Abstract: The present invention relates to a device (1) for measuring the oxidation stability and/or the thermal stability of any type of fuel, including diesel fuel, by miniaturization of the test system by use of a microfluidic technique. The physical phenomena to which fuels are subjected are reproduced by the microchannels (12) of the microfluidic chip (7), which comprise a representation of at least one of the fuel injection and the fuel circulation for a drive system, an internal-combustion engine or an aircraft reactor for example.

Abstract: The present invention describes a fluid which is suitable for the decontamination of heat engines which can carry out, at the same time, both the catalytic reduction of oxides of nitrogen (NOx) contained in exhaust gases and assist in the regeneration of the particulate filter (PF). The invention also describes several embodiments of said fluid consisting of producing an oil-in-water type emulsion.

Abstract: The present invention relates to a device (1) for measuring the oxidation stability and/or the thermal stability of any type of fuel, including diesel fuel, by miniaturization of the test system by use of a microfluidic technique. The physical phenomena to which fuels are subjected are reproduced by the microchannels (12) of the microfluidic chip (7), which comprise a representation of at least one of the fuel injection and the fuel circulation for a drive system, an internal-combustion engine or an aircraft reactor for example.

Abstract: The present invention describes a fluid which is suitable for the decontamination of heat engines which can carry out, at the same time, both the catalytic reduction of oxides of nitrogen (NOx) contained in exhaust gases and assist in the regeneration of the particulate filter (PF). The invention also describes several embodiments of said fluid consisting of producing an oil-in-water type emulsion.

Abstract: The present invention concerns spheroidal alumina particles characterized by a BET specific surface area in the range 150 to 300 m2/g, a mean particle diameter in the range 1.2 to 3 mm and a particle diameter dispersion, expressed as the standard deviation, not exceeding 0.1, a total pore volume, measured by mercury porosimetry, in the range 0.50 to 0.85 mL/g, a degree of macroporosity within a particle of less than 30%, and in which the dispersion of the diameters of the macropores, expressed as the ratio D90/D50, does not exceed 8. The invention also concerns processes for the preparation of said particles as well as catalysts comprising said particles as a support, and their use in catalytic hydrocarbon treatment processes, in particular in a catalytic reforming process.

Abstract: The present invention concerns spheroidal alumina particles characterized by a BET specific surface area in the range 150 to 300 m2/g, a mean particle diameter in the range 1.2 to 3 mm and a particle diameter dispersion, expressed as the standard deviation, not exceeding 0.1, a total pore volume, measured by mercury porosimetry, in the range 0.50 to 0.85 mL/g, a degree of macroporosity within a particle of less than 30%, and in which the dispersion of the diameters of the macropores, expressed as the ratio D90/D50, does not exceed 8. The invention also concerns processes for the preparation of said particles as well as catalysts comprising said particles as a support, and their use in catalytic hydrocarbon treatment processes, in particular in a catalytic reforming process.

Abstract: The invention is a method for selectively removing hydrogen sulfide H2S from a gaseous effluent comprising at least H2S and CO2. A stage of selective absorption of the hydrogen sulfide in relation to the CO2 is carried out by contacting the effluent with a solution comprising (a) water and (b) at least one nitrogen compound. The compound comprises at least one tertiary amine function or one hindered secondary amine function. The absorption selectivity is controlled by adding (c) a viscosifying compound to the absorbent solution.

Abstract: The invention concerns a treatment fluid for wells drilled in oil mud in the form of an emulsion of water in oil comprising: a continuous organic phase comprising at least one emulsion-breaking organo-soluble additive; a dispersed aqueous phase including at least one solid-dissolving agent for the controlled destabilization of the processing fluid; at least one emulsifying agent; at least one weight-increasing agent; the proportion and the nature of the hydrosoluble additive being chosen so as to obtain a delay effect for the destabilization of the emulsion so as to be compatible with the tank fluids. The invention also concerns a method of processing wells bored with oil-based muds, using said processing fluid.

Abstract: The present invention relates to a method for determining the kinetics of gas hydrate formation in a fluid comprising water, wherein the following stages are carried out: a sample of the fluid is provided in form of a water-in-oil stable emulsion, DSC measurements are performed on the sample to obtain at least one peak corresponding to the gas hydrate conversion energy in the water drops of said emulsion, kinetic characteristics of the formation of hydrates in said fluid are deduced from the peak.

Abstract: In order to transport hydrates in suspension in a fluid comprising water, gas and a liquid hydrocarbon, at least one non-polluting composition consisting essentially of a mixture comprising at least one ester associated with a non-ionic co-surfactant of the polymerized (dimer and/or trimer) carboxylic acid type is incorporated into said fluid. The composition is generally introduced in a concentration of 0.1% to 5% by weight with respect to the liquid hydrocarbon.

