Abstract: A look-ahead logging method includes obtaining an initial resistivity log. The method further includes deriving an initial formation model based on the initial resistivity log. The method further includes estimating deep resistivity measurements from the initial formation model and deriving a reduced-complexity formation model from the estimated deep resistivity measurements. The method further includes collecting actual resistivity measurements and inverting the actual resistivity measurements, using the reduced-complexity formation model, to obtain look-ahead or look-around parameter values. The method further includes displaying the look-ahead or look-around parameter values or storing the look-ahead or look-around parameter values on a non-transient information storage medium.

Abstract: Methods and devices used to calibrate EM corrosion detection tools may estimate the effects of the presence of a core on measurements to enable more accurate corrosion detection in the well line. The methods may involve sending voltages to a core of a well tool disposed in the well line to obtain signals while the core is in a saturated and unsaturated state. Subsequent measurements using the core may be calibrated using a constant resulting from the division of the signals achieved at the core in the saturated and unsaturated states.

Abstract: A substance saturation sensing method includes making a resistivity measurement of a formation proximate to a well with a logging tool prior to installation of a casing string in the well. After the casing string is installed in the well, a first set of measurements of the formation is made with a monitoring system to generate a measured response. A set of calibration values is calculated based on the first set of measurements to produce a resistivity that matches the resistivity measurement. A second set of measurements of the formation is made with the monitoring system during or after saturating of a substance occurs in the formation. At least one parameter indicative of the saturating of the substance in the formation is determined based on the second set of the measurements and the set of calibration values.

Abstract: This disclosure may relate to a system and method for calculating the mud angle from a downhole device. A method for estimating a mud angle may comprise: disposing a downhole tool into a borehole; extending an arm of the downhole tool to a first location, wherein a pad is disposed on the arm; taking a first impedance measurement with at least one button electrode, wherein the button electrode is disposed in a button array, wherein the button array is disposed on the pad; extending the arm to a second location; taking a second impedance measurement with the at least one button electrode; transmitting the first measurement and the second measurement to an information handling system; and estimating the mud angle from the first impedance measurement and the second impedance measurement with an information handling system.

Abstract: A method of detecting a flood front through a subterranean formation, comprising, measuring a distance to the flood front, processing the measured distance using a predictor-corrector filter to determine a corrected distance to the flood front, and adjusting a formation device based on the corrected distance to control a flow of the flood front.

Abstract: A method of filtering measured responses of downhole pipes, obtained by electromagnetic (EM) logging tools, to correct for natural variations in downhole pipes during downhole pipe defect characterization. A further method of directly characterizing downhole pipe defects by obtaining measured responses at known pipe features, such as casing collars. An apparatus and system for characterizing downhole pipe corrosion is also disclosed.

Abstract: A variety of methods and systems are disclosed, including, a method for improving resistivity imaging, comprising: disposing a downhole tool into a borehole, wherein the downhole tool comprises a pad and a button array disposed on the pad; taking a measurement with the button array at a location in the borehole; selecting a projection angle; obtaining a corrected measurement from the projection angle and the measurement; and constructing an image using the corrected measurement. A system for improving resistivity imaging, comprising: a downhole tool, wherein the downhole tool comprises: an arm, and a pad; a conveyance; and an information handling system, wherein the information handling system is configured to take a measurement with the button array at a location in the borehole; select a projection angle; obtain a corrected measurement from the projection angle and the measurement; and construct an image using the corrected measurement.

Abstract: In-well steam monitoring for SAGD operations using permanent fiber optic sensors installed behind the casing of an injector or producer well provides continuous monitoring of downhole steam injection. Using in-well sensor measurements, the system may also adjust or otherwise manipulate the volume of injected steam over time.

Abstract: A logging system includes an electromagnetic logging tool that collects at least one measurement of a subterranean formation at a borehole. The logging system also includes a processing system that generates a plurality of earth models of the subterranean formation based on the at least one measurement of the subterranean formation. The processing system projects at least one second earth model upon a well path of the borehole, and selects a model of the plurality of models based on a spatial correlation between at least one parameter of the selected model and a corresponding at least one parameter of the at least one second earth model.

Abstract: The disclosed embodiments include systems and methods to image a borehole. In one embodiment, a borehole imaging system having a borehole imaging tool and a processor is provided. The borehole imaging tool includes a magnetic field source and an array of electrode buttons. The borehole imaging tool also includes a galvanic source operable to inject an electrical current through one or more electrode buttons of the array of electrode buttons into the formation. The processor is operable to determine a differential voltage between at least two electrode buttons of the array of the electrode buttons, and determine the current through the one or more electrode buttons. The processor is also operable to determine a magnetic susceptibility and a resistivity of the formation based on the differential voltage and the current, respectively, and construct a visual representation of the formation based on the resistivity and the magnetic susceptibility of the formation.

Abstract: An apparatus, method, and system for multi-well ranging and planning of a second injector well in the presence of a first injector well in close proximity to a producer well. The method includes generating a three-well forward simulation model using survey data for a producer well, survey data for a first injector well, survey data for a first section of a second injector well, a producer well casing property profile, and a formation resistivity parameter. The method provides for determining the offset between the true magnetic sensor position in the BHA and a planned depth position. The method determines ranging distance and direction of the drilling well to target well using the offset between the true magnetic sensor position and the first planned depth position. The method helps to adjust directional drilling parameter to achieve constant ranging distance between drilling well and target well.

