Abstract: A device for cleaning a tubular of a wellbore includes a cylindrical body. The cylindrical body has a fishing neck, an upper chamber, a lower chamber, a first spring, a second spring, and a rod. The fishing neck facilitates raising and lowering the device within the tubular. The upper chamber receives a latching dog that abuts against the tubular when the device is raised and lowered within the tubular. The lower chamber receives a brush with bristles that scour a surface of the tubular as the device is lowered. The first spring exerts a force between the latching dog and the cylindrical body, while the second spring exerts a force between the brush and the cylindrical body. Finally, the rod interconnects the latching dog and the brush such that the rod forces the brush to withdraw into the cylindrical body when the latching dog actuates away from the cylindrical body.

Abstract: A method includes running a eutectic alloy system downhole in a wellbore including a first casing string and a second casing string therein, activating a differential valve tool within the second casing to generate a primary annular seal within a casing-casing annulus defined between the first casing string and second casing string, pumping a flushing fluid into the casing-casing annulus above the primary annular seal via a first ported collar, melting a eutectic alloy blanket into a molten alloy within the flushing fluid in the casing-casing annulus via a heater, solidifying the molten alloy to establish a supplemental seal above the primary annular seal in the casing-casing annulus between the first casing string and second casing string, and pumping cement into the casing-casing annulus above the supplemental seal to form a cement column in the casing-casing annulus via a second ported collar.

Abstract: A system includes a pipe, a multiphase fluid, and a measurement unit. The multiphase fluid is disposed within the pipe. The measurement unit is connected to the pipe and includes a cylindrical structure, a first magnet, a second magnet, a first coil, and a second coil. The cylindrical structure is submersed in the multiphase fluid and has a first end and a second end. The first magnet is connected to the first end of the cylindrical structure, and the second magnet is connected to the second end of the cylindrical structure. The first coil is wound around the outer circumferential surface of the pipe in a location corresponding to a location of the first magnet disposed within the orifice. The second coil is wound around the outer circumferential surface of the pipe in a location corresponding to a location of the second magnet disposed within the orifice.

Abstract: A system includes a spray head comprising a spray head inlet for hydraulic connection of a cleaning fluid, a spray head outlet for directing the cleaning fluid at a planar surface of a louver, and a movable mount for positioning the spray head proximate the planar surface of the louver. The system may include a carriage frame attached to the cooling tower proximate the louver. The system may include the movable mount being movably mounted on the carriage frame and movable in at least two orthogonal directions along the planar surface of the louver. The system may include a control system for controlling movement of the movable mount on the carriage frame and supply of the cleaning fluid to the spray head so as to cause the cleaning fluid to be sprayed at preselected portions of the louver at preselected times.

Abstract: A method to optimize a gas processing plant with control parameters. The method includes acquiring a plurality of images, using a camera, of an incoming contaminated fluid and processing, by a computer processor, the plurality of images by a machine-learned model to produce a contamination estimate. The method further includes adjusting the control parameters of the gas processing plant, forming adjusted control parameters based on, at least in part, the contamination estimate. The method further includes receiving a plurality of data signals from a plurality of sensors configured to monitor sub-processes of the gas processing plant and validating the adjusted control parameters with the received data signals by verifying that the adjusted control parameters optimize, or at least improve the performance of, the gas processing plant.

Abstract: An evaporative cooler for cooling drilling fluid includes a flow pipe having an inner surface in contact with drilling fluid and an outer surface in contact with an evaporative medium. The flow pipe has a serpentine configuration within a transportation frame. A system for cooling a drilling fluid includes a mud circulation system connecting the drilling fluid between a well and a surface where an evaporative cooler is coupled to the mud circulation system and has a serpentine flow pipe in a transportation frame. A method includes pumping heated drilling fluid from a wellbore to an evaporative cooling system, with an evaporative cooler to cool the heated drilling fluid, and sending the cooled drilling fluid back to the wellbore. Another method includes using an intermediate cooler, wherein the intermediate cooler comprises a heat exchanger and an intermediate fluid.

