Halliburton Energy Services, Inc.

Ilker R Capoglu

Burkay Donderici

Ahmed Elsayed Fouda

Baris Guner

Akram Ahmadi Kalateh Ahmad

Christopher Michael Jones

Bin Dai

Etienne M Samson

Junwen Dai

Jian Li

Kai Ren

Neal Gregory Skinner

Luis Emilio San Martin

Hsu-Hsiang Wu

John L Maida

Daniel Joshua Stark

Reza Khalaj Amineh

Paul Gregory James

Tasneem Mandviwala

Yenny Natali Martinez

Freeman Lee Hill, Iii

Xinwei Lan

Sushovon Singha Roy

Paul Chin Ling Chang

Charles Richard Thomas Hay

Aurel Adrian Popoviciu

Wolfgang Harmut Nitsche

Paul Chin Chang

Hsu- Hsiang Wu

A method and system for visualizing data to detect a collar. A method may comprise disposing an electromagnetic logging tool downhole; emitting an electromagnetic field from the transmitter; energizing a casing with the electromagnetic field to produce an eddy current; recording the eddy current from the casing with the receiver; creating a variable-density-log from the recorded eddy current; selecting a wrapping period for the variable-density-log; creating a wrapped-variable-density-log from the variable-density-log using the wrapping period; and determining at least one collar location and a pipe index with the wrapped-variable-density-log. A system for to detect a collar may comprise an electromagnetic logging tool. The electromagnetic logging tool may comprise a transmitter and a receiver, wherein the transmitter and the receiver may be a coil. The system may further comprise an information handling system.

Workflow and visualization for localization of concentric pipe collars

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.

Interactive virtual reality manipulation of downhole data

A disclosed downhole drilling system may include a drill bit electrically coupled to a pulse-generating circuit to generate electrical arcs between first and second electrodes during pulsed drilling operations, a sensor to record responses to electromagnetic or acoustic waves produced by the electrical arcs, and a sensor analysis system. The electrical arcs occur at different azimuthal locations between the electrodes. The sensor analysis system may obtain a plurality of measurements representing first responses recorded by the sensor during a pulsed drilling operation, generate a model of a source of the electrical arcs based on the measurements, obtain an additional measurement representing a second response recorded by the sensor during the operation, and determine a characteristic of a formation near the drill bit using an inversion based on the model and the additional measurement. The determined characteristic may be used to determine dip parameters or construct images of the formation.

System and method for determining formation characteristics using electrical arc modeling

In some embodiments, a downhole drilling system may include a pulse-generating circuit, a drill bit including a first pair of electrodes electrically coupled to the pulse-generating circuit to receive a first electrical pulse from the pulse-generating circuit and form a first electrical arc between the first pair of electrodes during a pulsed drilling operation. The system further includes a sensor to record responses to the first electrical pulse during the pulsed drilling operation and a sensor analysis system communicatively coupled to the sensor, where the sensor analysis system is configured to obtain a first measurement from the sensor representing the responses recorded by the sensor during the pulsed drilling operation. Additionally, the system may determine a first value of a dielectric constant associated with a portion of a formation in proximity to the drill bit, where the first value of the dielectric constant is based on the first measurement.

Systems and methods for dielectric mapping during pulsed-power drilling

A downhole tool may comprise a mandrel, wherein the mandrel is a structural support for the downhole tool; one or more arms, wherein the one or more arms are attached to the mandrel; and a pad, wherein the pad is connected to the one or more arms. The pad may comprise a material, where the material expands or contracts from an external electromagnetic field; an insulator, wherein the insulator is connected at a first end to the material; and an electrode, wherein the electrode is connected to the insulator. A method may comprise applying a time varying biasing voltage to a material, wherein the material exhibits mechanical strain; taking a first measurement and a second measurement with at least one operating frequency with an electrode; calculating a mud property based at least in part on the first measurement and the second measurement; and applying a mud effect removal algorithm to the mud property.

System and method for measuring mud properties

An apparatus includes a processor and a machine-readable medium having program code to cause the apparatus to obtain a first dictionary based on a first training set of signals and determine a first subset of the first training set of signals based on a training reconstruction accuracy threshold and the first dictionary, wherein each atom in the first dictionary includes at least one of a signal pattern and a function representing the signal pattern. The program code also includes code to generate a second dictionary based on a second training set of signals, wherein the second training set of signals includes the first subset of the first training set of signals.