Abstract: In order to determine the gas hydrate anti-agglomeration power of a system composed of an aqueous phase dispersed in a liquid hydrocarbon phase in the presence of a gas, at least two successive cycles of hydrate formation and dissociation is carried out by cooling and reheating a sample of said system placed in the cell of a calorimeter to record thermograms; the anti-agglomeration power of said system is determined by comparing the thermograms obtained during the various cycles.

Abstract: The present invention relates to an additive that inhibits formation of gas hydrates for water-based drilling fluid, the additive having at least the following constituents (weight percent): a mixture A of glycerol derivatives having 10 to 55% monoglycerol, 15 to 32% diglycerol, and 5 to 12% triglycerol; 0 to 10% of at least one carboxylic acid salt, 0 to 45% of at least one inorganic salt.

Abstract: The present invention relates to a method for determining the kinetics of gas hydrate formation in a fluid comprising water, wherein the following stages are carried out: a sample of the fluid is provided in form of a water-in-oil stable emulsion, DSC measurements are performed on the sample to obtain at least one peak corresponding to the gas hydrate conversion energy in the water drops of said emulsion, kinetic characteristics of the formation of hydrates in said fluid are deduced from the peak.

Abstract: A temperature-stable, non eco-toxic oil-base well fluid that is particularly suitable for high pressure/high temperature drilling comprises an emulsification system comprising at least one superamide that may or may not be polyalkoxylated, optionally associated with a non-ionic co-surfactant. The oil-base well fluid comprising such a system can be used at temperatures of up to about 200° C. due to the production of highly temperature-stable reverse emulsions.

Abstract: An organic based emulsion-breaking formulation for use in treating well bores drilled in oil-bearing mud that is not eco-toxic and is optimally compatible with formation fluids comprises: as the emulsion-breaking agent, at least one constituent selected from non-ionic amphiphilic compositions obtained by reacting at least one polymerized vegetable oil with at least one aminoalcohol and alkyl esters (for example C1 to C8) of fatty acids derived from natural, vegetable or animal oils; optionally, at least one wetting agent selected from anionic surfactants; and optionally at least one solvent; the assembly being as a mixture in an organic base. Such a formulation can be weighted by mineral fillers.

Abstract: The present invention relates to an additive that inhibits formation of gas hydrates for water-based drilling fluid, the additive having at least the following constituents (weight percent): a mixture A of glycerol derivatives having 10 to 55% monoglycerol, 15 to 32% diglycerol, and 5 to 12% triglycerol; 0 to 10% of at least one carboxylic acid salt, 0 to 45% of at least one inorganic salt.

Abstract: An oil-based demulsifying formulation which can be used in the treatment of drains bored in oil-based mud, non ecotoxic and optimally compatible with formation fluids, comprises at least one wetting agent chosen from anionic surfacetants and at least one demulsifier (or “emulsion breaker”) chosen from copolymers of ethylene oxide and propylene oxide, alcohol or phenol derivatives with alkoxylated or polyalkoxylated chain formations, polyalkyleneglycols, polyamines, alkoxylated or polyalkoxylated derivatives of amines, quaternary ammonium salts, quaternized alkanolamine esters, alkyl esters of fatty acids or natural oils, possible alkoxylated or polyalkoxylated, and silicated derivatives such as polysiloxanes.

Abstract: In order to transport hydrates in suspension in a fluid comprising water, gas and a liquid hydrocarbon, at least one non-polluting composition consisting essentially of a mixture comprising at least one ester associated with a non-ionic co-surfactant of the polymerized (dimer and/or trimer) carboxylic acid type is incorporated into said fluid. The composition is generally introduced in a concentration of 0.1% to 5% by weight with respect to the liquid hydrocarbon.

Abstract: In order to determine the gas hydrate anti-agglomeration power of a system composed of an aqueous phase dispersed in a liquid hydrocarbon phase in the presence of a gas, at least two successive cycles of hydrate formation and dissociation is carried out by cooling and reheating a sample of said system placed in the cell of a calorimeter to record thermograms; the anti-agglomeration power of said system is determined by comparing the thermograms obtained during the various cycles.

Abstract: A temperature-stable, non eco-toxic oil-base well fluid that is particularly suitable for high pressure/high temperature drilling comprises an emulsification system comprising at least one superamide that may or may not be polyalkoxylated, optionally associated with a non-ionic co-surfactant. The oil-base well fluid comprising such a system can be used at temperatures of up to about 200° C. due to the production of highly temperature-stable reverse emulsions.