyond the drill-bit using a novel angular sensor orientation which also allows for optimized signal propagation and signal returns according to an axial plane and vertical depth.

Abstract: A method of calculating a 3-D geologic model in real time using, as input, 2-D geologic data. The 3-D is used for conducting further drilling operations. The model may be updated in real time using additional measurements obtained during drilling operations.

Abstract: An apparatus for determining the concentration of a conductive fluid present in a fluid filled bore hole is described. Such apparatus are known as water hold-up meters and are frequently used in oil, gas and water filled bore holes. In bore hole applications, data bandwidth between a down hole device and the surface can be limited, while determining water hold-up based on down hole measurements can be data intensive. A technique is proposed for calculating the water hold up that requires less data to be transmitted between the down hole device and the surface.

Abstract: An apparatus for estimating a property of an earth formation penetrated by a borehole, the apparatus having: a carrier configured to be conveyed through the borehole; a transmitter disposed at the carrier and configured to transmit electromagnetic energy at a first frequency into the formation; a first antenna disposed at the carrier and configured to receive electromagnetic signals from the formation as a result of the transmitted electromagnetic energy interacting with the formation; and an active filter coupled to the antenna and configured to filter electromagnetic signals received by the antenna to let the electromagnetic signals at the first frequency pass for processing to estimate the property.

Abstract: A method and system for characterizing formation fluids contaminated with drilling mud that compensates for the presence of such drilling mud. The operations that characterize formation fluids contaminated with drilling mud can be carried out in real-time. The operations also characterize a wide array of fluid properties of petroleum samples contaminated with drilling mud in a manner that compensates for the presence of drilling mud. The operations characterize the viscosity and density of petroleum samples contaminated with drilling mud at formation conditions in a manner that compensates for differences between formation conditions and flowline measurement conditions. The operations also derive live fluid density unaffected by contamination of mud filtrate based on a scaling coefficient dependent on measured gas-oil ratio of the formation fluid.

Abstract: One method of monitoring a formation core during coring operations can include measuring resistivities of a formation internal and external to a core barrel assembly, comparing the resistivities of the formation internal and external to the core barrel assembly, and determining a displacement of the core into the core barrel assembly, based at least in part on the comparing, while the core is being cut. A formation core analysis system can include multiple longitudinally spaced apart sets of transmitters and receivers which measure resistivity of a core while the core displaces into a core barrel assembly, and multiple longitudinally spaced apart sets of transmitters and receivers which measure resistivity of a formation external to the core barrel assembly while a coring bit penetrates the formation. A speed of displacement of the core may be indicated by differences in time between measurements taken via the different sets as the core displaces.

Abstract: The invention is a method of monitoring an underground formation into which a gas is injected or from which a gas is produced, by a stratigraphic inversion of seismic data with anamorphosis of impedances. Pre-injection and post-injection seismic data are acquired. A pre-injection seismic impedance cube IP1 is determined by a stratigraphic inversion of the pre-injection seismic data. An anamorphosis function ? is defined by a function comprising a positive lower limit B1, an upper limit B4, an identity interval defined between limits B2 and B3, with B1<B2<B3<B4. A value for each limit B1, B2, B3 and B4 is associated with each cell of the cube. Post-injection seismic impedances IP2 are determined by a stratigraphic inversion of the post-injection seismic data wherein the anamorphosis function ? is applied to seismic impedances IP2. The gas is located within the zone by identifying the cells where IP2<IP1.

Abstract: The present disclosure relates to determining the attenuation of an electromagnetic signal passing through a conductive material. An antenna is provided and placed in relatively close proximity to the conductive material. An alternating current is passed through the antenna and the impedance of the antenna is measured. The attenuation is determined using the measured impedance. A single frequency measurement may be made, or multiple measurements using different frequencies may be made. Grouped parameters based on properties of the material and the frequency of the current are used to relate the coil impedance to the attenuation. A current frequency for which the ratio of the antenna's resistive part of the impedance to the angular frequency of the current is substantially insensitive to at least one of the parameters is preferred.

