Abstract: A method and system for azimuthal direction detection of a cable. The method may comprise disposing an electromagnetic logging tool into a wellbore, transmitting a primary electromagnetic field from the one or more transmitters, recording one or more secondary electromagnetic fields at the one or more receivers, and identifying a direction to the cable from the one or more secondary electromagnetic fields. The system may comprise one or more transmitters disposed on the electromagnetic logging tool and configured to transmit a primary electromagnetic field. The system may further comprise one or more receivers disposed on the electromagnetic logging tool and configured to record one or more secondary electromagnetic fields. Additionally, the system may further comprise an information handling system configured to identify a direction to an azimuthally localized reduction in metal of the conductor or increase in the metal of the conductor from the secondary electromagnetic fields.

Abstract: Systems and methods are provided for determining the end of a reverse cementing operation based on one or more pressure measurements. In some aspects, a cement composition can be delivered to an annulus formed between a casing and a wellbore for reverse cementing the casing. In some cases, a determination that the cement composition has reached a shoe joint at a bottom portion of the casing can be based on a threshold change in a pressure measurement obtained while delivering the cement composition. In some instances, a trigger can be initiated for closing the shoe joint after determining that the cement composition has reached the shoe joint.

Abstract: Aspects of the disclosed technology provide solutions for facilitating user visualization and control the path of a new wellbore in three-dimensions (3D). This may include displaying visualizations that show a current well path, a well plan, all nearby offset well paths, and well path projections in a manner that may use different projection methods. These visualizations may also include boundaries where a drilling tool should not go, such “No-Go-Zones” may be shown in a 3D spatial visualization. Visualizations may be displayed continuously along the well path, at survey stations, and at user-defined depth positions during a drilling process. Such visualizations may include projections that show an anticipated wellbore path, based on current settings of a drilling control system. Alerts may be triggered to warn users of various issues that may affect a new well being drilled. Systems, methods, and computer-readable media are provided.

Abstract: Aspects of the subject technology relate to systems and methods for configuring links or switches that connect analog circuit elements. These analog circuit elements may be connected to a plurality of sensors that may sense different types of data. For example, these sensors may sense acoustic data, electromagnetic (EM) data, temperature, pressure, and possibly other metrics that may be located in a wellbore of an oil or gas well. These analog circuits may be configured as needed (e.g., on-the-fly) to perform optimized types of computations that may include the solving of differential equations. Examples of analog circuits that may be incorporated into a sensing system include yet are not limited to operational amplifier circuits or memcomputing devices, other components, or combinations thereof. Configured analog circuits may be coupled to digital electronics that perform other functions.

Abstract: Methods and fluids for consolidating unconsolidated particulates. An example method introduces a furfuryl alcohol-based resin treatment fluid into a wellbore; wherein the furfuryl alcohol-based resin treatment fluid is a furfuryl alcohol-based resin and a diluent. The method contacts the unconsolidated particulates within the wellbore with the furfuryl alcohol-based resin treatment fluid to produce resin-contacted unconsolidated particulates. The method further introduces a substituted amine acid treatment fluid into the wellbore after the introduction of the furfuryl alcohol-based resin treatment fluid into the wellbore; wherein the substituted amine acid treatment fluid is a substituted amine acid salt and a solvent. The method further contacts the resin-contacted unconsolidated particulates with the substituted amine acid treatment fluid.

Abstract: A burner nozzle assembly includes a plurality of burner nozzles. Each burner nozzle includes an outer housing and a nozzle receivable within the outer housing. An air inlet conveys air into a first burner nozzle of the plurality of burner nozzles and a well product inlet conveys a well product into the first burner nozzle. An air transfer conduit interposes and fluidly couples the outer housing of adjacent burner nozzles and transfers the air from the first burner nozzle to subsequent burner nozzles of the plurality of burner nozzles, and a well product transfer conduit interposes and fluidly couples the outer housing of adjacent burner nozzles and transfers the well product from the first burner nozzle to subsequent burner nozzles.