Dictionary generation for downhole signal compression

An apparatus includes a subsurface sensor for use in a borehole to provide a subsurface measurement series, a subsurface processor to receive the subsurface measurement series, and a machine-readable medium. The machine-readable medium has program code to cause the apparatus to obtain the subsurface measurement series and generate an atom combination based on the subsurface measurement series using the subsurface processor, wherein the atom combination comprises a subset of atoms from a dictionary. The code also has instructions to generate a set of characterizing values and transmit the set of characterizing values to a different physical location, wherein the set of characterizing values comprises an atom identifier and at least one corresponding atom weight for at least one atom from the atom combination.

Downhole signal compression and surface reconstruction

The disclosed embodiments include downhole electromagnetic reservoir monitors, and systems and methods to monitor downhole reservoirs. In one embodiment, the electromagnetic reservoir monitor includes a galvanic transmitter deployed proximate a wellbore casing and having a source electrode and a return electrode, where a current flowing from the source electrode, through a formation, to the return electrode is altered by a fluid reservoir of the formation, and where an altered component of the current induces a secondary magnetic field. The electromagnetic reservoir monitor also includes a magnetic receiver having a tilted coil deployed proximate the wellbore casing, the tilted coil having an orientation relative to a cross sectional plane normal to a longitudinal axis of the wellbore casing, and the tilted coil operable to detect a component of the secondary magnetic field, where the secondary magnetic field is indicative of at least one property of the fluid reservoir.

Systems and methods to monitor downhole reservoirs

The disclosed embodiments include in-line inspection devices, methods to perform in-line inspections of pipeline and protective casings, and methods to determine anomalies of pipeline and protective casings. The method includes deploying an in-line inspection device in a section of a pipeline enclosed by a protective casing. While the in-line inspection device is traveling along the pipeline, the method also includes transmitting, at a frequency, a transmitted signal toward the protective casing; and detecting a scattered signal scattered by the protective casing. The method further includes detecting a scattered signal scattered by the protective casing. The method further includes locating an anomaly of the protective casing based on the scattered signal.

In-line inspection devices

The disclosed embodiments include an acoustic noise reduction device. In one embodiment, the device includes a first sensor operable to detect a first acoustic noise signal and a desired signal and to modulate a first plurality of optical signals in response to detecting at least one of the first acoustic noise signal and the desired signal. The device also includes a second sensor operable to detect a second acoustic noise signal and modulate a second plurality of optical signals in response to detecting the second acoustic noise signal. The device further includes a coupler that is connected to the first and second sensors, where components of the modulated first and second plurality of optical signals approximately cancel each other out.

Systems and methods to reduce acoustic noise in fiber optic based sensor systems

A method and a system for estimating a pipe property for a plurality of nested pipes. The method may comprise determining the pipe property from the plurality of measurements, wherein the pipe property identifies a feature in the wellbore, forming a pre-computed table of responses for the at least one channel comprising a plurality of points that sample the pipe property, and performing a model-based inversion to estimate the pipe property using the plurality of measurements, the nominal properties of the pipes, and a fast forward model based on the pre-computed table of responses. A system may comprise an electromagnetic logging tool and an information handling system. The electromagnetic logging tool may comprise a transmitter, wherein the transmitter is a first coil and is operable to transmit an electromagnetic field, and a receiver, wherein the receiver and is operable to measure the electromagnetic field.

Pipe thickness inversion using a fast forward model

A method and system for identifying a deformation. The method may comprise disposing an electromagnetic logging tool in a pipe string, performing a logging operation with the electromagnetic logging tool, transmitting an electromagnetic field from a transmitter, energizing the casing string with the electromagnetic field to produce an eddy current, measuring the eddy current with at least one receiver, processing the measurements of the eddy current to find a point-wise eccentricity between the casing string and the pipe string, identifying a zone with the deformation based at least in part on the point-wise eccentricity, determining at least one characteristic of the deformation, and making a wellbore decision related to an integrity of the casing string based on the at least one characteristic of the deformation or the point-wise eccentricity. The system may comprise an electromagnetic logging tool which may comprise a transmitter and at least one receiver.

Mapping pipe bends in a well casing

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.

Growing community of inventors

Houston, TX, United States of America

Ilker R Capoglu