Abstract: A methodology improves sampling and characterization of heterogeneous, unconventional hydrocarbon-bearing regions. The methodology is designed to integrate consistently across measurements and scales. Additionally, the methodology involves characterizing various scales, such as regional-scale heterogeneity, wellbore-scale heterogeneity, core-scale heterogeneity, sample-scale, and pore-scale heterogeneity. The results are integrated across the multiple scales based on results obtained from the characterization of the scales. The methodology further comprises determining data propagation across the multiple scales in a hydrocarbon-bearing region.

Abstract: A method for logging subsurface formations penetrated by a wellbore include measuring electromagnetic properties of the formations using electromagnetic fields having a magnetic dipole axis parallel to a logging tool axis Electromagnetic properties of the formations are also measured using electromagnetic fields having a magnetic dipole axis oblique to the logging tool axis. A horizontal resistivity of the formations is determined from the parallel dipole axis measurements. A vertical resistivity, formation layer boundaries and a dip angle of the formations are determined from the oblique dipole axis measurements.

Abstract: A method for making dynamic gravity toolface measurements while rotating a downhole measurement tool in a borehole is disclosed. The method includes processing magnetic field measurements and accelerometer measurements to compute a toolface offset and further processing the toolface offset in combination with a magnetic toolface to obtain the dynamic gravity toolface. Methods for correcting dynamic and static navigational sensor measurements to remove sensor biases, for example, are also disclosed.

Abstract: Various embodiments include apparatus and methods of operation with respect to well logging. Apparatus and methods include a tool having an arrangement of transmitters and receivers that are operated at different positions downhole and a processing unit to process collected signals such that the arrangement of transmitters and receivers provides measurements that mimic operation of a different arrangement of transmitters and receivers. Additional apparatus, systems, and methods are disclosed.

Abstract: A system for determining at least one of a lithology of a formation traversed by a borehole and an operational condition of a component of a drill string disposed in the borehole is disclosed. The system includes a drill string with a high speed wired pipe telemetry system for transmitting downhole measurements made by a sensor to a computer processing system in real time. The computer processing system is external to the drill string and includes a model that models operation of the drill string and/or a formation that is being drilled. The model receives the downhole measurements and surface measurements of a drilling parameter and provides as output detection of the lithology of the formation and/or the operational condition of the component.

Abstract: Various methods are disclosed, comprising obtaining a plurality of raw depth measurements for a wellbore; obtaining survey data about a bottom hole assembly; obtaining depth compensation information; calculating a plurality of compensated depth measurements from the raw depth measurements and the depth compensation information and one or more additional corrections for residual pipe compliance, tide, and rig heave; calculating sag angle and correcting the survey data with the sag angle; determining a high fidelity wellbore trajectory from the compensated depth measurements and the survey data; and then employing the high fidelity wellbore trajectory in various drilling, formation evaluation, and production and reservoir analysis applications. Depth compensation information may comprise at least one of weight on bit, a friction factor, temperature profile, borehole profile, drill string mechanical properties, hookload, and drilling fluid property. The surveys may include both static and continuous surveys.

Abstract: A valve system for a mass flow controller that controls a flow rate of a fluid is disclosed. The valve system includes a valve movable between an open position and a closed position to adjust the flow rate of the fluid to a desired set point, and a valve controller. The valve controller sends a valve current through the valve, so as to adjust the flow rate of the fluid until an actual measured flow rate of the fluid substantially equals the desired set point. The valve controller monitors the valve current and the flow rate when the valve is moving to the closed position, determines a value of the valve current when the fluid has near-zero flow rate, and updates the valve cracking current for a next run, by setting the updated valve cracking current to the value of the valve current at the near-zero flow rate.

Abstract: Method and system for visualizing one or more properties of a subterranean earth formation while drilling a borehole using probability information from a modeling process. Probability waveforms based on information from a plurality of borehole stations may be plotted, either alone or superimposed onto other graphical representations, to provide a visual display that is easily interpreted by a user to make geosteering decisions. The probability waveforms include peaked sections that are proportional to the amount of uncertainty or error associated with a boundary estimate at a particular distance from an axis of the borehole. By providing a visual display of the uncertainty, a user can make better geosteering decisions.