Abstract: A method includes identifying, by pre-set criteria, a first plurality of optical channels and a second plurality of optical channels using optical data generated from a plurality of optical filters of a tester tool. The method also includes determining, from the optical data, a first plurality of fluid types detected by each channel in the first plurality of optical channels using a bootstrap fluid identification technique and determining, from the optical data and the first plurality of fluid types, a second plurality of fluid types detected by each channel in the second plurality of optical channels using a guided fluid identification technique. Further, the method includes generating a spectral signature indicating fluid types for each channel within the tester tool based on the first plurality of fluid types and second plurality of fluid types.

Abstract: Embodiments of a device, system and method are disclosed herein. In one embodiment, a device comprises a sample cell configured to interact a fluid sample with an ion selective substrate to modify an optical characteristic of the ion selective substrate according to an ion concentration of the fluid sample, wherein the sample cell is also configured to optically interact an illumination light with the ion selective substrate to generate a sample light; an optical element configured to interact with the sample light to provide a modified light that has a property of the fluid sample; and a detector that receives the modified light and provides an electrical signal proportional to the property of the fluid sample indicated by the modified light; and wherein the ion selective substrate comprises a membrane, the membrane configured to change an optical property in a selected wavelength range, according to the property of the fluid sample.

Abstract: Apparatus, methods, and systems are provided to count one or more magnetically permeable objects that have passed by a magnetic sensor and determine a direction thereof. The apparatus comprises a first permanent magnet; a second permanent magnet; a magnetic field sensor disposed between opposing poles of the first permanent magnet and the second permanent magnet; and a circuit connected to the magnetic field sensor, the circuit configured to count one or more magnetically permeable objects that have passed by the magnetic field sensor, and determine direction of the one or more magnetically permeable objects based on an output of the magnetic field sensor.

Abstract: Methods and systems for cementing in a wellbore. An example method includes introducing a conduit into a wellbore. The conduit comprises a reactive metal element disposed on an exterior of the conduit. The reactive metal element comprises a reactive metal having a first volume. The method further includes circulating a cement over the exterior of the conduit and the reactive metal element, contacting the reactive metal element with a fluid that reacts with the reactive metal to produce a reaction product having a second volume greater than the first volume, and contacting a surface of the cement adjacent to the reactive metal element with the reaction product.

Abstract: Methods and fluids for enhancing friction reduction. An example method introduces a treatment fluid into a wellbore tubing disposed in a wellbore. The wellbore tubing is composed of metal ions. The treatment fluid is composed of an aqueous fluid and a metal silicate. The method further includes coating at least a portion of the wellbore tubing with a silicate film produced from the reaction of the metal silicate with the metal ions of the wellbore tubing and then fracturing the subterranean formation.

Abstract: A treatment fluid can include a base fluid and a lost-circulation package. The lost-circulation package can include plurality of particles of a first, second, and third lost-circulation material. The plurality of particles can be cellulose, sized calcium carbonate, and fibers. The particle size distribution of the plurality of particles can be selected such that the particles enter permeable areas of a subterranean formation to help prevent loss of the base fluid into the formation and allow most of the particles to pass through the screen of a shale shaker. The plurality of particles can have a particle size distribution of a d10 value in the range of 30 to 55 microns, a d50 value in the range of 60 to 100 microns, and a d90 value in the range of 130 to 190 microns. The treatment fluid can be used in an oil and gas operation.

Abstract: System and methods of controlling fracture growth during multi-well stimulation treatments. The flow distribution of treatment fluid injected into first and second well formation entry points along multiple wellbores is monitored during a current stage of a multi-well, multistage stimulation treatment. Upon determining the fracture growth and/or monitored flow distribution meets a threshold, a remainder of the current stage is partitioned into a plurality of treatment cycles and at least one diversion phase. A portion of the fluid to be injected into the first well and/or second well formation entry points is allocated to each of the treatment cycles of the partitioned stage. The treatment cycles are performed for the remainder of the current stage using the treatment fluid allocated to each treatment cycle, wherein the flow distribution is adjusted so as not to meet the threshold.

