Abstract: Systems and methods include a computer-implemented method for determining a concentration of hydrocarbon fuel in a fluid sample. A thin Cyclic Olefin Copolymer (COC) film of a COC layer having a honeycomb mesh-pattern forming a conductive metal trace is sputtered. The thin COC film is configured to dissolve upon contact with alkyl aromatic compounds present in hydrocarbon fuels. A fluid sample of a hydrocarbon fuel is positioned in an open area on the thin COC film. A resistivity of the conductive metal trace is monitored. A determination is made in response to the monitoring that a change in resistivity of the conductive metal trace has occurred resulting from dissolution of the thin COC film. A time duration is measured from the positioning of the fluid sample to the resistivity change. A concentration of the hydrocarbon fuel in the fluid sample is determined based on the time duration.

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.

Abstract: Techniques for determining a thermal condition of a pipeline include identifying a pipeline that carries a first fluid at a first temperature that includes a tubular conduit that includes a bore that carries the first fluid, and a layer of insulation installed over the tubular conduit; circulating a second fluid at a second temperature from a bypass conduit that is fluidly coupled to the tubular conduit through the layer of insulation into the bore; based on circulating the second fluid into the bore, detecting a thermal gradient between the first fluid carried in the bore and the tubular conduit or the layer of insulation at a particular location of the pipeline; and based on the detected thermal gradient, determining a presence of at least one of water or water vapor between the tubular conduit and the layer of insulation at the particular location of the pipeline.

Abstract: Systems and methods include a computer-implemented method for inspection. Removable sensors are installed on equipment used in hydrocarbon facilities at locations susceptible to high temperature hydrogen attack (HTHA). Attachment uses adaptable hybrid pads. Surface data captured using the sensors includes surface temperatures, per hydrogen (Ph) measurements, and methane measurements for methane escaping from external surfaces of the equipment. A presence of cracks in the equipment base metal is determined. An HTHA susceptibility analysis of the equipment is performed based on the presence of the cracks and by analyzing the surface data and mapping potential HTHA cracks and early signs of methane formation. The steps are repeated on other locations. An inspection result and assessment, generated using the captured surface data, includes a final analysis of assessment reports indicating a likelihood of cracks propagation and a presence of fissuring inside the equipment base metal.

Abstract: A system and methods for detecting aromatic compounds mixed with aliphatic compounds are provided. An exemplary system includes a lower substrate, a polymer film including a resistor mesh disposed on the polymer film, and an upper substrate disposed over the polymer film, wherein the upper substrate includes an opening exposing the resistor mesh.

Abstract: Adhesion devices for transport assemblies are configured to engage non-metallic surfaces. The transport assemblies can be wheels, such as omni-directional wheels, or can be a tractor tread assembly. The transport assembly is configured to move adjacent to a non-metallic surface of a structure. The transport assembly comprises an outer surface disposed adjacent to the non-metallic surface as the transport assembly moves, and a plurality of adhesion devices are each mounted to the outer surface and extend at least in a normal direction away from the outer surface. Each adhesion device is responsive to proximity to the non-metallic surface to adhere to the non-metallic surface. The adhesion devices in one or more embodiments include a Van der Waals-type adhesion device, a micro spine-type adhesion device, a suction cup-type adhesion device, or a combination of such devices.

Abstract: Systems and methods include a computer-implemented method for determining a concentration of hydrocarbon fuel in a fluid sample. A thin Cyclic Olefin Copolymer (COC) film of a COC layer having a honeycomb mesh-pattern forming a conductive metal trace is sputtered. The thin COC film is configured to dissolve upon contact with alkyl aromatic compounds present in hydrocarbon fuels. A fluid sample of a hydrocarbon fuel is positioned in an open area on the thin COC film. A resistivity of the conductive metal trace is monitored. A determination is made in response to the monitoring that a change in resistivity of the conductive metal trace has occurred resulting from dissolution of the thin COC film. A time duration is measured from the positioning of the fluid sample to the resistivity change. A concentration of the hydrocarbon fuel in the fluid sample is determined based on the time duration.

