Schlumberger Technology Corporation

Cameron International Corporation

Evgeny Borisovich Barmatov

Trevor Lloyd Hughes

Jill F Geddes

Bruno Drochon

Michael J Fuller

Sergey Makarychev-Mikhailov

Lynne Patricia Crawford

Dimitri M Khramov

Man Yi Ho

Paul Barnes

Tore Nordvik

Joseph P Varkey

Dean Michael Willberg

Nitin Y Vaidya

Vadim Protasov

Paul Wanjau

Matthew Miller

Konstantin Mikhailovich Lyapunov

Dmitry Eskin

Bruce Alexander Mackay

Dmitry Isaakovich Eskin

Denis Vsevolodovich Ivanov

Alexander Victorovich Golovin

Michaela Nagl-Vogel

Konstantin Mikhaylovich Lyapunov

Improved emulsifier for synthetic-based mud, process for preparation, and drilling method. The emulsifier has the formula (II) wherein each Ris a Cto Calkyl; R, R, R, and Rare each independently selected from H, Cto Calkyl, Cto Calkoxyalkyl, and Cto Chydroxyalkyl; n and m are independently integers from 1 to 10; and y is an integer from 1 to 5. It is prepared by reacting a polyalkyleneamine with a monocarboxylic acid to form a first reaction product, reacting the first reaction product with a dicarboxylic acid to form a second reaction product, and heat treating the second reaction product to form an isomer. The drilling fluid contains the emulsifier, an oleaginous phase, and a non-oleaginous phase, and during use is circulated in a wellbore.

Emulsifier for synthetic-based mud, process for preparation, and drilling method

A method of forming a fluid loss material for a wellbore fluid includes mixing tannin at least one modifier to form a mixture, heating the mixture to a temperature greater than about 100° C. to react the tannin with the at least one modifier to form a modified tannin, and reacting the modified tannin with an amine to form an organophilic fluid loss material comprising the amine bonded to the modified tannin. Related organophilic fluid loss materials and methods of operating a wellbore are also disclosed.

Methods of forming organophilic fluid loss materials, and related organophilic fluid loss materials and methods

Compositions may include a corrosion inhibitor including a heterocyclic diamine prepared from the reaction of an alkyl diamine and an aldehyde, wherein the alkyl diamine has the general formula: R4NH(CH)NHR5, where n is an integer between 3 and 6, and R4 and R5 are independently hydrogen or a C2-C30 saturated or unsaturated hydrocarbon radical. Methods may include contacting a metal surface with a corrosion inhibitor composition, wherein the corrosion inhibitor includes a heterocyclic diamine corrosion inhibitor from the reaction of an alkyl diamine and an aldehyde, wherein the alkyl diamine has the general formula: R4NH(CH)NHR5, where n is an integer between 3 and 6, and R4 and R5 are independently hydrogen or a C2-C30 saturated or unsaturated hydrocarbon radical.

Corrosion inhibitor with improved performance at high temperatures

A method for measuring average thickness of a metal or alloy coating on a metal or alloy substrate using an X-ray fluorescence (XRF) spectrometer is used when the coating has an uneven surface at different distances from a measurement window of the XRF spectrometer. The method includes measuring elemental composition of the coating or substrate using the XRF spectrometer and obtaining the average thickness of the coating using a calibration relationship between coating thickness and elemental composition of the coating or substrate. The metal or alloy coating may be a metal or alloy coating of a plurality of outer armor wires wrapped around a cable. The method may be used to analyze coating thickness changes over time or along the length of the cable, or to analyze a corrosive environment in order to choose optimal material for a metal or alloy coating.

Measurement of metal or alloy coating

A method for measuring a thickness of a deposit layer on a metal or alloy substrate using an X-ray fluorescence (XRF) spectrometer, where the deposit layer includes scale deposits or corrosion products. As part of the method, an elemental composition of the deposit layer or the metal or alloy substrate is measured using the XRF spectrometer. The thickness of the deposit layer is obtained from the elemental composition using a calibration relationship between deposit layer thicknesses and corresponding elemental compositions of the deposit layer or the metal/alloy substrate. The method can be applied to determine the rate of deposit layer formation and evaluate the effectiveness of a treatment.

Measurement of thickness of scale or corrosion

Drilling fluid compositions include an emulsifier having a generic structure A, structure B, or a combination thereof. Structure A includes an amide (e.g., amic acid group) and structure B includes a cyclic imide. The emulsifier of the emulsifier system is formed by reacting a fatty oil amine (e.g., oleyl amine), with a cyclic anhydride (e.g., succinic anhydride) in the absence of diluent or in a diluent that does not react with the starting materials. The reaction takes place via application of a stepwise increase in temperature. An emulsifier based on structure A is formed when the reaction temperature is maintained at 50 to 100&#xb0; C. for 1 to 3 hours. A further increase in reaction temperature (e.g., up to 200&#xb0; C.) can include water elimination which results predominately in the formation of a molecule represented by structure B.

