Abstract: A device for detection of a BTEX component in a liquid or gaseous phase including a sensor for producing a signal representative of the detection of the BTEX component. The sensor includes a layer of a material intended to be in physical contact with the phase, the material comprising a polymer having substituted benzyl group which is repeated more than ten times. The benzyl group comprising fluorine atoms and, at most, two other components selected among hydrogen, halogen atoms, and C1 to C2 alkyl groups.

Abstract: Method for purifying a composition comprising a plastic liquefaction oil, comprising: a) providing a composition comprising a plastic liquefaction oil containing at least 20 ppm by mass of heteroatoms, b) putting said composition in contact with an aqueous medium with a pH above 7, the putting in contact being implemented in turbulent regime having a Reynolds number higher than 2000 and at a temperature of less than or equal to 250° C. to obtain an effluent containing the modified composition, c) subjecting the effluent from step (b) to (c1) a washing in the presence of water or of a solvent that is not miscible with the purified composition, (c2) a separation, or to the succession of steps (c2) and (c1), and obtaining a purified composition having a reduced heteroatom content, and a phase containing the basic compound containing the basic com-pound and heteroatoms initially contained in the modified composition.

Abstract: Disclosed is a method for determining a seismic-to-well tie for a plurality of wells comprised within a reservoir zone. The method comprises generating a first candidate population of well locations for each of said plurality of wells and using a trained neural network to invert seismic data relating to said reservoir zone in accordance with said candidate population of well locations, to obtain inversion well data. The inversion well data is evaluated by comparing said inversion well data to validation well data relating to the reservoir zone. An evolutionary algorithm is applied to said candidate population of well locations to obtain an updated candidate population of well locations. A further training said trained neural network is performed in accordance with said updated candidate population of well locations, and the steps iteratively repeated until at least one stopping criterion is reached.

Abstract: The process comprises defining, a primary transmissivity graph of cells of the geocellular model, the cells forming nodes of the primary transmissivity graph, each edge between cells having a transmissivity calculated from the fluid properties without consideration of transmissivity multipliers, and a transmissivity multiplier; expanding the primary transmissivity graph to split each edge between two original nodes displaying a transmissivity multiplier whose value is smaller than 1 by adding an additional node having a zero volume and a position centered at mid distance from the original nodes; calculating at least one geophysical property for each cell, using the expanded transmissivity graph; positioning or predicting flow in at least a well in the field using the calculated at least one geophysical property of the cells.

Abstract: Provided in the disclosure is a method for determining a wind feature above a body of water, the method including the following phases: A phase of building a training database including the following steps, collecting synthetic aperture radar data, collecting, for each SAR data, a wind speed for the corresponding body of water at the time of acquisition of the SAR data, applying a processing treatment, called averaging treatment, on the SAR images of each SAR data, so as to obtain averaged data for each SAR data, building the training database by associating the collected wind speed and the averaged data of each SAR data, a phase of training a determination model on the basis of the training database, and a phase of operating the trained determination model.

Abstract: The invention concerns a hydrocarbon fluid comprising 75 to 95% by weight of isoparaffins and less than 500 ppm by weight of aromatics relative to the total weight of the hydrocarbon fluid, said fluid having an initial boiling point and a final boiling point in the range of 120 to 240° C. and a flash point lower than 90° C. The invention also concerns the use of the hydrocarbon fluid of the invention as solvent, for example in a paint, material coating, material treatment, sealant, polymerization, aerosol, cleaning or water treatment composition.

Abstract: A lubricant composition includes at least one base oil and at least one additive having the formula (I): wherein R and R1 are selected independently of each other from among: a hydrogen atom; or linear or branched, saturated or unsaturated hydrocarbon groups, containing from 8 to 40 carbon atoms; with at least one radical from among R and R1 being a hydrocarbon group containing at least two ethoxylated and/or propoxylated units.

Abstract: In various aspects, the present disclosure provides an example autonomous microsystem for immersion into a fluid. The autonomous microsystem includes electronics, a power source, and a packaging system that surrounds the electronics and the power source. The electronics can be configured to sense and record one or more environmental conditions. The packaging system may include a deformable shell that defines an internal space and a plurality of filler particles disposed in the internal space and configured to control a density of the autonomous microsystem in relation to the fluid. The filler particles may comprise a low-density material having a bulk density greater than or equal to about 100 kg/m3 and less than or equal to about 1,000 kg/m3 and have a packing density greater than or equal to about 1011/m3 and less than or equal to about 1021/m3.

Abstract: The disclosure relates to method for optimizing a hybrid system for green H2 and/or H2 derivative production and/or conversion. The method comprises providing constraints, which include one or more constraints each related to a H2 demand over a predetermined time period, and/or one or more constraints related to technologies of the hybrid system that are involved in the green H2 and/or H2 derivative production and/or conversion. The method comprises providing an objective function quantifying a rate of the green H2 and/or H2 derivative production and/or conversion by only renewable technologies of the system. The method comprises optimizing the objective function based on the constraints, the optimization using a MILP optimization method based on a linear formulation of the constraints and having free variables including a green H2 and/or H2 derivative production capacity of an electrolyzer of the system and operational variables for mass and power exchanges between the system technologies.

Abstract: The present invention relates to a method for characterizing a zone of land, referred to as the target zone, intended for the installation of photovoltaic panels, the method comprising: receiving a bird's eye image of a target zone, detecting, in the image, a shadow cast over the target zone originating from an obstacle, determining a dimension, referred to as the main dimension, of the detected cast shadow, determining the position of the sun during the acquisition of the image on the basis of characteristics relating to the image, determining the height of the obstacle on the basis of the main dimension and the determined position of the sun, and characterizing the target zone on the basis of the height determined for the obstacle.