Abstract: Techniques for determining a thermal condition of a pipeline include identifying a pipeline that carries a first fluid at a first temperature that includes a tubular conduit that includes a bore that carries the first fluid, and a layer of insulation installed over the tubular conduit; circulating a second fluid at a second temperature from a bypass conduit that is fluidly coupled to the tubular conduit through the layer of insulation into the bore; based on circulating the second fluid into the bore, detecting a thermal gradient between the first fluid carried in the bore and the tubular conduit or the layer of insulation at a particular location of the pipeline; and based on the detected thermal gradient, determining a presence of at least one of water or water vapor between the tubular conduit and the layer of insulation at the particular location of the pipeline.

Abstract: This application discloses magnetically coupled integrated probes and probe systems, attachable to the robotic arms of a remotely operated vehicle to perform both cathodic protection (CP) voltage measurements and ultrasonic testing (UT) thickness measurements at an underwater surface. The integrated probe system can include a spring for coupling to an ROV end effector. An ultrasonic probe is disposed within and extends from the sleeve housing. A magnetic carrier, flux concentrator, and gimbal surround a portion of the ultrasonic probe, and one or more electrically conductive legs extend from the front surface of the gimbal to function as a CP probe. The legs are arranged about the ultrasonic probe, which has a flexible membrane exposed at the front surface of the gimbal, such that during inspection, at least one leg contacts the surface and the ultrasonic probe is sufficiently proximate to provide substantially simultaneous CP and UT measurements.

Abstract: Techniques for determining a thermal condition of a pipeline include identifying a pipeline that carries a fluid at a steady-state temperature, where the pipeline includes a tubular conduit that includes a bore that carries the fluid, and a layer of insulation installed over an exterior surface of the tubular conduit; changing the steady-state temperature of the fluid by applying a thermal contrast to the pipeline; based on changing the steady-state temperature, detecting a thermal gradient between the fluid carried in the bore and at least one of the tubular conduit or the layer of insulation at a particular location of the pipeline; and based on the detected thermal gradient, determining a presence of at least one of water or water vapor between the exterior surface of the tubular conduit and the layer of insulation at the particular location of the pipeline.

Abstract: A system for determining corrosion under insulation of an industrial asset is provided. The system includes an infrared camera configured to acquire one or more time-series infrared images of an industrial asset. The system further includes a computing device configured to receive data characterizing the one or more time-series infrared images, and to identify an area of interest of the industrial asset within the one or more time-series infrared images. The computing device further configured to identify, by a machine learning algorithm, a plurality of defects within the area of interest based on pixel-wise assignment of at least one defect category selected from a plurality of defect categories associated with corrosion under insulation of the industrial asset, and to provide the plurality of defects within the area of interest of the industrial asset. Related methods, apparatuses, and computer-readable mediums are also provided.

Abstract: This application discloses magnetically coupled integrated probes and probe systems, attachable to the robotic arms of a remotely operated vehicle to perform both cathodic protection (CP) voltage measurements and ultrasonic testing (UT) thickness measurements at an underwater surface. The integrated probe system can include a spring for coupling to an ROV end effector. An ultrasonic probe is disposed within and extends from the sleeve housing. A magnetic carrier, flux concentrator, and gimbal surround a portion of the ultrasonic probe, and one or more electrically conductive legs extend from the front surface of the gimbal to function as a CP probe. The legs are arranged about the ultrasonic probe, which has a flexible membrane exposed at the front surface of the gimbal, such that during inspection, at least one leg contacts the surface and the ultrasonic probe is sufficiently proximate to provide substantially simultaneous CP and UT measurements.

Abstract: Systems and methods include a computer-implemented method for inspection. Removable sensors are installed on equipment used in hydrocarbon facilities at locations susceptible to high temperature hydrogen attack (HTHA). Attachment uses adaptable hybrid pads. Surface data captured using the sensors includes surface temperatures, per hydrogen (Ph) measurements, and methane measurements for methane escaping from external surfaces of the equipment. A presence of cracks in the equipment base metal is determined. An HTHA susceptibility analysis of the equipment is performed based on the presence of the cracks and by analyzing the surface data and mapping potential HTHA cracks and early signs of methane formation. The steps are repeated on other locations. An inspection result and assessment, generated using the captured surface data, includes a final analysis of assessment reports indicating a likelihood of cracks propagation and a presence of fissuring inside the equipment base metal.