Abstract: Systems and methods for determining fluid density include receiving calibration data for a fluid density measurement tool. The fluid density measurement tool can include a cantilever beam and at least one strain sensor that is coupled to the cantilever beam. The cantilever beam can be housed in the fluid density measurement tool and is buoyed by a fluid that enters the fluid density measurement tool. The systems and methods measure strain values at the at least one strain sensor and determine a density of the fluid based on the calibration data, and the strain values measured at the at least one strain sensor.

Abstract: Methods for cementing. An example method provides a cement composition comprising an aqueous fluid, a cement, and a cement retarder; wherein the cement retarder is a waste residue from a manufacturing process of a sweetener and comprises a sugar concentration of at least 40%, a Brix value of at least 60, a nitrogen-free extract concentration of at least 50%, a total solids concentration of at least 60%, a crude protein concentration less than 10%, a fat concentration less than 5%, a fiber concentration less than 5%, and an ash concentration less than 10%. The method also introduces the cement composition into a wellbore penetrating a subterranean formation and pumps the cement composition to a location within the wellbore, and allows the cement composition to set in the location.

Abstract: Aspects of the subject technology relate to systems, methods, and computer-readable media for machine learning analysis of low-frequency signal data in fracturing operations. The present technology can receive strain data associated with a monitoring well that is proximate to a treatment well. The strain data can comprise information representing a fracturing operation associated with the treatment well. Further, the present technology can convert the strain data into image data where a color scale corresponds to a degree of strain observed by a fiber optic cable deployed in the monitoring well. As follows, the present technology can provide the image data to a machine-learning model, which is configured to identify one or more features in the image data.

Abstract: A perforating gun connection is disclosed whereby a signal may be carried from surface, down through a wireline or other conveyance, and across the connection from the pin on one perforating gun to an electrical contact structure on the next perforating gun in the string. In an example, the connection includes a connector body with an electrical pin positioned for contact with an electrical contact structure on the next perforating gun. The electrical contact structure has a contact tab aligned for engagement by the pin when connected with the connector body. The electrical contact structure may be unitarily formed to include a number of features to facilitate connection between perforating guns.

Abstract: A centralizer for a downhole probe disposed within a pipe, the centralizer having a two spaced apart primary tubular members, each with three or more centralizer strip assemblies spaced circumferentially about the wall of the primary tubular member to form seats at each end of each strip assembly. Each seat is disposed to engage a connecting rod assembly extending between the two spaced apart primary members. Each connecting rod assembly has an inner portion and an outer portion, wherein the inner portions of the connecting rod assemblies engage the outer diameter of a probe and the outer portions of the connecting rod assemblies engage the inner diameter of a pipe.

Abstract: An electro-hydraulic control system for actuating a control valve includes a control module. The control module is coupled to the surface via two hydraulic lines and an electric line. The control module uses one of the hydraulic lines as an “open” line and the other line as a “close” line. The control module includes a normally closed (NC) solenoid valve (SOV) that is coupled to the electric line and can be controlled from the surface to open or close. The opening or closing of the NC SOV in cooperation with hydraulic pressure on an “open” or “close” line of the hydraulic lines operates (i.e., closes or opens) the control valve.

Abstract: A centralizer for a downhole probe disposed within a pipe, the centralizer having an elongated, primary tubular member that is polygonal in cross-section such that the wall of the tubular primary tubular member is formed with at least three sides. Each side has two adjacent inwardly extending ridges positioned between two outwardly extending ridges. The inwardly extending ridges each extend inward to an inner diameter to engage the outer diameter of a sonde and the outwardly extending ridges each extend outward to an outer diameter to engage the inner diameter of a pipe.