Abstract: The invention concerns the use of a hydroxide having the formula XOH, wherein X is Na or K, in a bituminous composition including bitumen modified by a crosslinked elastomer which is a crosslinked vinyl aromatic hydrocarbon and conjugated diene copolymer, having a vinyl aromatic hydrocarbon content representing less than 30% by weight of the weight of the crosslinked elastomer, for improving the effect of the crosslinked elastomer on the elastic properties of the bituminous composition.

Abstract: The device includes a first X-ray source, configured to illuminating a measurement cell with a first beam of X photons; a first detector, placed opposite the first X-ray source along a first illumination axis; a second X-ray source, configured to illuminating the measurement cell with a second beam of X photons simultaneously with the first X-ray source; a second detector, placed opposite the second X-ray source along a second illumination axis; and a tray carrying the first X-ray source, the first detector, the second X-ray source, and the second detector, the tray being rotatable around the cell axis.

Abstract: A method for determining the production-based availability of a wind farm includes: determining a time series comprising at least an expected production for each wind turbine and a total expected production for the entire wind farm at each timestep of a given time period. The expected productions take into account systematic losses relative to each wind turbine. The method further includes determining a total delivered production for the entire windfarm on the basis of the expected production of each wind turbine at each timestep and a determined availability of each wind turbine at each timestep of the time series, and determining the production-based availability of the entire wind farm at each timestep on the basis of the total expected production and of the total delivered production.

Abstract: The present invention relates to a process for the non-oxidative conversion of saturated C1+ hydrocarbons into unsaturated C2+ hydrocarbons and hydrogen in the presence of an unsupported carbon-based catalyst having a carbon content of at least 90.0 wt % and a metal concentration which is less than 0.3 wt %; with wt % expressed based on the total weight of said carbon-based catalyst. The present invention also provides a process for producing a graphite derivative. Further provided are a graphite derivative, and uses thereof, and systems for carrying out the processes of the invention.

Abstract: A water treatment assembly includes a water treatment system including at least one ventilation device for ventilating water treated in the water treatment system, a compressed air system for producing and storing compressed air, the compressed air system being configured for feeding compressed air to the ventilation device and/or to an electrical power unit configured for producing electrical energy from compressed air, and an electrical power system configured for producing electrical power with using at least one renewable energy source and for feeding the water treatment system and the compressed air system with electrical power. The water treatment assembly includes a heat management system configured for transferring heat from the electrical power system, the electrical power unit and/or the compressed air system to the water treatment system.

Abstract: A seismic data processing method comprises transforming an at least one common receiver gather in the time-offset domain to obtain a grid in a frequency-wavenumber domain; calculating and applying a Doppler correction filter value at each point of the grid in the frequency-wavenumber domain; inverse transforming the grid in the frequency-wavenumber domain to the time-offset domain to obtain a Doppler corrected common receiver gather; and processing the corrected Doppler common receiver gather to obtain at least a representation or/and a measurement of at least a ground feature using the Doppler corrected common receiver gather. The method may further include calculating and applying a Doppler correction filter value by determining an instantaneous frequency function of at least one of the sweeps emitted by the source, inverting the instantaneous frequency function to obtain an inverse frequency function, and calculating the Doppler correction filter value from the inverse frequency function.

Abstract: A method for training a solar irradiance forecasting model for an area of interest, the method includes collecting a training database comprising, for each sub-period of a past period of time, solar irradiance measurements of the area of interest, determining, for each sub-period, a forecast of the solar irradiance on the basis of a baseline forecast model and of the solar irradiance measurements for said sub-period, determining, for each sub-period, an error metric, called variability, identifying the sub-periods, called more informative sub-periods, whose variability is above a predetermined variability threshold, compiling a refined training database on the basis of the solar irradiance measurements of the more informative sub-periods, and training the solar irradiance forecasting model on the basis of the refined training database.

Abstract: A method for determining the locations of flow entities for operating a reservoir includes receiving a geological description of the reservoir, and building a geographical graph comprising nodes and edges between nodes. Each node represents a flow entity location and is assigned geographic coordinates, and each edge represents relationships between adjacent nodes and is assigned a value of at least one edge property derived from the geological description of the reservoir. A deformation process on the geological graph is implemented by defining a geological quantity over the geological graph, being function of the spacing between the nodes and of the edge property assigned to the edges of the graph, starting from initial coordinates of the nodes, adjusting the locations of the nodes based on the defined geological function, and outputting the adjusted flow entities locations as determined locations for operating the reservoir.

Abstract: A lubricant composition includes at least one base oil; at least one additive having the formula (I): wherein R and R1 are selected independently of each other from among a hydrogen atom; or saturated or unsaturated, linear hydrocarbon groups containing from 8 to 20 carbon atoms; with at least one of the two radicals R or R1 being a saturated or unsaturated, linear hydrocarbon group containing from 8 to 20 carbon atoms.

Abstract: Provided herein is method for transferring fluid between a first offshore assembly located in a body of water and an assembly floating on the body of water, associated assembly and facility. The method includes the following steps: installing and mechanical tensioning of a plurality of mooring lines between the offshore assembly and the floating assembly, each mooring line having an active length under mechanical tension between a first point and a second point; fluidic connection between a first capacity and a second capacity via a fluid transfer system, and transfer of fluid between the first capacity and the second capacity; continuous measurement of the mechanical tension applied to the active length of at least one mooring line; and control of the active length of the at least one mooring line by a controller, to keep the mechanical tension applied to the at least one mooring line within a preset mechanical tension interval.