Abstract: Permeability in earth models has three components: natural fracture, distinctive matrix permeability and porosity correlated matrix permeability. While matrix permeability is usually predictable from porosity and diagenesis effects, fracture permeability can be a highly uncertain parameter. The earth model permeability components are calibrated by determining fracture distribution and estimating fracture properties through an iterative optimization process. The calibration proceeds iteratively until the current estimate of calculated reservoir flow capacity is within acceptable accuracy limits to reservoir flow capacity indicated from production logging tool measurements.

Abstract: Embodiments disclosed herein may relate to a testing apparatus. The testing apparatus may include a sealed, chemically-resistant testing apparatus body defining a testing void; a first fluid port and a second fluid port; and a first geomaterial and a second geomaterial. The first and second geomaterials may be positioned between the first fluid port and the second fluid port and relative to one another such that a flow channel may be provided between the first and second geomaterials. The first and second geomaterials may be coupled to a testing void interior surface so as to restrict flow to the flow channel between an upflow region and a downflow region of the testing void. The first and second geomaterials may be comprised of a natural formation material.

Abstract: A flapper holder tool may have a tubular body defining a bore extending a length from a first end to a second end. Additionally, a lip may extend radially outward at the first end. Further, an internal fish neck may be provided on an inner surface of the tubular body. The second end of the tubular body may be configured to engage a flapper of a tubing-retrievable subsurface safety valve.

Abstract: An example laser tool includes a laser head to output a laser beam and a robotic arm that is articulated and that is connected to the laser head. The robotic arm includes segments that are connected by flexible joints to enable movement of the laser head in six degrees of freedom. A control system is configured to control the robotic arm to direct output of the laser beam.

Abstract: A method for predicting a dissolved oxygen level in treated seawater includes directing raw seawater from a fluid channel into a deaerator, directing an inert gas and an oxygen scavenger solution into the deaerator, thereby removing dissolved oxygen from the raw seawater such that the treated seawater exits the deaerator, receiving information about a plurality of input parameters comprising a raw seawater flow rate, an inert gas flow rate, and an oxygen scavenger flow rate, implementing a neural network trained to predict the dissolved oxygen level of the treated seawater based on the plurality of input parameters and predicting, with the neural network, the dissolved oxygen level of the treated seawater based on the plurality of input parameters.

Abstract: A composition includes a colloidal solution which includes a solvent, a plurality of nanoparticles dispersed in the solvent, an activator dissolved in the colloidal solution, and a plurality of gel particles suspended in the colloidal solution. A method for water shutoff includes injecting a composition into a fracture near a water zone in a formation, wherein the composition includes a colloidal solution which includes a solvent, a plurality of nanoparticles dispersed in the solvent, an activator dissolved in the solvent, and a plurality of gel particles suspended in the colloidal solution.

Abstract: Barite (barium sulfate) scale may be problematic in subterranean formations, wellbores, pipelines, and other locations and may be difficult to remove in many instances. Aqueous fluid compositions effective for removing barite scale may comprise a concentrated mineral acid, a first salt comprising an iodide anion, and a second salt comprising an anion that forms an aqueous-soluble barium salt. One suitable aqueous fluid composition may comprise concentrated hydroiodic acid, an alkali metal iodide, and an alkali metal hypophosphite salt. The aqueous fluid compositions may be used in combination with a second treatment phase comprising a fluid composition comprising at least one acid gas capturing agent. The at least one acid gas capturing agent may comprise a first component reactive toward hydrogen sulfide and an optional second component reactive toward carbon dioxide.

Abstract: While operating a compressor system equipped with compression train(s), condensate is collected from within stages of the compression train(s), and directed to a blowdown system. Gas from a later stage of the compression train is routed to the blowdown system and used to drive the condensate to a condensate destination at a pressure that avoids flashing of the condensate until it reaches the condensate destination. Inside the blowdown system the condensate is stored in a tank and directed to parallel piped vessels. Operation of the vessels includes (1) receiving the condensate, (2) pressurization with gas from a later stage of compression, (3) flowing the pressurized condensate from the vessel to the condensation destination, (4) depressurizing the vessel, and (5) repeating steps (1)-(4). A flow of condensate from the blowdown system is continuous by staggering the phases of operation between the two vessels.