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.

Abstract: This application discloses magnetically coupled integrated probes and probe systems, attachable to the robotic arms of a remotely operated vehicle to perform both cathodic protection (CP) voltage measurements and ultrasonic testing (UT) thickness measurements at an underwater surface. The integrated probe system can include a spring for coupling to an ROV end effector. An ultrasonic probe is disposed within and extends from the sleeve housing. A magnetic carrier, flux concentrator, and gimbal surround a portion of the ultrasonic probe, and one or more electrically conductive legs extend from the front surface of the gimbal to function as a CP probe. The legs are arranged about the ultrasonic probe, which has a flexible membrane exposed at the front surface of the gimbal, such that during inspection, at least one leg contacts the surface and the ultrasonic probe is sufficiently proximate to provide substantially simultaneous CP and UT measurements.

Abstract: A system and method for inspecting a surface of a structure for defects includes an inspection apparatus having a heating device for heating a section of the surface of the structure, an infrared camera for receiving infrared radiation from the surface in response to heating, a controller configured to generate thermographs from the received infrared radiation, and a communication device. A training system includes an expert system module configured to determine correlations between a set of thermographs generated by a thermal simulation of modeled structural elements with defects, and parameters of the modeled structural elements. A computer system communicatively coupled to the training system and the inspection apparatus, is adapted to receive thermographs received from the inspection apparatus and to detect quantitative parameters of defects in the structure using the correlations obtained from the training system.

Abstract: Techniques for determining a thermal condition of a pipeline include identifying a pipeline that carries a first fluid at a first temperature that includes a tubular conduit that includes a bore that carries the first fluid, and a layer of insulation installed over the tubular conduit; circulating a second fluid at a second temperature from a bypass conduit that is fluidly coupled to the tubular conduit through the layer of insulation into the bore; based on circulating the second fluid into the bore, detecting a thermal gradient between the first fluid carried in the bore and the tubular conduit or the layer of insulation at a particular location of the pipeline; and based on the detected thermal gradient, determining a presence of at least one of water or water vapor between the tubular conduit and the layer of insulation at the particular location of the pipeline.

Abstract: Techniques for determining a thermal condition of a pipeline include identifying a pipeline that carries a fluid at a steady-state temperature, where the pipeline includes a tubular conduit that includes a bore that carries the fluid, and a layer of insulation installed over an exterior surface of the tubular conduit; changing the steady-state temperature of the fluid by applying a thermal contrast to the pipeline; based on changing the steady-state temperature, detecting a thermal gradient between the fluid carried in the bore and at least one of the tubular conduit or the layer of insulation at a particular location of the pipeline; and based on the detected thermal gradient, determining a presence of at least one of water or water vapor between the exterior surface of the tubular conduit and the layer of insulation at the particular location of the pipeline.

Abstract: Disclosed is a methodology for determination and prediction of heat exchanger fouling, such as polymer fouling in the circulation loop that forms part of the heat exchanger system. The buildup of a polymer or other undesired material deposit in the heat exchanger provides a distinctive temperature signature (thermal gradient) on the surface of the heat exchanger asset, which is visualized using a thermographic camera. Coupling images (thermograms) from the camera with a machine learning algorithm identifies fouling and, with knowledge of the historical data of the asset and operating and ambient conditions, enables prediction of future fouling. The thermal images provide several types, or orders, of temperature information that are indicative of locations vulnerable to fouling. In one case, the method uses machine learning applied to time-based temperature change/gradient information to detect hidden polymer fouling in areas that form part of the heat exchanger asset.

Abstract: A technological solution for analyzing a sequence of electromagnetic spectrum image frames of a nonmetallic asset and detecting or predicting an aberration in the asset, including a detected or predicted location of the aberration.