Amide emulsifier for high-temperature oil-based drilling fluid

An aqueous acid composition that may be used, for example, in a matrix acidizing treatment can include an acid, a polymeric acid corrosion inhibitor, and an acid corrosion inhibitor intensifier. The acid corrosion inhibitor can include iodide ions and metal ions, with the metal ions being one or more of copper, silver, bismuth, or antimony. The molar ratio of metal ions to iodide ions can be 1:X, where X is greater than or equal to 2. The polymer of the polymeric acid corrosion inhibitor can have a molecular weight less than 100,000 g/mol.

Aqueous acidic compositions with a corrosion inhibitor

A corrosion inhibiting compound with a general structure A-B or A-X-B for inhibition of corrosion of steel in acidic solution. A comprises a heterocyclic ring system having a plurality of cyclic Carbon atoms and at least one cyclic Nitrogen atom, wherein the at least one cyclic Nitrogen atom is neutral under neutral conditions and protonatable under acidic conditions. B comprises at least two unsaturated Carbon atoms. B may comprise a ring system or a polymerisable group.

Corrosion inhibition

A method is provided for characterizing fluid flow in a pipe where the fluid includes a drag reducing polymer of a particular type and particular concentration. A computational model is configured to model flow of a fluid in a pipe. The computational model utilizes an empirical parameter for a drag reducing polymer of the particular type and the particular concentration. The computational model can be used to derive information that characterizes the flow of the fluid in the pipe. The empirical parameter for the particular type and the particular concentration of the drag reducing polymer can be identified by solving another computational model that is configured to model turbulent Couette flow in a Couette device for a fluid that includes a drag reducing polymer of the particular type and the particular concentration. The empirical data needed for identification of the empirical parameter are obtained from Couette device experiments.

Characterization of fluids with drag reducing additives in a couette device

A method of inhibiting corrosion of duplex stainless steel by aqueous acidic solution, comprises carrying out a preliminary treatment which is passivation of the steel while exposing the steel to a first aqueous acidic solution containing at least one organic corrosion inhibitor able to adsorb to a steel surface, so as to deposit a passivating and corrosion inhibiting film on the steel surface; and thereafter during a second period of time exposing the steel to a second aqueous acidic solution different from the first aqueous acidic solution and also containing at least one organic corrosion inhibitor able to adsorb to a steel. The second aqueous acidic solution maintains the film on the steel surface, such that weight loss through corrosion in the second period of time is lower than the weight loss which would be observed with the same second aqueous acidic solution but without carrying out the preliminary treatment.

A method of inhibiting corrosion of metal which will be in contact with aqueous, and possibly acidic, solution comprises contacting the metal with a corrosion inhibiting composition containing more than 30% by weight of one or more organic corrosion inhibiting constituents which are water-insoluble hydrophobic material, and a corrosion inhibitor which contains one or more polymerisable groups containing double or triple bonded carbon, before contacting the metal with the aqueous solution. The method may be used to protect coiled tubing used for matrix acidizing of an oil well by propelling a slug of the corrosion inhibiting composition along the coiled tubing before pumping acid through the tubing.

A corrosion inhibiting composition which is a liquid carrier in which is dissolved or dispersed a corrosion inhibitor compound comprising at least one moiety (A) which is an aliphatic, aromatic or mixed aliphatic/aromatic structure containing one or more hetero atoms which are nitrogen, oxygen, phosphorus or sulphur, and also at least one moiety (B) which contains one or more polymerisable groups containing double or triple bonded carbon, with the moieties (A) and (B) directly or indirectly covalently connected together.

Corrosion of steel by aqueous acidic solution when treating a wellbore with acid is inhibited by a procedure in which the steel is initially exposed to a first aqueous solution containing one or more corrosion inhibiting constituents which provide both corrosion inhibitor and hydrophobic liquid and deposit a corrosion inhibiting film on the steel surface and then exposed to an acidic second aqueous solution containing one or more such corrosion inhibiting constituents at a lower concentration. During this second period, the lower concentration of corrosion inhibiting constituents in the second aqueous solution maintains the film already established on the steel surface. Weight loss through corrosion in the second stage is lower than the weight loss which otherwise would be observed. Overall there can be reduction of both weight loss and consumption of corrosion inhibitor.

A wire includes a ferrous core. The ferrous core can be coated. The coatings can include nickel, molybdenum, zinc and Fe. A process of forming a wire can include placing a metal strip alongside a ferrous wire core, bending the strip around the core, and seam welding the strip to form a metal tube around the core. The process of forming a wire can include applying a metal layer to a ferrous metal rod to form a plated rod, placing a metal strip alongside the rod, bending the strip around the rod, and seam welding the strip to form a metal tube around the rod. The process of forming a wire can include coating a ferrous wire core with a layer of nickel, molybdenum or a nickel alloy that circumferentially surrounds the ferrous wire core.

Growing community of inventors

Cambridge, United Kingdom

Evgeny Borisovich Barmatov