Halliburton Energy Services, Inc.

Reza Khalaj Amineh

Burkay Donderici

Luis Emilio San Martin

Ahmed Elsayed Fouda

Luis Sanmartin

Aixa Maria Rivera-Rios

Ilker R Capoglu

John Andrew Quirein

Burkay Dondericl

Paul Chinling Chang

Luis Emillio San Martin

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.

Tool and method to make high resolution and high penetration measurement of corrosion

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

Pipe]parameter determinations from electromagnetic logs can be improved, in accordance with various embodiments, by weighting signals with frequencies below a threshold associated with resolution degradation lower than signals with frequencies above the threshold. The threshold frequency may be determined based on a spatial resolution associated with the logging tool and a logging speed. Further embodiments are described.

Adjustable frequency processing of electromagnetic logging data

Apparatus and methods can be implemented to monitor the condition of the production and intermediate casing strings in oil and gas field operations. A series of measurements can be made in a multi-pipe structure and received responses can be operated on by employing a mapping optimization procedure in which a surrogate model is updated. Estimates of one or more properties of the pipes of the multi-pipe structure can be generated using coefficients of the updated surrogate model. Additional apparatus, systems, and methods are disclosed.

Space mapping optimization to characterize multiple concentric pipes

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.

Determining formation characteristics using reference sensor responses recorded during pulsed drilling

An inspection tool apparatus includes a core having an axial length. The axial length is determined based on a desired depth of inspection radially from the core. A plurality of arms are coupled to and extend radially from the core. The core and the plurality of arms comprise a high permeability magnetic material. The core or at least one of the plurality of arms is wound by a respective coil that is positioned to receive magnetic flux that is passing through the core or at least one of the plurality of arms.

Downhole pipe inspection tool utilizing electromagnetic energy

Apparatus and methods to investigate a multiple nested conductive pipe structure can be implemented in a variety of applications. An electromagnetic pulsed tool disposed in the multiple nested conductive pipe structure in a wellbore can make a set of log measurements and provide a measured log at different depths in the multiple nested conductive pipe structure. A test setup or library can provide a set of small defect log measurements. Processing circuitry can process the set of log measurements to generate thickness estimations of the multiple nested conductive pipes and processing circuitry can process the set of small defect log measurements to generate small defect thickness estimations. Processing circuitry can solve a system of equations involving the thickness estimations and the small defect thickness estimations to generate thickness variations for the multiple nested conducted pipes over the different depths. Additional apparatus, systems, and methods are disclosed.

Thickness value restoration in eddy current pipe inspection

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.

Downhole electromagnetic corrosion detection using known pipe features and natural pipe variation rejection

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.

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.

Detecting and evaluating eccentricity effect in multiple pipes

Systems and methods to investigate multi-pipe structures for detection of corrosion and quantitative assessment of thickness in the multiple pipes can be implemented in a variety of applications. Systems can include a set of transmitters and multiple receivers arranged on a tool structure with variable distances to the transmitters of the set of transmitters, where the receivers are arranged to measure electromagnetic responses from a multi-pipe structure to excitation of the set of transmitters with the tool structure disposed in the multi-pipe structure. The electromagnetic responses may include responses correlated to a near field zone, a transition zone, and a far field zone, where the electromagnetic responses can be processed to recover individual thicknesses of each pipe of the multi-pipe structure. Additional apparatus, systems, and methods are disclosed.

Multi-spacing array tool for determining pipe thickness of a multi-pipe structure

A method for determining tubing permeability includes conveying a tool through a tubular string in a borehole. The tool includes a transmitter that transmits a primary electromagnetic field and a receiver that receives at least one collar response. The collar response includes a secondary electromagnetic field produced in response to the primary field by a collar in the tubular string. The method further includes determining a permeability of at least one portion of the tubular string based on a magnitude of the at least one collar response. The method further includes displaying a representation of the at least one portion of the tubular string based on the permeability.

Determining permeablility based on collar responses

Systems and methods for corrosion detection of downhole tubulars. A method may include disposing an electromagnetic logging tool in a wellbore, wherein the electromagnetic logging tool may comprise a transmitter and a receiver; making a first measurement with the electromagnetic logging tool in a first nominal section of the wellbore, wherein the first nominal section may comprise M pipes, wherein M may be a number of pipes positioned in the first nominal section; making a second measurement with the electromagnetic logging tool in a second nominal section of the wellbore, wherein the second nominal section may comprise N pipes, wherein N may be a number of pipes in the second nominal section, wherein N may be different than M; calculating a phase difference between the first and second measurements; calculating a thickness difference between the first and second measurements; calculating a first slope from at least the phase difference and the thickness difference; making a third measurement in a non-nominal section of the wellbore; and calculating a thickness associated with a depth of the third measurement using at least the first slope and the third measurement.

Remote field eddy current technique for corrosion inspection of multiple pipes including transition sections

A method and system for location a collar. A method for locating a collar may comprise disposing a logging tool within a plurality of concentric pipes in a wellbore, measuring one or more wellbore parameters, creating a corrosion detection tool log from the measuring one or more wellbore parameters, processing the corrosion detection tool log to determine a location and a position of a plurality of collars on the concentric pipes, and adjusting the corrosion detection tool log to account for the location and position of the plurality of collars. A system for locating a collar may comprise a conveyance line, a logging tool, and an information handling system. The information handling system may be capable to measure one or more wellbore parameters, create a corrosion detection tool log from the measuring one or more wellbore parameters, and document the location and the position of the plurality of collars.

Locating positions of collars in corrosion detection tool logs

Systems and methods for reducing effects of pipe couplings in electromagnetic log data. A method for corrosion detection comprises disposing an electromagnetic logging tool within a plurality of concentric pipes in a wellbore; obtaining electromagnetic log data along the concentric pipes; and identifying a location of at least one pipe coupling on at least one of the concentric pipes; and processing the electromagnetic log data to determine one or more attribute of the concentric pipes as a function of depth, wherein the processing uses the location of at least one pipe coupling to account for effect of the at least one pipe coupling on the electromagnetic log data.

Growing community of inventors

Houston, TX, United States of America

Reza Khalaj Amineh