Abstract: Systems and methods compress data and control data compression in borehole communication. The systems and methods convert original data collected by a sensor from a first domain into a second domain, wherein the original data is associated with one or more properties of an underground formation. A predetermined number of significant coefficients is selected from components of the second domain, wherein the predetermined number of significant coefficients are components of the second domain with largest amplitudes. The selected predetermined number of significant coefficients is quantized via an quantization technique and the selected predetermined number of significant coefficients is encoded into compressed data via an encoder.

Abstract: A continuous geomechanically stable trajectory in a subterranean formation is found by calculating at least one reachable stable position relative to a starting position based on geological data indicative of characteristics of the subterranean formation, and iteratively utilizing the calculated reachable stable position as a new starting position. The calculation may be constrained by a boundary including selected distance and direction relative to the starting position, and selected rate of angle change. Within the constraints of the boundary, the possible new trajectories considered may be discretized. The result of the calculations is a three dimensional tree which defines a stability volume. Pruning of at least some branches of the tree may be employed so that not all stable positions have the preselected number of branches, thereby helping to elongate the tree. Either or both of the tree and stability volume are used to select at least one trajectory.

Abstract: The invention is a method of constructing a three-dimensional fracture density log of a porous formation traversed by fractures and a borehole. A number N of intersections between the fractures and the borehole is measured over a section of the borehole of length L located at a depth d, from observations of the wall of this section. A conditional probability law of the three-dimensional fracture density is then estimated, knowing the number N of intersections. The value of the three-dimensional fracture density at depth d is determined by calculating the mean of this conditional probability law. Finally, the three-dimensional fracture density log is constructed by repeating the previous stages for different depths. A three-dimensional fracture density uncertainty log can also be associated by calculating quantiles of the conditional probability law.

Abstract: A method of steering a drilling operation of a well using acoustic measurements. The method includes obtaining, using a central processing unit (CPU), a clean-wet matrix line for the well, where the clean-wet matrix line includes a number of normal compressional values, obtaining, using the CPU, the acoustic measurements from at least one logging while drilling tool at a current depth of the drilling operation, where the acoustic measurements include a compressional to shear velocity ratio and a delta-T compressional measurement, and determining, using the CPU, a current phase of the drilling operation by comparing the acoustic measurements to the clean-wet matrix line. The method further includes, in response to determining that the current phase is not a target phase, generating an updated well trajectory for steering the drilling operation toward the target phase and adjusting the drilling operation using the updated well trajectory.

Abstract: This invention relates to surveying wellbores. In particular this invention provides methods of correcting magnetic surveys for the effects introduced by magnetic mud. The method of the present invention comprises, in broad terms, measuring gravitational and magnetic fields at least one position in the wellbore; comparing the measured fields with theoretical values, and introducing scale factors to adapt the measured values to equal the theoretical values thus making it possible to cope with the effects of magnetic mud.

Abstract: Embodiments of the invention provide a system and method for partitioning data for modelling a geological structure including laterally partitioning the data into multiple columns, where each column may be substantially laterally centered about a dual fiber and vertically partitioning each column at each of multiple intersection points of multiple surfaces and the dual fiber about which the column may be substantially laterally centered.

Abstract: A method for determining dip of rock formations penetrated by a wellbore using multiaxial induction measurements and imaging measurements made from within the wellbore includes estimating dip from the multiaxial induction measurements. Dip is also estimated from the imaging measurements. The dip is determined by combining the induction and imaging measurements.