Abstract: A calibration system for an electromagnetic (EM) tool includes a processor. The processor employs the EM tool to measure responses at each of a plurality of channels. The processor records the measured responses at each of the channels in an EM data log for the channel. The processor selects one or more calibration points from the EM data log for a particular channel, based on a difference between the nominal value of the particular channel and the measured response at the calibration point being greater than a particular threshold.

Abstract: A method and electromagnetic ranging system for determining the location of a target well. A method may comprise taking a first measurement with an electromagnetic ranging tool at a first position and calculating a first modeled signal. Additionally, calculating a calibration for the electromagnetic ranging tool from at least the first measurement and the first modeled signal, taking a second measurement with the electromagnetic ranging tool at a second position, and calculating a calibrated measurement. The method may comprise determining a distance, direction, and/or orientation to a target wellbore using at least the calibrated measurement. An electromagnetic ranging system may comprise an electromagnetic ranging tool and an information handling system coupled to the electromagnetic ranging tool.

Abstract: A method and system for locating one or more bed boundaries. A method for locating one or more bed boundaries may include disposing a downhole tool into a wellbore, measuring wellbore wall resistivity with the downhole tool, extracting a vertical voltage measurement, deconvolving the vertical voltage measurement with an impulse response an apparent resistivity, and calculating a derivative of the apparent resistivity and finding one or more peaks of the derivative to determine the locations of the one or more bed boundaries. A well measurement system for locating one or more bed boundaries may include a downhole tool. The downhole tool may include a pad, an arm, a receiver disposed on the pad, and a transmitter disposed on the pad. The well measurement system may further comprise a conveyance and an information handling system.

Abstract: Apparatus and methods can be conducted in a multi-pipe structure to determine eccentricity of one or more pipes of the multi-pipe structure. A tool having a center axis as a symmetry axis of the tool can be used in which receivers are arranged as a number of pairs of receivers around the center axis of the tool. Each receiver of a pair can be disposed opposite the other receiver of the pair with respect to the center axis such that each pair is symmetrical with respect to the center axis of the tool. Eccentricity of one or more pipes of the multi-pipe structure can be determined based on the received responses at the receivers of the pairs.

Abstract: Described are tools, systems, and methods for dielectric logging using transient waveforms. In some embodiments, one or more microstrip antennas are employed for the measurements. In various embodiments, the waveforms are processed in the time-domain to determine the dielectric properties of a formation, from which geophysical formation properties can then be derived. Further embodiments are disclosed.

Abstract: A method for three dimensional visualization and manipulation of downhole data. A measured signal is received a downhole environment and a three dimensional virtualization of the measured signal is generated. A stereographic viewer displays the three dimensional virtualization of the measured signal. The three dimensional virtualization can be manipulated in response to an input from a user, thereby creating a manipulated three dimensional virtualization. The stereographic viewer can display the manipulated three dimensional virtualization.

Abstract: A downhole drilling system is disclosed. The system may include a drill bit including first and second electrodes electrically coupled to a pulse-generating circuit to receive pulse drilling signals, a reference sensor in proximity to the drill bit, an additional sensor uphole from the reference sensor, and a sensor analysis system communicatively coupled to the reference sensor and to the additional sensor. The sensor analysis system may be configured to obtain measurements representing responses recorded simultaneously by the reference sensor and by the additional sensor during a pulsed drilling operation in a wellbore, generate modified measurements in which effects of variations in the pulse drilling signal on the measurements representing responses recorded by the additional sensor are reduced based on the measurements representing responses recorded by the reference sensor and determine, based on the modified measurements, a characteristic of a formation downhole from the drill bit.

Abstract: A multi-string monitoring system that includes a processor. The processor obtains electromagnetic (EM) log measurements of a well having at least one inner tubing string and at least one outer tubing string, the measurements including first channel measurements for higher resolution and second channel measurements for deeper penetration. The processor inverts the first channel measurements over a characterization region of the well and the second channel measurements over the characterization region of the well, to obtain an attribute of the at least one outer tubing string and an attribute of the at least one inner tubing string, based, at least in part, on a first plurality of calibration coefficients and a second plurality of calibration coefficients. The processor stores the attribute of the at least one outer tubing string and the attribute of the at least one inner tubing string as a function of position along the well.

Abstract: Systems and methods for active ranging-while-drilling (ARWD) for collision avoidance and/or well interception. A method for electromagnetic ranging of a target wellbore may comprise disposing a downhole measurement tool into a wellbore, wherein the downhole measurement tool may comprise receivers comprising at least one radially spaced pair of the receivers and at least one axially spaced pair of the receivers; performing field measurements with the receivers, where a first set of field measurements are from at least one radially spaced pair of the receivers, and a second set of field measurements are from at least one axially spaced pair of the receivers; and calculating at least one target well parameter of a target well from at least one of the first set of field measurements and the second set of field measurements.