Abstract: Processes for producing products from crude oil include separating the crude oil into at least a lesser boiling point fraction and a greater boiling point fraction and passing the fractions to a reactor system that includes a riser section and a downer section. An outer boundary of the downer section is defined by a first wall in a plane perpendicular to a central axis, and outer boundaries of the riser section are defined by the first wall and a second wall in the plane perpendicular to the central axis. In an alternate arrangement, an outer boundary of the riser section is defined by a first wall in a plane perpendicular to a central axis, and outer boundaries of the downer section are defined by the first wall and a second wall in the plane perpendicular to the central axis. The process includes cracking the lesser boiling point fraction in the riser section in the presence of a catalyst and cracking the greater boiling point fraction in the downer reactor in the presence of the catalyst.

Abstract: Provided herein are methods and compositions for delayed in-situ generation of acids.

Abstract: An apparatus for mixing wash water and crude oil includes a crude oil pipe, a wash water manifold, a plurality of conduits, and a flow controller. The crude oil pipe includes a wall having an interior surface, an exterior surface, and a plurality of wash water injectors. The plurality of wash water injectors are angularly distributed on a circumferential band of the wall of the crude oil pipe. The flow controller is operable to regulate wash water flow through the plurality of conduits. Each of the plurality of wash water injectors is fluidly coupled to the wash water manifold by one of the plurality of conduits. The plurality of wash water injectors are arranged to provide mixing of the wash water and the crude oil when the wash water is injected into the crude oil pipe through the plurality of wash water injectors.

Abstract: An integrated process for upgrading a hydrocarbon oil feed stream includes solvent deasphalting the hydrocarbon oil stream; processing the heavy residual hydrocarbons in a gasification unit to form syngas and gasification residue; hydrotreating the deasphalted oil stream to form a C3-C4 hydrocarbon stream, a light C5+ hydrocarbon stream, and a heavy C5+ hydrocarbon stream; dehydrogenating the C3-C4 hydrocarbon stream to form propylene and butylene; steam enhanced catalytically cracking the light C5+ hydrocarbon stream; steam enhanced catalytically cracking the heavy C5+ hydrocarbon stream; passing at least a portion of the light steam enhanced catalytically cracked stream, the heavy steam enhanced catalytically cracked stream, or both to a product separator to produce a olefin product stream, a naphtha product stream, and a BTX product stream; and processing the naphtha product stream in the aromatics complex to produce benzene and xylenes.

Abstract: In accordance with one or more embodiments herein, an integrated process for upgrading a hydrocarbon oil feed stream utilizing a gasification unit, steam enhanced catalytic cracker, and an aromatics complex includes solvent deasphalting the hydrocarbon oil stream; processing the heavy residual hydrocarbons in a gasification unit to form syngas and gasification residue; hydrotreating the deasphalted oil stream to form a light C5+ hydrocarbon stream and a heavy C5+ hydrocarbon stream; steam enhanced catalytically cracking the light C5+ hydrocarbon stream; steam enhanced catalytically cracking the heavy C5+ hydrocarbon stream; passing at least a portion of the light steam enhanced catalytically cracked stream, the heavy steam enhanced catalytically cracked stream, or both to a product separator to produce a olefin product stream, a naphtha product stream, and a BTX product stream; and processing the naphtha product stream in the aromatics complex to produce benzene and xylenes.

Abstract: Systems and methods include a computer-implemented method for inspection. Sensors are installed on locations susceptible to high temperature hydrogen attack (HTHA) on equipment used in hydrocarbon facilities. Attachment uses adaptable hybrid pads. Surface data captured using permanent sensors includes surface temperatures, per hydrogen (pH) measurements, and methane measurements for methane escaping from external surfaces of the equipment. Stress cracks in the equipment base metal are detected. An HTHA susceptibility analysis of the equipment is performed based on the presence of the cracks and by analyzing surface data and mapping potential HTHA cracks and locations of early signs of methane formation, including monitoring heat-affected zones (HAZ) and fusion lines of welds. Locations of the detected stress cracks caused by HTHA in metals are determined.