Abstract: An apparatus and method for measuring depth, velocity, or both depth and velocity of instrumentation within a wellbore is provided. The apparatus includes a downhole portion movable within the wellbore in a direction generally parallel to the wellbore. The apparatus further includes a first acceleration sensor mounted at a first position within the downhole portion. The first acceleration sensor generates a first signal indicative of a first acceleration in a first direction generally parallel to the wellbore at the first position. The apparatus further includes a second acceleration sensor mounted at a second position within the downhole portion. The second acceleration sensor generates a second signal indicative of a second acceleration in a second direction generally parallel to the wellbore at the second position. The apparatus further includes a bend sensor generating a third signal indicative of an amount of bend of at least a portion of the downhole portion.

Abstract: Method for conducting a seismic survey (23) wherein the acquisition parameters are modified as the survey progresses using information (24) from sensors located to monitor structures and fixtures located in the survey area. The sensor output is compared to acceptable levels, and acquisition parameters such as the seismic source strength are adjusted (26) to prevent exceeding the acceptable levels. An automated arbitration scheme (22) is used to resolve conflicting system goals within survey resource constraints.

Abstract: A method for processing well logging data includes method dividing the well logging data into a number of constant dimensional effect segments, where each constant dimensional effect segment defines an interval having a similar dimensional effect on the log response. The well logging data is taken from a highly deviated well, which may include portions deviated at greater than 90-degrees. The method further includes dividing the constant dimensional effect segments into a number of constant property intervals, each constant dimensional effect segment including at least one corresponding constant property interval, and each constant property interval defining a wellbore distance over which a formation property is substantially constant that results in a log response having a low variance. The method further includes providing the constant property intervals to an output device.

Abstract: Systems and methods in which data compression techniques are utilized to fill a predetermined channel capacity are shown. According to one configuration, event data points within test data are selected for communication via the data communication channel and a data decimator is utilized to identify other data points within the test data to fill or substantially fill the predetermined channel capacity. The foregoing data decimator may employ one or more variables for selecting data for communication, wherein one or more of the variables are preferably adjusted in decimator iterations to select an optimum or otherwise desirable subset of data for communication. Data decimators may additionally or alternatively implement a suitable “growth” function to select the particular data for communication and/or the amount of data communicated.

Abstract: The invention is a method for inverting reservoir bi-axial anisotropy and identifying complicated fracture/cross-bedding system (104) by using tri-axial induction logs and wellbore survey/image log data. An inversion method is disclosed that uses all nine components that can be measured by tri-axial induction tools (101), plus borehole azimuth and deviation data, to solve for the tri-axial induction response in an arbitrary anisotropic formation due to the non-orthogonal bedding plane and fracture plane (or cross bedding plane). A mathematical formula is provided relating the conductivity tensor in the tool's reference frame to the conductivity tensor in a reference plane associated with the fracture/cross bedding planes (102). This equation is inverted (103) to yield the conductivity tensor components in the fracture/cross bedding coordinate system, along with dip and azimuth angles for both the fracture/cross bedding planes and the tool.

Abstract: Systems and methods which provide accurate formation information regardless of formation and borehole geometry, including those associated with high angle and horizontal wells, are shown. In providing processing of logging or image data, such as may be provided by a density tool or other tool, according to embodiments, formation attributes or features (e.g., density and dip angle) are estimated using raw data provided by a the tool. The foregoing estimations may thereafter be iteratively refined using effective volume of interest (EVOI) information. According to embodiments, depth boundaries of formation information provided by the tool are shifted as a function of azimuth for correct spatial positioning of formation features using EVOI information. Processing of formation attribute or feature data provided by embodiments may be used with respect to various tool configurations, including configurations with and without borehole standoff.

Abstract: A multicomponent induction logging tool is used on a MWD bottomhole assembly. Multifrequency focusing that accounts for the finite, nonzero, conductivity of the mandrel is applied. Using separation of modes, the principal components and relative dip angles in an earth formation are determined. The results are used for reservoir navigation in an earth formation.

Abstract: A method for determining dip of rock formations penetrated by a wellbore using multiaxial induction measurements and imaging measurements made from within the wellbore includes estimating dip from the multiaxial induction measurements. Dip is also estimated from the imaging measurements. The dip is determined by combining the induction and imaging measurements.