Abstract: The invention relates to a copolymer having: A) at least one monomer unit a) derived from at least one ethylenically unsaturated aliphatic monocarboxylic or polycarboxylic acid, a corresponding anhydride, or a corresponding water-soluble salt; B) at least one monomer unit b) derived from a particular sulfonated or sulfated ethylenically unsaturated ether or at least one monomer unit (b?) derived from a sulfonated ethylenically unsaturated monomer other than (b), C) at least one monomer unit (c) derived from a monomer with the average general formula [CH2?CH—CH2—R6—O—]xP(?O)(OM)3-x. The invention also relates to a method for preparing such a copolymer, an inhibitor composition including such a copolymer, and a method for inhibiting inorganic deposits in a petroleum reservoir by means of said inhibitor composition.

Abstract: The invention relates to a copolymer having: A) at least one monomer unit a) derived from at least one ethylenically unsaturated aliphatic monocarboxylic or polycarboxylic acid, a corresponding anhydride, or a corresponding water-soluble salt; B) at least one monomer unit b) derived from a particular sulfonated or sulfated ethylenically unsaturated ether or at least one monomer unit (b?) derived from a sulfonated ethylenically unsaturated monomer other than (b), C) at least one monomer unit (c) derived from a monomer with the average general formula [CH2?CH—CH2—R6—O—]xP(?O)(OM)3-x. The invention also relates to a method for preparing such a copolymer, an inhibitor composition including such a copolymer, and a method for inhibiting inorganic deposits in a petroleum reservoir by means of said inhibitor composition.

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: Method of treating the area surrounding an acid gas storage well (1) using a reactive solution, wherein the following stages are carried out: a) injecting from the well a wash fluid for washing the rock of said surrounding area so that it no longer contains products reactive with said solution, b) injecting into the rock thus washed a predetermined volume of reactive solution suited to react with acid gases.

Abstract: A method for estimating the quantity of CO2 present in a geologic formation and a device for implementing the method include the steps of penetrating the formation by a well drilled from the surface contacting formation with a fluid that travels from the formation to the surface sampling a given quantity of return fluid at the surface and transferring it to a cell, ensuring the pH of the quantity of fluid, adding a given quantity of product acidifying the fluid to adjust the pH to a value of less than 4, and measuring the CO2 level of the gas in the cell after the acidification step.

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 well drilling method comprises removing the drilling cuttings using an aqueous drilling fluid such as a foam including a foaming agent which includes at least one mono-(aliphatic hydrocarbyl) phosphate ester. More specifically, the drilling fluid takes the form of a potassium and/or alkanolamine and/or alkylalkanolamine salt, the foam also comprising a foam stabiliser.

Abstract: The invention relates to a well drilling method consisting in removing the drilling cuttings using an aqueous drilling fluid such as a foam including a foaming agent which is, or includes, at least one mono-(aliphatic hydrocarbyl) phosphate ester. More specifically, the drilling fluid takes the form of a potassium and/or alkanolamine and/or alkylalkanolamine salt, said foam also comprising a foam stabiliser.

Abstract: A method providing real-time determination of a thermal profile of the drilling fluid in a well from three measuring points available in the field, i.e. the injection temperature, the outlet temperature and the bottomhole temperature is disclosed. The form of the profile between these three points is defined by a type curve representative of the thermal profiles in a well under drilling, estimated from physical considerations on thermal transfers in the well.

Abstract: The invention relates to a method for estimating the quantity of CO2 present in a geologic formation (20) comprising the following steps:

Abstract: The present invention relates to a method and to a system for monitoring the evolution of the characteristics of a fluid circulating in a well (1) for example, wherein complex dynamic viscosity measurements are performed with a suitable detector (6) arranged on a line (5) through which said fluid circulates, so as to obtain a law of variation of the complex dynamic viscosity &eegr;* as a function of 2&pgr;f; a rheogram of the fluid, i.e. a law of variation of the viscosity &eegr; as a function of the shear ({dot over (&ggr;)}), is deduced therefrom; Va, Vp and YV are calculated from the rheogram; these stages are repeated after a predetermined time interval; the evolution of the characteristics of the fluid is deduced from these measurements.

Abstract: Method of determining the gas hydrate formation conditions in a well fluid, comprising the following stages: taking a fluid sample, placing this sample in a calorimetry cell, performing on this sample a reference thermogram in a temperature range between T1 and T2, performing on the same sample a second thermogram in the same range and under a pressure Ph of a hydrocarbon gas, T1 being a temperature low enough to obtain the formation of hydrates in the sample at a gas pressure Ph, T2 being high enough to obtain hydrate dissociation, identifying a peak in the second thermogram corresponding to the hydrates dissociation zone and deducting therefrom a hydrates dissociation temperature.

Abstract: The present invention relates to a method and to a system for monitoring the evolution of the characteristics of a fluid circulating in a well (1) for example, wherein complex dynamic viscosity measurements are performed with a suitable detector (6) arranged on a line (5) through which said fluid circulates, so as to obtain a law of variation of the complex dynamic viscosity &eegr;* as a function of 2&pgr;f; a rheogram of the fluid, i.e. a law of variation of the viscosity &eegr; as a function of the shear ({dot over (&ggr;)}), is deduced therefrom; Va, Vp and YV are calculated from the rheogram; these stages are repeated after a predetermined time interval; the evolution of the characteristics of the fluid is deduced from these measurements.

Abstract: Method of determining the gas hydrate formation conditions in a well fluid, comprising the following stages: