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Небесная энциклопедия

Космические корабли и станции, автоматические КА и методы их проектирования, бортовые комплексы управления, системы и средства жизнеобеспечения, особенности технологии производства ракетно-космических систем

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Мониторинг СМИ

Мониторинг СМИ и социальных сетей. Сканирование интернета, новостных сайтов, специализированных контентных площадок на базе мессенджеров. Гибкие настройки фильтров и первоначальных источников.

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Поддерживает ввод нескольких поисковых фраз (по одной на строку). При поиске обеспечивает поддержку морфологии русского и английского языка
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Применить Всего найдено 28549. Отображено 100.
05-01-2012 дата публикации

Coated particles of a chelating agent

Номер: US20120004147A1
Принадлежит: Akzo Nobel NV

The present invention relates to a coated particle including a particle including at least one chelating agent of the formula COOH—CHX—N—(CH 2 —COOH) 2 , wherein X stands for carboxyalkyl, alkyl, hydroxyalkyl or aminoalkyl, and alkyl is a C1-C4 alkyl group, and the coating on the particle includes at least one scale-inhibiting additive, a process to prepare such particle, and to the use thereof in detergents, in oil field applications, in agriculture and in water treatment.

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26-01-2012 дата публикации

Generation of materials with enhanced hydrogen content from anaerobic microbial consortia including desulfuromonas or clostridia

Номер: US20120021495A1
Автор: Gary Vanzin
Принадлежит: Luca Technologies LLC

An isolated microbial consortia is described. The consortia may include a first-bite microbial consortium that converts a starting hydrocarbon that is a complex hydrocarbon into two or more first-bite metabolic products. The consortia may also include a downstream microbial consortium that converts a starting hydrocarbon metabolic product into a downstream metabolic product. The downstream metabolic product has a greater mol. % hydrogen than the starting hydrocarbon. The first-bite microbial consortium or the downstream microbial consortium includes one or more species of Desulfuromonas.

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09-02-2012 дата публикации

Microbiocide/Sulfide Control Blends

Номер: US20120034313A1
Принадлежит: Baker Hughes Inc

A chemical blend that simultaneously kills bacteria and suppresses the production of hydrogen sulfide (H 2 S) includes both a first chemical, which may be a glutaraldehyde, a tetrakishydroxymethyl phosphonium sulfate (THPS), a quaternary amine compound, a thiocyanate, a carbamate, a cinnamaldehyde, an alkyl dimethyl benzyl ammonium chloride, and/or a diamine diacetate; a second chemical which is a quinone; optionally a third chemical, which is a phosphate compound and a solvent which includes monoethylene glycol. The chemical blend has shown synergistic results for killing bacteria and/or suppressing the production of hydrogen sulfide as compared with the addition of the results of each of the components of the blend used separately.

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23-02-2012 дата публикации

Methods and Compositions for Sand Control in Injection Wells

Номер: US20120043082A1
Принадлежит: Halliburton Energy Services Inc

Methods including the steps of providing an injection well having unconsolidated particulates in one or more formation intervals along the wellbore that accept injection fluid; providing a consolidating treatment fluid comprising a base fluid and a consolidating agent; introducing the consolidating treatment fluid through the injection well, while the well is under injection, such that the consolidating treatment fluid enters into a portion of a formation interval along the wellbore that accepts injection fluid; and, allowing the consolidating fluid to consolidate formation particulates therein. The methods may be performed such that the percentage of consolidating agent varies over the course of the treatment or the rate of injection varies over the course of the treatment.

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08-03-2012 дата публикации

Solvents and compositions for treating hydrocarbon-bearing formations

Номер: US20120055668A1
Принадлежит: 3M Innovative Properties Co

A method of treating a hydrocarbon-bearing formation that includes receiving data comprising a temperature and a brine composition of the hydrocarbon-bearing formation; selecting a treatment composition for the hydrocarbon-bearing formation comprising a fluorinated compound and solvent, wherein, at the temperature, a mixture of an amount of the brine composition and the treatment composition separates into at least two separate transparent liquid layers, and wherein the mixture is free of precipitated solid; and contacting the hydrocarbon-bearing formation with the treatment composition. Compositions containing certain fluorinated polymers and solvents containing water, monohydroxy alcohols, and ketones are also disclosed.

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08-03-2012 дата публикации

Novel formulations of water-soluble polymers and stabilizing additives for injecting a single compound useable in injection fluids for chemical enhanced oil recovery

Номер: US20120058922A1
Принадлежит: SPCM SA

Composition based on anionic polymers or water-soluble amphoteric (co)polymers suitable for viscosifying the injection fluids for oil recovery, characterized in that, before dilution with the injection fluid, it further contains at least 3 stabilizing agents selected from the group comprising oxygen reducing agents, precipitating agents, free radical scavengers, complexing agents and sacrificial agents, the said stabilizing agent being suitable for preventing the chemical degradation of the polymer once the polymer is introduced into the injection fluid.

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15-03-2012 дата публикации

Wellbore fluid and methods of treating an earthen formation

Номер: US20120061083A1
Автор: David Antony Ballard
Принадлежит: MI Drilling Fluids UK Ltd

The present application describes improved compositions for wellbore fluids for use in downhole (e.g. oilwell) applications. The compositions comprise a blocked isocyanate (BI) component having a tolerance improving group (such as a hydrophilic group, e.g. an amine) bonded to it, and an active hydrogen component. When the BI group is unblocked, it reacts with the active hydrogen component to form a gel which, by virtue of the tolerance improving group, is more tolerant to contaminants (such as aqueous inorganic salts or brines) than the corresponding gel forms from unmodified BI. The application also relates to methods of treating an earthen formation using such a composition.

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22-03-2012 дата публикации

Method for the Use of Nitrates and Nitrate Reducing Bacteria In Hydraulic Fracturing

Номер: US20120067566A1
Принадлежит: Multi Chem Group LLC

A slick water fracturing fluid including a brine, an inorganic nitrate, a nitrogen reducing bacteria, a scale inhibitor selected from the group consisting of a polyacrylate polymer, a polyacrylate copolymer, a polyacrylate terpolymer, and mixtures thereof, and a friction reducer, wherein the friction reducer is a polyacrylamide.

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29-03-2012 дата публикации

Polymers Having N-Vinyl Amide And Hydroxyl Moieties, Their Compositions And The Uses Thereof

Номер: US20120077717A1
Автор: Cuiyue Lei, Osama M. Musa
Принадлежит: ISP Investments LLC

The invention relates to polymers derived at least from one: (A) one N-vinyl amide unit, and (B) one hydroxyl-containing acrylate unit, and to polymers derived at least from: (A) N-vinyl-2-caprolactam, and (B) one non-acrylate unit having: (i) at least one hydroxyl group, and/or (ii) at least one functional group convertible to a hydroxyl group wherein at least one group is converted to hydroxyl functionality in the final polymer product. Such polymers may exhibit degradability, e.g., in seawater or soil environments. In preferred embodiments, these polymers and compositions thereof are used in oilfield applications, such as an inhibitor of gas hydrates and/or a kinetic inhibitor of gas hydrates. The polymer can assume alternating, block, and/or random configurations of the repeating units, with at least one ester group. The chemical structure subscripts m, and n may be any integer equal to or greater than 1.

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12-04-2012 дата публикации

Hydrocarbon recovery process

Номер: US20120085555A1

Hydrocarbons are recovered from subterranean formations by waterflooding. The method comprises passing an aqueous displacement fluid via an injection well through a porous and permeable sandstone formation to release oil and recovering said released oil from a production well spaced from said injection well, wherein (a) the sandstone formation comprises at least one mineral having a negative zeta potential under the formation conditions; (b) oil and connate water are present in the pores of the formation; and (c) the fraction of the divalent cation content of the said aqueous displacement fluid to the divalent cation content of said connate water is less than 1.

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26-04-2012 дата публикации

Non-ionic alkali polymer solutions for enhanced oil recovery in a subterranean formation

Номер: US20120097389A1
Принадлежит: Chevron USA Inc

A method for enhancing oil recovery is disclosed. The method includes providing a subsurface reservoir containing hydrocarbons therewithin and a wellbore in fluid communication with the subsurface reservoir. A solution for injection into the reservoir is formed by mixing a composition with at least one non-ionic chemical, at least one polymer, and at least one alkali. The non-ionic chemical can be alcohol alkoxylates such as alkylaryl alkoxy alcohols or alkyl alkoxy alcohols. The solution is solution is clear and aqueous stable when mixed. The solution is injected through the wellbore into the subsurface reservoir.

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03-05-2012 дата публикации

Water removal from anti-agglomerate ldhis

Номер: US20120103422A1
Принадлежит: Multi Chem Group LLC

A method of controlling corrosion in a subsea pipeline is disclosed which includes supplying a low dose inhibitor stream (LDHI) comprised of a quaternary amine and drying with a desiccant.

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10-05-2012 дата публикации

Equipment and method for reinforcing a borehole of a well while drilling

Номер: US20120111578A1
Автор: Steina Wasa Tverlid
Принадлежит: STATOIL ASA

The equipment for drilling and reinforcing a borehole of a well comprises a drill pipe string carrying a drill tool at its lowermost end and a downhole treatment device held on the drill pipe string for applying a liner of polymer material at the surface of the borehole. The polymer material is a fusible and/or curable material dissolved and/or emulsified and/or dispersed in drilling fluid or mud circulated through the drill pipe string and an annulus between the drill pipe string and the wall of the borehole. The treatment device is adapted to concentrate energy for fusing and/or curing the polymer material contained in the drilling fluid in a limited space at the vicinity of the wall of the borehole. The treatment device thus focuses its energy in the vicinity of the wall and allows a continuous reinforcing of the borehole simultaneously while drilling.

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10-05-2012 дата публикации

Polymeric corrosion inhibitors

Номер: US20120114523A1
Принадлежит: Akzo Nobel Chemicals International BV

The present invention relates to the use of a product obtainable by the reaction of an alkoxylated fatty amine having the formula (I) wherein R is a hydrocarbyl group having 8-24 carbon atom; each B is, independently, an alkyl group having 1-4 carbon atoms, a benzyl group, or the group (AO) n H, wherein A is an alkylene group containing 2-4 carbon atoms, preferably 2 carbon atoms; each n is at least 1 and the sum of all n is 2-30; x is 2 or 3; and y is 0-3, preferably 0 or 1; or of a product obtainable by partial or total quaternisation of the alkoxylated fatty amine of formula (I); with a dicarboxylic acid derivative having the formula (IIa) or (IIb) wherein D is —OH, —Cl, or —OR3, wherein R3 is a C1-C4 alkyl group; R2 is an alkylene radical of formula —(CH 2 ) z —, wherein z is an integer from 0 to 10, preferably from 2 to 4, and most preferably 2, and wherein the alkylene radical may be substituted by 1 or 2 —OH groups; the group —CH═CH—, or the o-phenylene group; or by reacting a product (I) with a dicarboxylic acid derivative (IIa) or (IIb), followed by partial or total quaternisation of the reaction product obtained; or by reacting a product (I) with a dicarboxylic acid derivative (IIa) or (IIb), followed by partial or total quaternisation of the reaction product obtained, wherein the product consists to >60% w/w of oligomers/polymers with at least two alkoxylated amine units and one or more diacid/acid anhydride unit and to >50% w/w of oligomers/polymers with at least two alkoxylated amine units and two or more diacid/acid anhydride units; as a corrosion inhibitor for metal surfaces. The invention also relates to a method for protecting a metal surface from corrosion by contacting the metal surface with said corrosion inhibitor.

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17-05-2012 дата публикации

Scale Inhibiting Particulates

Номер: US20120122741A1
Автор: Thomas D. Welton
Принадлежит: Halliburton Energy Services Inc

Scale inhibiting particulates formed from a mixture of fly ash and a phosphonic acid curing agent; wherein the fly ash is cured into a solid material by the contact with the phosphonic acid curing agent. The mixture may also contain a multivalent ion and the particulates may be coated with a coating material in an amount from about 0.1% to about 40% coating material by weight of the scale inhibiting particulate to delay the release of the scale inhibitor.

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24-05-2012 дата публикации

Systems and Methods For Enhanced Waterfloods

Номер: US20120125605A1
Принадлежит: Individual

Methods and systems for enhanced oil recovery from a subterranean formation are provided. An exemplary includes separating fluid produced from the subterranean formation into a first fluid stream that includes an aqueous stream containing multivalent ions. At least a portion of the multivalent ions in the first fluid are removed to form a second fluid stream and the second fluid stream is injected into the subterranean formation. The first fluid stream and the second fluid stream have substantially the same interfacial tension with a hydrocarbon and substantially the same kinematic viscosity, and the second fluid stream has a total concentration of ions greater than about 100,000 ppm.

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24-05-2012 дата публикации

Process for mineral oil production using hydrophobically associating copolymers

Номер: US20120125643A1
Принадлежит: BASF SE

A process for mineral oil production, in which an aqueous formulation comprising at least one water-soluble, hydrophobically associating copolymer is injected through at least one injection borehole into a mineral oil deposit, and crude oil is withdrawn from the deposit through at least one production borehole, wherein the water-soluble, hydrophobically associating copolymer comprises at least acrylamide or derivatives thereof, a monomer having anionic groups and a monomer which can bring about the association of the copolymer, and water-soluble, hydro-phobically associating copolymer which has a low shear degradation and is suitable for execution of the process.

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07-06-2012 дата публикации

Method and system for configuring crude oil displacement system

Номер: US20120143579A1
Принадлежит: BP Exploration Operating Co Ltd

A computer-implemented method for determining one or more operating modes for a crude oil displacement system is provided. The crude oil displacement system is arranged to inject an aqueous displacement fluid into one or more reservoirs, each reservoir comprising a porous and permeable rock formation, wherein crude oil and formation water are contained within a pore space of the rock formation. The crude oil displacement system is for use in displacing crude oil from the pore space of the rock formation. The computer-implemented method comprises the steps of receiving measurement data associated with one or more chemical characteristics of the displacement fluid and one or more chemical characteristics of the rock formation, the crude oil and the formation water of the one or more reservoirs, and inputting the measurement data and data representing a predetermined volume of oil into a computer-implemented predictive model. The predictive model is operated so as to generate predicted data indicative of a predicted additional amount of oil, compared to the predetermined volume of oil, that will be displaced by configuring the crude oil displacement system so as to inject the displacement fluid having the chemical characteristics into the one or more reservoirs. On the basis of the predicted data, the one or more operating modes of the crude oil displacement system are determined. A further computer-implemented method employing the predictive model in which predicted data indicative of one or more predicted chemical characteristics of the displacement fluid are generated is also provided. Additionally, a system for configuring a crude oil displacement system is provided.

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14-06-2012 дата публикации

Acidic Treatment Fluids Containing Non-Polymeric Silica Scale Control Additives and Methods Related Thereto

Номер: US20120145401A1
Автор: Enrique A. Reyes
Принадлежит: Halliburton Energy Services Inc

The present invention relates to treatment fluids and compounds useful in subterranean formations, particularly those that retard deposition of silica scale in subterranean formations. Methods of the present invention comprise providing a treatment fluid having a pH of 6 or less that comprises an acidic base fluid and a non-polymeric silica scale control additive and introducing the treatment fluid into at least a portion of a subterranean formation. The non-polymeric silica scale control additive retards deposition of silica scale in the subterranean formation.

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14-06-2012 дата публикации

Composition and Method For Using Waxy Oil-External Emulsions To Modify Reservoir Permeability Profiles

Номер: US20120149605A1
Принадлежит: ExxonMobil Upstream Research Co

A waxy oil-external emulsion is provided for injection into a selected zone of a subsurface formation. The selected zone is typically a high permeability zone. The emulsion generally comprises oil, added wax, and water. The emulsion may also include an emulsifying agent and a solvent. The emulsion is formulated to be a liquid at a temperature greater than a targeted temperature in the subsurface formation, but a solid at the targeted temperature. The targeted temperature is typically the maximum operating temperature for the formation. A method of formulating the emulsion is also provided. Further, a method of plugging a high permeability zone using the emulsion is disclosed.

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14-06-2012 дата публикации

Corrosion inhibitors for oil and gas applications

Номер: US20120149608A1
Принадлежит: Individual

A corrosion inhibitor composition and method of inhibiting corrosion on a surface in an oil or gas application is disclosed and claimed. The corrosion inhibitor includes at least one fatty acid; at least one alkanolamine; at least one alkylamine; and at least one organic sulfonic acid. The method of inhibiting corrosion includes on a surface in an oil or gas application comprises contacting an effective dosage of the corrosion inhibitor with the surface.

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21-06-2012 дата публикации

Heat generating system for enhancing oil recovery

Номер: US20120152536A1
Принадлежит: Chevron USA Inc

The instant invention pertains to a composition which may be useful for enhancing oil recovery. The composition typically comprises the reaction mixture of at least (a) two or more compounds capable of generating at least about 20 kcal to about 150 kcal per mole when contacted; (b) one or more suitable surfactants or one or more suitable polymers or a mixture thereof; and (c) oil. The invention also pertains to a method for enhancing oil recovery wherein a suitable system is injected through a wellbore into a reservoir to enhance mobility of oil.

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05-07-2012 дата публикации

Weighted Elastomers, Cement Compositions Comprising Weighted Elastomers, and Methods of Use

Номер: US20120172261A1
Принадлежит: Halliburton Energy Services Inc

Methods and compositions are provided that relate to weighted elastomers. The weighted elastomers may comprise an elastomer and a weighting agent attached to an outer surface of the elastomer. An embodiment includes a method of cementing that comprises providing a cement composition containing cement, water, and a weighted elastomer. In addition, the cement composition may be introduced into a subterranean formation and allowed to set therein.

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26-07-2012 дата публикации

Permeability blocking with stimuli-responsive microcomposites

Номер: US20120190593A1
Принадлежит: Soane Energy LLC

Disclosed is a two-component fluid loss control system comprising a core substrate and a polymeric shell cooperating with each other to form a microcomposite, wherein the core substrate and the polymeric shell are formed from different materials. The system can demonstrate switchable behavior. The core substrate and the polymeric shell can be further modified, where modifications cooperate with each other to form the microcomposite. Also disclosed are formulations for fluid loss control and methods for controlling fluid loss in a well.

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16-08-2012 дата публикации

Process for mineral oil production from mineral oil deposits with high deposit temperature

Номер: US20120205099A1
Принадлежит: Wintershall Holding GmbH

A two-stage process for mineral oil production from mineral oil deposits with a deposit temperature of more than 70° C. and a salinity of 20 000 ppm to 350 000 ppm, in which an aqueous formulation comprising at least one glucan with a β-1,3-glycosidically linked main chain, and side groups β-1,6-glycosidcally bonded thereto and having a weight-average molecular weight M w of 1.5*10 6 to 25*10 6 g/mol, are injected into a mineral oil deposit through at least one injection borehole and crude oil is withdrawn from the deposit through at least one production borehole. The aqueous formulation is prepared in two stages, by first preparing an aqueous concentrate of the glucan, and diluting the concentrate on site with water to the use concentration.

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16-08-2012 дата публикации

Well treatment

Номер: US20120208728A1
Принадлежит: STATOIL ASA

The present invention provides a method for inhibiting scale formation within a hydrocarbon producing system (e.g. a subterranean formation), said method comprising contacting said system with a clay mineral, an organosilane and a scale inhibitor.

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23-08-2012 дата публикации

Well Treatment Compositions and Methods Utilizing Nano-Particles

Номер: US20120211227A1
Принадлежит: Halliburton Energy Services Inc

Disclosed embodiments relate to well treatment fluids and methods that utilize nano-particles. Exemplary nano-particles are selected from the group consisting of particulate nano-silica, nano-alumina, nano-zinc oxide, nano-boron, nano-iron oxide, and combinations thereof. Embodiments also relate to methods of cementing that include the use of nano-particles. An exemplary method of cementing comprises introducing a cement composition into a subterranean formation, wherein the cement composition comprises cement, water and a particulate nano-silica. Embodiments also relate to use of nano-particles in drilling fluids, completion fluids, simulation fluids, and well clean-up fluids.

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27-09-2012 дата публикации

Synergistic H2S/Mercaptan Scavengers Using Glyoxal

Номер: US20120241361A1
Принадлежит: Baker Hughes Inc

The use of neutral aqueous solutions of glyoxal (pH approximately 6 to 8.5) scavenges H 2 S that is present in natural gas and in oil better than glyoxal alone or base alone. The resulting scavenger combination significantly increases the reaction rate and the overall scavenging efficiency, i.e. capacity over glyoxal used alone. A buffer may be optionally used. In another embodiment, the combination of non-nitrogen-containing surfactants and glyoxal results in a significant increase in the reaction rate and the overall scavenging efficiency, i.e. capacity as compared to glyoxal used alone.

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27-09-2012 дата публикации

Use of high ratio aqueous alkali silicates for profile modification, water control and stabilization

Номер: US20120245062A1
Автор: Michael J. Mcdonald
Принадлежит: Individual

Soluble silicates are commonly used to block and strengthen permeable zones in subterranean formations. These applications include conformance for oil field, grouting for the construction industry and water shut-off for mining. It was discovered that set times and set properties could be improved by using novel, high ratio alkali silicates. Ratio being defined as the mol ratio of SiO 2 :Me 2 O, where Me is an alkali metal and is most commonly sodium or potassium (i.e. Na 2 O and K 2 O).

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18-10-2012 дата публикации

Methods and Compositions for Controlling Formation Fines and Reducing Proppant Flow-Back

Номер: US20120261126A1
Принадлежит: Halliburton Energy Services Inc

Provided herein are methods for controlling the migration of particulates within a portion of a subterranean formation that comprise aqueous tackifying treatment fluids, curable resin compositions, and/or noncurable resin compositions.

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25-10-2012 дата публикации

Control of Particulate Entrainment by Fluids

Номер: US20120267105A1
Автор: Kewei Zhang
Принадлежит: TRICAN WELL SERVICE LTD

An aqueous slurry composition for use in industries such as petroleum and pipeline industries that includes: a particulate, an aqueous carrier fluid, a chemical compound that renders the particulate surface hydrophobic, and a small amount of an oil. The slurry is produced by rendering the surface of the particulate hydrophobic during or before the making of the slurry. The addition of the oil greatly enhances the aggregation potential of the hydrophobically modified particulates once placed in the well bore.

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06-12-2012 дата публикации

Methods to improve stability of high solid content fluid

Номер: US20120305254A1
Принадлежит: Schlumberger Technology Corp

A method of treating a subterranean formation of a well bore comprises providing a treatment fluid comprising a carrier fluid, a particulate material, a surfactant and micelles, wherein micelles are stabilized by the surfactant and act as particles in the treatment fluid; and introducing the treatment fluid into the wellbore.

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06-12-2012 дата публикации

Generation of hydrogen from hydrocarbon bearing materials

Номер: US20120309070A1
Принадлежит: Luca Technologies LLC

Disclosed are strategies for the economical microbial generation of hydrogen, useful as an alternative energy source, from hydrocarbon-rich deposits such as coal, oil and/or gas formations, oil shale, bitumen, tar sands, carbonaceous shale, peat deposits and sediments rich in organic matter through the management of the metabolism of microbial consortia.

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06-12-2012 дата публикации

Compositions And Methods For Inhibiting Naphthenate Solids Formation From Liquid Hydrocarbons

Номер: US20120310022A1
Принадлежит: MI LLC

The present invention relates to a composition and method for inhibiting the formation of naphthenate solids in a liquid hydrocarbon. The method includes contacting a composition including a rosin amine having a formula (I): or (II): where formula (AA): represents a single or double bond; R1, R2 and R5 each independently represent H, alkyl, alkenyl or an alkynyl group each having between one and ten carbon atoms, —(R3O)nR4 wherein R3 is an alkyl group having 1 to 3 carbon atoms and R4 is H, alkyl, alkenyl or an alkynyl group each having between one and ten carbon atoms; n is an integer between 5 and 50; X is a halide, sulphate, phosphate or acetate ion; and a demulsifier intermediate with the liquid hydrocarbon.

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27-12-2012 дата публикации

Pentane-hexane solvent in situ recovery of heavy oil

Номер: US20120325470A1
Принадлежит: FCCL PARTNERSHIP

An integrated thermal recovery process using a solvent of a pentane or hexane or both as an additive to, or sole component of, a gravity-dominated process for recovering bitumen or heavy oil from a reservoir. A pentane-hexane specific solvent fraction is extracted at surface from a diluent stream. That pentane-hexane solvent fraction is then injected into the reservoir as part of a gravity-dominated recovery process within the reservoir, and when that solvent fraction is subsequently produced as part of the oil or bitumen blend, it is allowed to remain within the blend to enhance the subsequent blend treating and transportation steps. Meanwhile, the remainder of the diluent from which the solvent stream had been extracted is utilized at surface as a blending stream to serve as an aid in treating of produced fluids and also to serve as a means of rendering the bitumen or heavy oil stream pipelineable.

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03-01-2013 дата публикации

Radiation-Induced Triggering for Set-On-Command Compositions and Methods of Use

Номер: US20130000891A1
Принадлежит: Halliburton Energy Services Inc

Methods of isolating a portion of a wellbore comprising placing a sealant composition into a subterranean formation after drilling of the wellbore therein and subjecting the sealant composition to ionizing radiation wherein subjecting the sealant composition to the ionizing radiation alters the set modifier. The sealant composition comprises a set modifier selected from the group consisting of an accelerator, an oxidizing agent, a set retarder, and combinations thereof. And the sealant composition comprises a polymeric component.

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03-01-2013 дата публикации

Solvent injection recovery process

Номер: US20130000894A1
Принадлежит: STATOIL ASA

A process for the recovery of hydrocarbon such as bitumen/EHO from a hydrocarbon bearing formation in which are situated an upper injection well and a lower production well, the method comprising the steps: preheating an area around and between the wells by circulating hot solvent through the completed interval of each of the wells until sufficient hydraulic communication between both wells is achieved; injecting one of more hydrocarbon solvents into the upper injection well at or above critical temperature of the solvent or solvent mixture, thereby causing a mixture of hydrocarbon and solvent to flow by gravity drainage to the lower production well; and producing the hydrocarbon to the surface through the lower production well.

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10-01-2013 дата публикации

In situ recovery from a hydrocarbon containing formation

Номер: US20130008660A1
Принадлежит: Shell Oil Co

An oil shale formation may be treated using an in situ thermal process. Heat may be applied to the formation to raise a temperature of a portion of the formation to a pyrolysis temperature. Heat input into the formation may be controlled to raise the temperature of portion at a selected rate during pyrolysis of hydrocarbons within the formation. A mixture of hydrocarbons, H 2 , and/or other formation fluids may be produced from the formation.

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24-01-2013 дата публикации

Surfactant system to increase hydrocarbon recovery

Номер: US20130020085A1
Принадлежит: ConocoPhillips Co

A post-primary oil recovery process for recovering oil from a subterranean formation may involve injecting into a crude oil-bearing subterranean formation an aqueous saline surfactant composition of brine, Alkyl Polyglucoside, Linear Primary Alcohol Ethoxylate, sodium hydroxide and alcohols; displacing the aqueous composition through the oil-bearing formation and driving oil from the oil-bearing formation; and recovering oil displaced from the subterranean formation. The injecting step may be preceded by the step of injecting into the subterranean formation a volume of salinity water to adjust salinity of connate water within the subterranean reservoir to a predetermined salinity. Injection of the surfactant composition may further be followed by injection of a buffer comprising water dispersible polymeric viscosifier or water soluble polymeric viscosifier. The surfactant composition may additionally contain at least one cosurfactant selected from hydrocarbon sulfonates and alcohols. The aqueous saline surfactant composition may be or include SCHMOO-B-GONE SURFACTANT®.

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31-01-2013 дата публикации

Method of controlling the corrosion rate of alloy particles, alloy particle with controlled corrosion rate, and articles comprising the particle

Номер: US20130029886A1
Принадлежит: Baker Hughes Inc

A composite particle comprises a core, a shielding layer deposited on the core, and further comprising an interlayer region formed at an interface of the shielding layer and the core, the interlayer region having a reactivity less than that of the core, and the shielding layer having a reactivity less than that of the interlayer region, a metallic layer not identical to the shielding layer and deposited on the shielding layer, the metallic layer having a reactivity less than that of the core, and optionally, an adhesion metal layer deposited on the metallic layer.

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28-02-2013 дата публикации

Method of using fracturing fluids containing carboxyalkyl tamarind

Номер: US20130048292A1
Принадлежит: Individual

The production of hydrocarbons from a hydrocarbon bearing formation is enhanced by introduction into the formation an aqueous fluid containing a carboxyalkyl tamarind powder. The fluid may be linear or crosslinked.

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14-03-2013 дата публикации

Alkaline microbial enhanced oil recovery

Номер: US20130062053A1
Принадлежит:

The present invention is related to the field of microbial enhanced oil recovery (MEOR). In particular, the invention concerns new, efficient, economical and environmentally safe microbial methods to enhance oil recovery, as well as microorganisms useful in such methods. 1. A method of enhancing oil recovery comprising(a) inoculating an oil reservoir with a consortium comprising microbes that are obligatory alkaliphilic, halo-alkaliphilic or alkaline tolerant and are deficient in their ability to utilize short chain hydrocarbons of 12 carbons or less but have the ability to convert hydrocarbons into fatty acids,(b) allowing the consortium to proliferate and degrade hydrocarbons of greater than 12 carbons, and(c) obtaining enhanced oil recovery from the oil reservoir.2. The method of wherein step (b) is performed under alkaline conditions.3. The method of claim 1 , wherein said consortium comprises microbes that are naturally alkaliphilic claim 1 , halo-alkaliphilic or alkaline tolerant.4. The method of claim 1 , wherein said consortium comprises microbes that are engineered to be alkaliphilic claim 1 , halo-alkaliphilic or alkaline tolerant.54. The method of claim 1 , claim 1 , claim 1 , or claim 1 , wherein said consortium comprises microbes that are naturally deficient in their ability to degrade short chain hydrocarbons of 12 carbons or less.64. The method of claim 1 , claim 1 , claim 1 , or claim 1 , wherein said consortium comprises microbes that are engineered to be unable to degrade short chain hydrocarbons of 12 carbons or less.7. The method of claim 6 , wherein said consortium comprises microbes in which one or more metabolic pathways for degrading short chain hydrocarbons of 12 carbons or less are down regulated or deleted or modified.84. The method of claim 6 , claim 6 , claim 6 , or claim 6 , wherein said consortium comprises microbes that naturally have the ability to degrade hydrocarbon chains of greater than 12 carbons.94. The method of claim 6 , ...

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21-03-2013 дата публикации

SUSPENSIONS FOR ENHANCED OIL RECOVERY

Номер: US20130068312A1
Автор: Sanders Aaron W.
Принадлежит: Dow Global Technologies LLC

Embodiments of the present disclosure include suspensions for use in enhanced oil recovery, and methods of using the suspensions for recovering oil. Suspensions of the present disclosure include a nonionic surfactant that can dissolve in supercritical carbon dioxide, and a metal salt having a concentration of 200 to 1 parts-per-million. 1. A method , comprising:supplying supercritical carbon dioxide through piping; andintroducing a suspension having a nonionic surfactant and a metal salt into the supercritical carbon dioxide in the piping, the suspension having a metal salt having a concentration of 200 to 1 parts-per-million.2. The method of claim 1 , including depositing at least a portion of the metal salt on at least a portion of the piping; anddissolving the metal salt from at least the portion of the piping with an aqueous solution.3. The method of claim 1 , where the nonionic surfactant is selected from the group consisting of an alkylphenol alkoxylate claim 1 , an alkyl alkoxylate and combinations thereof.4. The method of claim 1 , where the metal salt is selected from the group consisting of a carboxylate claim 1 , a boron salt claim 1 , a titanium salt claim 1 , a metal carbonate claim 1 , a metal chloride claim 1 , a metal sulfate claim 1 , a metal phosphate claim 1 , a metal sulphonate claim 1 , a metal phosphonate claim 1 , a metal-cyanide salt claim 1 , and combinations thereof.5. The method of claim 1 , including exposing the suspension to an oxidizing agent prior to introducing the suspension into the supercritical carbon dioxide.6. The method of claim 1 , including forming a carboxylic acid in the suspension prior to introducing the suspension into the supercritical carbon dioxide.7. A method claim 1 , comprising:supplying supercritical carbon dioxide through piping;introducing a suspension having a nonionic surfactant and a metal salt into the supercritical carbon dioxide in the piping the suspension having a metal salt concentration of 200 to 1 ...

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21-03-2013 дата публикации

SYSTEMS AND METHODS FOR SEPARATING OIL AND/OR GAS MIXTURES

Номер: US20130068456A1
Принадлежит: SHELL OIL COMPANY

A system for producing oil and/or gas from an underground formation comprising a well above the formation; a mechanism to inject an enhanced oil recovery formulation into the formation, the enhanced oil recovery formulation comprising water and a solvent; a mechanism to produce the water, solvent, oil, and gas from the formation; a separator to separate the oil, water, and a first portion of the solvent from the gas and a second portion of the solvent; and an absorption tower to expose the gas and the second portion of the solvent to water to remove the second portion of the solvent from the gas. 1. A system for producing oil from an underground formation comprising:a first well located above the formation;a mechanism located at the first well to inject an enhanced oil recovery formulation into the formation, the enhanced oil recovery formulation comprising water and a solvent;a mechanism to produce water, solvent, oil, and gas from the formation;a separator to separate the produced oil, produced water, and a first portion of the produced solvent from the produced gas and a second portion of the produced solvent; andan absorption tower to expose the separated gas and the separated second portion of the solvent to water to remove the second portion of the solvent from the separated gas.2. The system of claim 1 , further comprising a second well a distance from the first well claim 1 , wherein the mechanism to produce the water claim 1 , solvent claim 1 , oil claim 1 , and gas from the formation is located at the second well.3. The system of claim 1 , further comprising a stripper to expose the produced water and a first portion of the produced solvent to a gas to remove the first portion of the produced solvent from the produced water.4. The system of claim 1 , further comprising a first conduit to pass the separated gas from the absorption tower to the stripper.5. The system of claim 4 , further comprising a turbo expander in the first conduit to lower the pressure ...

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28-03-2013 дата публикации

PROCESS FOR THE REMOVAL OF DEPOSITS FROM AN OIL OR GAS WELL, AND/OR FROM THE SURFACE STRUCTURES, AND/OR FROM THE EQUIPMENT CONNECTED THEREWITH, AND/OR FROM HYDROCARBON BEARING FORMATIONS

Номер: US20130079255A1
Принадлежит: ENI S.P.A.

Process for the removal of deposits from an oil or gas well, and/or from surface structures, and/or from the equipment connected therewith, and/or from hydrocarbon-bearing formations, comprising: —injecting at least one oil-in-water nanoemulsion into said oil or gas well, and/or surface structures, and/or equipment connected therewith, and/or hydrocarbon bearing formations; leaving said nanoemulsion in said oil or gas well, and/or surface structures, and/or equipment connected therewith, and/or hydrocarbon bearing formations, for a predetermined time. 1. A process for removing deposits , the process comprising:injecting at least one oil-in-water nanoemulsion into at least one space selected from the group consisting of an oil well, a gas well, a surface structure, an equipment connected to an oil well, an equipment connected to a gas well, an equipment connected to a surface structure, and a hydrocarbon bearing formation; andleaving the at least one nanoemulsion in the space, for a predetermined time.2. The process of claim 1 , wherein said process is suitable for removing organic deposits.3. The process of claim 1 , wherein said oil-in-water nanoemulsion comprises a dispersed phase comprising an oil and a dispersing phase comprising water.4. The process of claim 3 , wherein the dispersed phase is distributed in the dispersing phase in the form of droplets having a diameter ranging from 10 nm to 500 nm.5. The process of claim 4 , wherein the dispersed phase is distributed in the dispersing phase in the form of droplets having a diameter ranging from 15 nm to 200 nm.6. The process of claim 1 , wherein said oil-in-water nanoemulsion is prepared according to a process comprising dilutinga homogeneous water/oil mixture (1)in a dispersing phase consisting of water to which at least one surfactant (2) has been added,wherein:the homogeneous water/oil mixture (1) comprises water, in an amount ranging from 65% by weight to 99.9% by weight with respect to a total weight of ...

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28-03-2013 дата публикации

Oil release with polyethylene oxide segment-containing n-lauroyl amino acid-based compounds

Номер: US20130079259A1
Принадлежит: EI Du Pont de Nemours and Co

Chemical compounds that are N-lauroyl amino acids containing a polyethylene oxide segment were found to have oil-releasing activity. Solutions containing these compounds may be introduced into oil reservoirs or onto oil-contaminated surface sites to release oil from oil-coated surfaces. The released oil may be recovered for further processing or waste disposal.

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28-03-2013 дата публикации

SULFONATED INTERNAL OLEFIN SURFACTANT FOR ENHANCED OIL RECOVERY

Номер: US20130079261A1
Принадлежит:

A process for recovering oil from an oil-bearing formation comprises introducing into said formation an aqueous composition comprising at least one sulfonated derivative of one or more internal olefins, said internal olefins being characterized by having low amounts of tri-substitution on the olefin bond, said sulfonated derivative being obtained by sulfonating a composition comprising internal olefins of the formula: RRC═CRRwherein R, R, Rand Rare the same or different and are hydrogen or straight- or branched-chain, saturated hydrocarbyl groups and the total number of carbon atoms of R, R, Rand Ris 6 to 44 with the proviso that at least about 96 mole percent of Rand Rare straight- or branched-chain, saturated hydrocarbyl groups and at least about 96 mole percent of Rand Rare hydrogen. Further provided are compositions for use in recovering oil from an oil bearing formation. 2. The process of wherein the one or more alpha-olefins are obtained by the metathesis of an unsaturated glyceride containing composition with ethene and/or one or more lower alpha-olefins in the presence of a metathesis catalyst.4. The process of wherein the metathesis catalysts are selected from the group consisting of Grubbs-type catalysts claim 1 , Schrock catalysts claim 1 , Hoveyda-Grubbs claim 1 , tungsten catalysts claim 1 , molybdenum catalysts and rhenium catalysts.6. The process of wherein at least about 97 mole percent of Rand Rare straight- or branched-chain claim 1 , saturated hydrocarbyl groups and at least about 97 mole percent of Rand Rare hydrogen.7. The process of wherein at least about 98 mole percent of Rand Rare straight- or branched-chain claim 1 , saturated hydrocarbyl groups and at least about 98 mole percent of Rand Rare hydrogen.8. The process of wherein at least about 99 mole percent of Rand Rare straight- or branched-chain claim 1 , saturated claim 1 , hydrocarbyl groups and at least about 99 mole percent of R and Rare hydrogen.9. The process of wherein less than ...

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04-04-2013 дата публикации

HYDROCARBON RECOVERY FROM BITUMINOUS SANDS WITH INJECTION OF SURFACTANT VAPOUR

Номер: US20130081808A1
Принадлежит:

A process of increasing recovery rate of hydrocarbon from a reservoir of bituminous sands is disclosed. The process comprises softening bitumen in a region in the reservoir to generate a fluid comprising a hydrocarbon, to allow the fluid to drain by gravity from the region into a production well below the region for recovery of the hydrocarbon; and providing vapour of a compound to the region, and allowing the compound to disperse and condense in the region. The compound is represented by 2. The process of claim 1 , wherein softening bitumen in the region comprises injecting steam or a solvent into the region.3. The process of claim 1 , wherein softening bitumen in the region comprises heating bitumen in the region.4. The process of claim 1 , wherein the compound is a primary claim 1 , secondary claim 1 , or tertiary alcohol ethoxylate.5. The process of claim 1 , wherein Ris a linear or branched alkyl group having more than 5 carbon atoms claim 1 , and m is greater than 1.7. The process of claim 4 , wherein the vapour of the alcohol ethoxylate is provided to the region at a partial pressure of about 85 kPa to about 590 kPa and a temperature from about 225° C. to about 275° C.8. The process of claim 1 , wherein the vapour of the compound is provided to the region with steam from an injection well.9. The process of claim 8 , wherein the compound is an alcohol ethoxylate claim 8 , and the steam is at a temperature from about 225° C. to about 275° C. in the injection well claim 8 , and the molar ratio of the vapour of the alcohol ethoxylate to the steam in the injection well is about 0.03:1 to about 0.1:1.10. The process of claim 8 , wherein the steam is at a temperature from about 160° C. to about 310° C. and a pressure of about 600 kPa to 10 MPa in the injection well.11. The process of claim 8 , wherein the compound is an alcohol ethoxylate claim 8 , and the volume ratio of the alcohol ethoxylate to the steam claim 8 , measured at room temperature on a liquid basis ...

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04-04-2013 дата публикации

Fluid Loss Additives and Methods of Making and Using Same

Номер: US20130085085A1
Принадлежит: Chevron Phillips Chemical Co LP

A non-aqueous wellbore servicing fluid comprising a fluid loss additive wherein the fluid loss additive comprises the reaction product of (i) a functional polymer and (ii) an oligomerized fatty acid. A method of conducting an oil-field operation comprising placing a non-aqueous wellbore servicing fluid downhole wherein the non-aqueous wellbore servicing fluid comprises a fluid loss additive comprising the reaction product of (i) a functional polymer and (ii) an oligomerized fatty acid.

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11-04-2013 дата публикации

Dendritic comb-shaped polymer thickening agent, preparaton of the same and application thereof

Номер: US20130090269A1
Принадлежит: Petrochina Co Ltd

The present invention relates to a dendritic comb-shaped polymer thickening agent and preparation and application thereof; it is a copolymer obtained by copolymerization of monomer (A) and monomer (B). Monomer (A) is one or more water-soluble unsaturated monomers with olefin chain, and monomer (B) is at least one monomer with the following general structure: wherein R 1 , R 2 is selected from H or C 1 ˜C 12 alkyl group, respectively; R 3 , R 4 , R 5 is selected from H or C 1 ˜C 8 alkyl group, C 1 ˜C 8 alkylaryl group, C 1 ˜C 8 alkyl ether or C 1 ˜C 8 alkyl ester group, respectively; A′ is selected from COO − or OH. The content of the monomer (A) is 70˜99.99% of the total mass of the monomer (A) and the monomer (B), and the content of monomer (B) is 0.01˜30% of the total mass of the monomer (A) and the monomer (B). The viscosity of the polymer solution with the present polymer is 30% higher than that with common polyacrylamide and it is used in polymer flooding for oil reservoir with permeability lower than 400 mD in oilfields.

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18-04-2013 дата публикации

OIL RELEASE WITH AMINO ACID-BASED COMPOUNDS HAVING A LONG CHAIN N-ACYL GROUP

Номер: US20130095562A1
Принадлежит: E.I. Du Pont De Nemours and Company

Chemical compounds that are N-acyl amino acids or derivatives thereof having long chain N-acyl groups were found to have oil-releasing activity. Solutions containing these compounds may be introduced into oil reservoirs or onto oil-contaminated surface sites to release oil from oil-coated surfaces. The released oil may be recovered for further processing or waste disposal. 2. The method of wherein the composition further comprises:a) one or more microorganism which grows in the presence of oil and an electron acceptor; andb) a minimal growth medium comprising a carbon source and an electron acceptor;wherein the oil-coated surface is in an oil reservoir and the microorganism inoculates the oil reservoir such that it populates and grows in the oil reservoir.3. The method of or wherein Ris H or CH.4. The method of or wherein Rand Rare both uncharged.5. The method of or wherein Ris an alkali metal cation.6. The method of wherein the alkali metal cation is Na or K.7. The method of or wherein the composition comprises a mixture of compounds of structure (XXIV).8. The method of wherein the compounds of structure (XXIV) in the mixture vary in the type of alkyl chain in the compound.9. The method of or wherein the aqueous composition comprises injection water.10. The method of wherein the oil-coated surface is in a subsurface or surface formation.11. The method of wherein the subsurface formation is an oil reservoir.12. The method of or wherein the oil-coated surface is selected from the group consisting of rock claim 9 , soil claim 9 , sand claim 9 , shale claim 9 , clay claim 9 , sediment claim 9 , sludge claim 9 , harbor dredge spoils claim 9 , refinery waste claim 9 , and mixtures thereof.13. The method of wherein the oil-coated surface is selected from the group consisting of a pipeline claim 1 , oil tank claim 1 , oil tanker claim 1 , and oil handling equipment.14Pseudomonas, Bacillus, Actinomycetes, Acinetobacter, Arthrobacter, Schizomycetes, Corynebacteria, ...

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25-04-2013 дата публикации

Process for producing mineral oil using surfactants based on a mixture of c24 guerbet-, c26 guerbet-, c28-guerbet containing hydrocarbyl alkoxylates

Номер: US20130098612A1
Принадлежит: BASF SE

The present invention relates to a surfactant mixture comprising at least three ionic surfactants which differ in terms of the hydrocarbyl moiety (R 1 )(R 2 )—CH—CH 2 — and are of the general formula (I) where R 1 , R 2 , A 0 , k, X, o, Y, a, b, M are each as defined in the description and the claims. The invention further relates to the use and preparation thereof, and to aqueous surfactant formulations comprising the mixtures, and to processes for producing mineral oil by means of Winsor type Ill microemulsion flooding, in which the aqueous surfactant formulation is injected into a mineral oil deposit through injection wells and crude oil is withdrawn from the deposit through production wells.

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25-04-2013 дата публикации

Geothermal well diversion agent formed from in situ decomposition of carbonyls at high temperature

Номер: US20130098613A1
Автор: Daniel Bour, Peter Rose

A method of selectively blocking fractures in a subterranean formation by injecting a diversion agent into the well is disclosed. According to one embodiment, the method comprises injecting a diversion agent into a subterranean formation to form an alkaline-earth carbonate precipitate from decomposition of a carbonyl compound, wherein the diversion agent includes the carbonyl compound and an alkaline-earth halide salt.

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25-04-2013 дата публикации

Downhole polymer foam applications

Номер: US20130098622A1
Принадлежит: Schlumberger Technology Corp

A method of treating a subterranean formation penetrated by a wellbore by contacting an energized fluid with the subterranean formation; and reducing a partial pressure of the energized fluid by an amount sufficient to form polymeric foam structure within the subterranean formation

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02-05-2013 дата публикации

HYDROPHOBICALLY ASSOCIATING COPOLYMERS

Номер: US20130105165A1
Принадлежит: BASF SE

Water-soluble, hydrophobically associating copolymers which comprise new types of hydrophobically associating monomers. The monomers comprise an ethylenically unsaturated group and a polyether group with block structure comprising a hydrophilic polyalkylene oxide block which consists essentially of ethylene oxide groups, and a terminal, hydrophobic polyalkylene oxide block which consists of alkylene oxides with at least 4, preferably at least 5 carbon atoms. 123-. (canceled)24. A process for the development , exploitation , and completion of subterranean mineral oil deposits and natural gas deposits comprising utilizing a water-soluble , hydrophobically associating copolymer comprising at least(a) 0.1 to 20% by weight of at least one monoethylenically unsaturated, hydrophobically associating monomer (a), and(b) 25% to 99.9% by weight of at least one monoethylenically unsaturated hydrophilic monomer (b) different therefrom, {'br': None, 'sub': 2', '2', 'k', '2', 'l, 'sup': 1', '4', '2', '3', '5, 'HC═C(R)—R—O—(—CH—CH(R)—O—)—(—CH—CH(R)—O—)—R\u2003\u2003(I)'}, 'wherein the quantitative data are based in each case on the total amount of all of the monomers in the copolymer, wherein at least one of the monomers (a) is a monomer of the general formula (I)'}{'sub': 2', 'k', '2', 'l, 'sup': 2', '3, 'wherein the units —(—CH—CH(R)—O—)and —(—CH—CH(R)—O—)are arranged in block structure in the order shown in formula (I) and the radicals and indices have the following meaningk: a number from 10 to 150,l: a number from 5 to 25,{'sup': '1', 'R: H or methyl,'}{'sup': 2', '2, 'R: independently of one another, H, methyl, or ethyl, with the proviso that at least 50 mol % of the radicals Rare H,'}{'sup': 3', '2′', '2′, 'sub': '2', 'R: independently of one another, a hydrocarbon radical having at least 2 carbon atoms or an ether group of the general formula —CH—O—R, wherein R is a hydrocarbon radical having at least 2 carbon atoms,'}{'sup': '4', 'sub': n', '2n', 'n′', '2n′', 'n″', '2n″, ' ...

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02-05-2013 дата публикации

Method of Oil Extraction

Номер: US20130109598A1
Автор: Sabatino Nacson
Принадлежит: Individual

A composition for use in extracting oil, the composition comprising: (a) a mixture comprising, by weight, 50-55% of an aromatic alkyl, 15-19% d-limonene, 6.5-7% polyethylsorbitan monoleate, 15-15.5% PEG sorbitan monostearate, 3.4-9.9% tall fatty acid, and EDTA in an amount up to 1%; and (b) water in an amount such that the mixture is diluted to 1%-2% by weight of the composition.

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09-05-2013 дата публикации

Compositions and Methods for Protecting Metal Surfaces from Corrosion

Номер: US20130112415A1
Принадлежит:

Guard bed compositions for protecting metal surfaces in a wellbore from corrosion may comprise a variety of constituent components. Exemplary guard bed compositions may include: one or more surfactants selected from the group comprising amine surfactants; one or more co-surfactants selected from the group comprising C3 to C15 alcohols; and one or more non-surfactant amines. Other exemplary guard bed compositions may comprise: a hydrocarbon fluid and an overbased detergent. Still other exemplary guard bed compositions may comprise: a hydrocarbon fluid; one or more surfactants; one or more co-surfactants; and one or more non-surfactant amines. The one or more surfactants may be selected from the group comprising alkyl alkoxylated surfactants. Still further, exemplary guard bed compositions may comprise: a hydrocarbon fluid and one or more associating surface active polymers selected from the group comprising amphiphilic polymers. 1. A guard bed composition for protecting a metal surface in a wellbore from corrosion , the composition comprising:a hydrocarbon fluid; andone or more associating surface active polymers selected from the group comprising amphiphilic polymers.2. The guard bed composition of wherein the polymer comprises between about 0.1 wt % and about 10 wt % of the guard bed composition.3. The guard bed composition of wherein the hydrocarbon fluid comprises hydrocarbons selected from the group of normal and branched alkane hydrocarbons having C8 to C20 carbons.4. The guard bed composition of wherein the hydrocarbon fluid comprises cyclic hydrocarbons.5. The guard bed composition of wherein the hydrocarbon fluid comprises synthetic oils.6. The guard bed composition of wherein the hydrocarbon fluid comprises an ultra low aromatic fluid.7. The guard bed composition of wherein the hydrocarbon fluid comprises less than about 1 wt % aromatic compounds.8. The guard bed composition of wherein the associating surface active polymers comprise a hydrocarbon backbone ...

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09-05-2013 дата публикации

Compositions and Methods for Protecting Metal Surfaces from Corrosion

Номер: US20130112416A1
Принадлежит: Individual

Guard bed compositions for protecting metal surfaces in a wellbore from corrosion may comprise a variety of constituent components. Exemplary guard bed compositions may include: one or more surfactants selected from the group comprising amine surfactants; one or more co-surfactants selected from the group comprising C3 to C15 alcohols; and one or more non-surfactant amines. Other exemplary guard bed compositions may comprise: a hydrocarbon fluid and an overbased detergent. Still other exemplary guard bed compositions may comprise: a hydrocarbon fluid; one or more surfactants; one or more co-surfactants; and one or more non-surfactant amines. The one or more surfactants may be selected from the group comprising alkyl alkoxylated surfactants. Still further, exemplary guard bed compositions may comprise: a hydrocarbon fluid and one or more associating surface active polymers selected from the group comprising amphiphilic polymers.

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09-05-2013 дата публикации

Compositions and Methods for Protecting Metal Surfaces from Corrosion

Номер: US20130112417A1
Принадлежит:

Guard bed compositions for protecting metal surfaces in a wellbore from corrosion may comprise a variety of constituent components. Exemplary guard bed compositions may include: one or more surfactants selected from the group comprising amine surfactants; one or more co-surfactants selected from the group comprising C3 to C15 alcohols; and one or more non-surfactant amines. Other exemplary guard bed compositions may comprise: a hydrocarbon fluid and an overbased detergent. Still other exemplary guard bed compositions may comprise: a hydrocarbon fluid; one or more surfactants; one or more co-surfactants; and one or more non-surfactant amines. The one or more surfactants may be selected from the group comprising alkyl alkoxylated surfactants. Still further, exemplary guard bed compositions may comprise: a hydrocarbon fluid and one or more associating surface active polymers selected from the group comprising amphiphilic polymers. 1. A guard bed composition for protecting a metal surface in a wellbore from corrosion , the composition comprising:a hydrocarbon fluid; andan overbased detergent; wherein the overbased detergent is selected to form a colloidal coating on the metal surface upon contact with hydrogen sulfide and water.2. The guard bed composition of wherein the overbased detergent comprises greater than about 20 wt % based on the weight of the guard bed composition.3. The guard bed composition of wherein the overbased detergent comprises between about 20 wt % and about 99 wt %.4. The guard bed composition of further comprising at least one co-surfactant selected from the group comprising C3 to C15 alcohols claim 1 , wherein the alcohols are selected from the group comprising branched alcohols claim 1 , linear alcohols claim 1 , and mixtures thereof.5. The guard bed composition of wherein the hydrocarbon fluid comprises hydrocarbons selected from the group comprising normal and branched alkane hydrocarbons having C8 to C20 carbons claim 1 , cyclic alkanes claim ...

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09-05-2013 дата публикации

Composition and Methods for Protecting Metal Surfaces from Corrosion

Номер: US20130112418A1
Принадлежит:

Guard bed compositions for protecting metal surfaces in a wellbore from corrosion may comprise a variety of constituent components. Exemplary guard bed compositions may include: one or more surfactants selected from the group comprising amine surfactants; one or more co-surfactants selected from the group comprising C3 to C15 alcohols; and one or more non-surfactant amines. Other exemplary guard bed compositions may comprise: a hydrocarbon fluid and an overbased detergent. Still other exemplary guard bed compositions may comprise: a hydrocarbon fluid; one or more surfactants; one or more co-surfactants; and one or more non-surfactant amines. The one or more surfactants may be selected from the group comprising alkyl alkoxylated surfactants. Still further, exemplary guard bed compositions may comprise: a hydrocarbon fluid and one or more associating surface active polymers selected from the group comprising amphiphilic polymers. 1. A guard bed composition for protecting a metal surface in a wellbore from corrosion , the composition comprising:a hydrocarbon fluid;one or more surfactants selected from the group comprising alkyl alkoxylated surfactants;one or more co-surfactants selected from the group comprising C3 to C15 alcohols; andone or more non-surfactant amines.2. The guard bed composition of wherein the hydrocarbon fluid comprises between about 0 wt % and about 90 wt % based on the weight of the guard bed composition.3. The guard bed composition of wherein the hydrocarbon fluid comprises hydrocarbons selected from the group of normal and branched alkane hydrocarbons having C8 to C20 carbons.4. The guard bed composition of wherein the hydrocarbon fluid comprises cyclic hydrocarbons.5. The guard bed composition of wherein the hydrocarbon fluid comprises an ultra low aromatic fluid.6. The guard bed composition of wherein the hydrocarbon fluid comprises less than about 1 wt % aromatic compounds.7. The guard bed composition of wherein the alkyl alkoxylated ...

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09-05-2013 дата публикации

Enhanced electrolytic degradation of controlled electrolytic material

Номер: US20130112429A1
Автор: James B. Crews
Принадлежит: Baker Hughes Inc

A method for degrading a downhole article includes exposing the downhole article to a composition comprising a corrosive agent selected from a reducing sugar, ester, aminocarboxylic acid, or a combination thereof. The method also includes contacting the downhole article with the corrosive agent to degrade the downhole article. Additionally, a composition for degrading a downhole article includes water, salt, and a corrosive agent selected from a reducing sugar, ester, aminocarboxylic acid, or a combination thereof.

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09-05-2013 дата публикации

Chemical seal ring composition and method of using

Номер: US20130116156A1
Принадлежит: Schlumberger Technology Corp

Disclosed herein is a chemical seal ring composition that includes polyacrylamide crosslinked with a non-metallic crosslinker such as polylactam. Also, described in a method of forming a chemical seal ring from the chemical seal ring composition.

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16-05-2013 дата публикации

POLYMERS HAVING ACID AND AMIDE MOIETIES, AND USES THEREOF

Номер: US20130123147A1
Принадлежит: ISP Investments Inc.

Polymers are described that are polymerized from at least one reactive vinyl monomer having acid functionality or a salt thereof, and at least one reactive vinyl monomer having amide functionality. These polymers have a molecular weight from about 500 Da to about 15,000 Da; and may additionally comprise one or more solvent adducts. These polymers may be included in compositions that find use in oilfield applications, such as for inhibition and/or prevention of gas hydrates and/or corrosion. 1. A polymer polymerized from at least one reactive vinyl monomer having acid functionality or a salt thereof , and at least one reactive vinyl monomer having amide functionality , wherein the polymer has a molecular weight from about 500 Da to about 15 ,000 Da.2. The polymer according to further comprising at least one solvent adduct.3. The polymer according to wherein said solvent adduct is present in an amount from about 0.1% to about 20% by weight.4. The polymer according to wherein said solvent adduct is obtained from a glycol ether claim 3 , alcohol claim 3 , thiol claim 3 , or blends thereof.5. The polymer according to wherein said glycol ether is selected from the group consisting of: 2-methoxyethanol claim 4 , 2-ethoxyethanol claim 4 , 2-propoxyethanol claim 4 , 2-isopropoxyethanol claim 4 , 2-butoxyethanol claim 4 , 2-phenoxyethanol claim 4 , 2-benzyloxyethanol claim 4 , 2-(2-methoxyethoxy)ethanol claim 4 , 2-(2-ethoxyethoxy)ethanol claim 4 , 2-(2-butoxyethoxy)ethanol claim 4 , dimethoxyethane claim 4 , diethoxyethane claim 4 , dibutoxyethane claim 4 , and blends thereof.6. The polymer according to that is a random claim 1 , block claim 1 , graft claim 1 , or alternating polymer.7. The polymer according to wherein said reactive vinyl monomer containing acid functionality or salt thereof is present from about 0.1% to about 99.9% by weight.8. The polymer according to wherein said reactive vinyl monomer containing acid functionality is selected from the group consisting of ...

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16-05-2013 дата публикации

Metallic particle induced saponification of fatty acids as breakers for viscoelastic surfactant-gelled fluids

Номер: US20130123150A1
Автор: James B. Crews
Принадлежит: Baker Hughes Inc

A method for affecting the viscosity of an aqueous fluid gelled with a VES includes providing an aqueous fluid and adding to the aqueous fluid, in any order: at least one VES comprising a non-ionic surfactant, cationic surfactant, amphoteric surfactant or zwitterionic surfactant, or a combination thereof, in an amount sufficient to form a gelled aqueous fluid comprising a plurality of elongated micelles, a glyceride oil comprising a fatty acid, and a plurality of metallic particles to produce a mixture comprising dispersed metallic particles. The method also includes dissolving at least a portion of the metallic particles in the aqueous fluid to provide a compound comprising a metallic base and forming in situ a soap reaction product of the fatty acid with the compound, wherein the soap reaction product is present in an amount effective to increase, decrease, or increase and then decrease a viscosity of the gelled aqueous fluid.

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23-05-2013 дата публикации

Lubricity Agents to Increase Pump Efficiency in Hydrate Inhibitor Applications

Номер: US20130130941A1
Принадлежит: BAKER HUGHES INCORPORATED

Saturated and unsaturated carboxylic fatty acids and alkylamine salts, alkyl esters and alkyl amide derivatives of these fatty acids are effective in improving the lubricity of hydrate inhibitor formulations, thereby effectively reducing the level of wear on moving parts of a pump under a load during pumping of the hydrate inhibitor formulation, for instance into an umbilical for a subsea hydrocarbon production operation. 1. A method of pumping a hydrate inhibitor composition , the method comprising:adding to the hydrate inhibitor composition an effective amount to increase lubricity of at least one lubricity agent selected from the group consisting of a C1-C36 carboxylic fatty acid, an alkylamine salt of a C1-C36 fatty acid, an alkyl ester of a C1-C36 fatty acid, an alkylphenol ester of a C1-C36 fatty acid, an alkanolamine salt of a C1-C36 fatty acid, an imidazoline salt of a C1-C36 fatty acid, an anhydride salt of a C1-C36 fatty acid, an alkanol amide of a C1-C36 fatty acid, an alkyl amide of a C1-C36 fatty acid, a polyetheramine salt of a C1-C36 fatty acid, and combinations thereof; andpumping the hydrate inhibitor composition containing the lubricity agent.2. The method of where the hydrate inhibitor composition comprises a hydrate inhibitor selected from the group consisting of:0.01 to 99.99 vol % of an alcohol selected from the group consisting of methanol, ethanol, monoethylene glycol, triethylene glycol and combinations thereof;0.01 to 99.99 vol % of a low dose hydrate inhibitor (LDHI) selected from the group consisting of anti-agglomerants (AAs) kinetic hydrate inhibitors (KHIs) and combinations thereof; andcombinations thereof.3. The method of where the fatty acid of the lubricity agent is derived from naturally-occurring fats claim 1 , naturally-occurring oils claim 1 , oligomers of naturally-occurring fats claim 1 , oligomers of naturally-occurring oils claim 1 , and combinations thereof.4. The method of where the fatty acid is tall oil fatty acid (TOFA ...

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23-05-2013 дата публикации

Methods and compounds for improving sulfide scavenging activity

Номер: US20130131387A1
Автор: Gregory Kaplan, Ping Lue
Принадлежит: General Electric Co

Methods for reducing sulfides from fluid streams are provided. The methods comprise adding secondary amine-formaldehyde adduct (SAFA) scavengers to fluid streams. The SAFA scavengers added comprise less than about 40 wt % N-methyl secondary amines of the total weight of SAFA scavengers. Methods for distilling N-methyl secondary amines from secondary amine-formaldehyde adduct (SAFA) scavengers are also provided. Purified SAFA scavengers are also disclosed.

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30-05-2013 дата публикации

Methods for Initiating New Fractures in a Completed Wellbore Having Existing Fractures Present Therein

Номер: US20130133887A1
Автор: Bradley L. Todd
Принадлежит: Halliburton Energy Services Inc

Fracturing operations can be problematic in completed wellbores containing at least one existing fracture, since it can be difficult to seal an existing fracture and initiate a new fracture within a reasonable timeframe due to the presence of particulate materials in the wellbore. Methods for fracturing a completed wellbore can comprise introducing a treatment fluid comprising a plurality of degradable sealing particulates into a completed wellbore penetrating a subterranean formation having an existing fracture therein; sealing the existing fracture with at least a portion of the degradable sealing particulates, thereby forming a degradable particulate seal; after sealing, allowing any degradable sealing particulates remaining in the treatment fluid to degrade, such that the treatment fluid becomes substantially particulate free; and after the treatment fluid becomes substantially particulate free, fracturing the subterranean formation so as to introduce at least one new fracture therein.

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30-05-2013 дата публикации

Methods of Removing Deposits of Oil and Gas Applications

Номер: US20130137608A1
Принадлежит: THE LUBRIZOL CORPORATION

This invention relates to compositions and methods for controlling and/or removing deposits in oil and/or gas handling equipment, and more specifically relates to controlling and/or removing deposits from the walls of oil and/or gas pipelines. 1. A method of removing deposits in oil and/or gas handling equipment comprising the steps of (I) supplying to internal surfaces of said equipment a composition comprising: (i) a quaternary ammonium salt comprising the reaction product of: (1) the reaction of a hydrocarbon substituted acylating agent and a compound having an oxygen or nitrogen atom capable of condensing with said acylating agent and further having a tertiary amino group; and (2) a quaternizing agent suitable for converting the tertiary amino group to a quaternary nitrogen;', '(ii) a hydrocarbon substituted with at least two carboxy functionalities in the form of acids and/or one or more anhydrides;', '(iii) a hydrocarbon substituted benzene sulfonic acid; and, '(a) an additive component comprising at least one of the following(b) a hydrocarbon solvent that is liquid at 20 degrees C.2. The method of wherein the hydrocarbon group of deposit additive (i) and/or (ii) contains at least 30 carbon atoms; andwherein the quaternizing agent of deposit additive (i) is selected from the group consisting of dialkyl sulfates, benzyl halides, hydrocarbyl substituted carbonates; hydrocarbyl epoxides optionally in combination with an acid; or mixtures thereof.3. The method of wherein the hydrocarbon group of deposit additive (i) and/or (ii) is derived from polyisobutylene that has a number average molecular weight of at least 800.4. The method of wherein the hydrocarbon group of deposit additive (iii) contains from 10 to 14 carbon atoms.5. The method of wherein component (b) comprises a heavy aromatic naptha solvent claim 1 , a branched fatty alcohol containing at least 8 carbon atoms claim 1 , or a combination thereof.6. The method of wherein the composition further comprises ...

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30-05-2013 дата публикации

ADDITIVE COMPOSITION FOR WELL TREATMENT FLUIDS

Номер: US20130137611A1
Принадлежит: Calfrac Well Services Ltd.

Described is an additive composition made up of at least one dibasic ester, at least one non-ionic surfactant, at least one terpene or terpene derivative and optionally, at least one polyalkylene glycol and/or water. The composition is useful as an additive for well treatment fluids used for cleaning or stimulation of oil or gas wells. 1. An additive composition for a well treatment fluid , the additive composition comprising:about 30% to about 60% by weight of at least one dibasic ester;about 30% to about 60% by weight of at least one non-ionic surfactant;about 1% to about 15% by weight of at least one terpene or terpene derivative;no more than about 20% by volume of water; andno more than about 5% by weight of at least one polyalkylene glycol.2. The additive composition according to wherein the additive composition is effective to increase the solubility of at least one of an aqueous material or a hydrophobic material in the well treatment fluid compared to the solubility of the aqueous material or the hydrophobic material in the well treatment fluid which is free from the additive composition.3. The additive composition according to wherein the additive composition is effective to form a microemulsion with an aqueous fluid.4. The additive composition according to wherein the at least one dibasic ester is selected from a di(C)alkyl ethylsuccinate claim 1 , a di(C)alkyl methylglutarate claim 1 , a di(C)alkyl adipate claim 1 , and a mixture thereof.5. The additive composition according to wherein the at least one dibasic ester is dimethyl 2-methylglutarate.6. The additive composition according to wherein the at least one non-ionic surfactant is at least one aliphatic alkoxylated alcohol.7. The additive composition according to wherein the at least one aliphatic alkoxylated alcohol is ethoxylated isodecyl alcohol having a Hydrophile-Lipophile Balance (HLB) number between about 7 and about 15.8. The additive composition according to wherein the at least one terpene or ...

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13-06-2013 дата публикации

TWO-STAGE FILTER CAKE REMOVAL COMPOSITION FOR DRILLING FLUIDS AND METHOD OF USE THEREOF

Номер: US20130146289A1
Принадлежит: Saudi Arabian Oil Company

Disclosed is a two-stage filter cake removal composition, and method of use thereof, for use in a wellbore for controlled removal of a filter cake present in a target production zone. The two-stage filter cake removal composition may include an enzyme present in an amount of between about 1% and 20%, and a mixture of hydrochloric acid and an organic acid present in amounts of between about 0.1% and 5% and about 0.1% and 10%, respectively, by weight. The two-stage filter cake removal composition, when the enzyme is applied to the filter cake in the target production zone in a first stage and the mixture of the hydrochloric acid and the organic acid is applied to the filter cake in the target production zone in a second stage, is operable to remove the filter cake in the target production zone over an extended reaction time. 1. A two-stage filter cake removal composition for use in a wellbore for controlled removal of a filter cake present in a target production zone , the two-stage filter cake removal composition comprising:an enzyme; anda mixture of hydrochloric acid and an organic acid,wherein the two-stage filter cake removal composition, when the enzyme is applied to the filter cake in the target production zone in a first stage and the mixture of the hydrochloric acid and the organic acid is applied to the filter cake in the target production zone in a second stage, is operable to remove the filter cake in the target production zone over an extended reaction time.2. The two-stage filter cake removal composition of claim 1 , wherein the enzyme is selected from the group consisting of an α-amylase enzyme claim 1 , a β-amylase enzyme claim 1 , and a γ-amylase enzyme claim 1 , the enzyme being present in an amount of between about 1 to about 20% by weight.3. The two-stage filter cake removal composition of claim 2 , wherein the enzyme comprises the α-amylase enzyme present in an amount of about 10% by weight.4. The two-stage filter cake removal composition of claim ...

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13-06-2013 дата публикации

FILTER CAKE REMOVAL COMPOSITION FOR DRILLING FLUIDS AND METHOD OF USE THEREOF

Номер: US20130146295A1
Принадлежит: Saudi Arabian Oil Company

Disclosed is a filter cake removal composition, and method of use thereof, for use in a wellbore for controlled removal of a filter cake present in a target production zone. The filter cake removal composition includes hydrochloric acid and an organic acid. The filter cake removal composition, when a mixture of the hydrochloric acid and the organic acid is applied to the filter cake in the target production zone, is operable to dissolve the filter cake in the target production zone over an extended reaction time. The mixture includes the hydrochloric acid present in an amount of between about 0.1% and 5% by weight and the organic acid present in an amount of between about 0.1% and 10% by weight. 1. A filter cake removal composition for use in a wellbore for controlled removal of a filter cake present in a target production zone , the filter cake removal composition comprising:hydrochloric acid; andan organic acid,wherein the filter cake removal composition, when a mixture of the hydrochloric acid and the organic acid is applied to the filter cake in the target production zone, is operable to dissolve the filter cake in the target production zone over an extended reaction time, andwherein the mixture comprises the hydrochloric acid present in an amount of between about 0.1% and 5% by weight and the organic acid present in an amount of between about 0.1% and 10% by weight.2. The filter cake removal composition of claim 1 , wherein the hydrochloric acid is present in an amount of about 1% by weight.3. The filter cake removal composition of claim 1 , wherein the organic acid is selected from the group consisting of formic acid claim 1 , lactic acid claim 1 , and malonic acid.4. The filter cake removal composition of claim 1 , wherein the organic acid comprises lactic acid present in an amount of about 4% by weight.5. The filter cake removal composition of claim 1 , wherein the filter cake removal composition comprises the mixture of the hydrochloric acid present in an ...

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13-06-2013 дата публикации

LIGHT CO-SOLVENT COMPOSITIONS

Номер: US20130150269A1

Provided herein are inter alia non-surfactant aqueous compositions and methods having application in the field of enhanced oil recovery. In particular, non-surfactant compositions including light co-solvents and an alkali agent presented herein can be used, inter alia, for the recovery of a large range of crude oil compositions from challenging reservoirs. 1. A non-surfactant aqueous composition comprising a light co-solvent , a water-soluble polymer and an alkali agent.2. The non-surfactant aqueous composition of claim 1 , comprising a plurality of different light co-solvents.5. The non-surfactant aqueous composition of claim 3 , wherein Ris linear unsubstituted Calkylene and n is 5.6. The non-surfactant aqueous composition of claim 5 , wherein m is 5.7. The non-surfactant aqueous composition of claim 3 , wherein Ris branched unsubstituted Calkylene and n is 1.8. The non-surfactant aqueous composition of claim 7 , wherein m is 1.9. The non-surfactant aqueous composition of claim 3 , wherein n and m are independently 0.10. The non-surfactant aqueous composition of claim 9 , wherein Ris linear or branched unsubstituted Calkylene.11. An emulsion composition comprising an unrefined petroleum phase and a non-surfactant aqueous phase claim 9 , wherein said non-surfactant aqueous phase comprises a light co-solvent and alkali agent.12. The emulsion composition of claim 11 , wherein the emulsion composition is a microemulsion.15. A method of displacing an unrefined active petroleum material in contact with a solid material claim 11 , said method comprising:(i) contacting an unrefined active petroleum material with a non-surfactant aqueous composition, wherein said unrefined active petroleum material is in contact with a solid material;(ii) allowing said unrefined active petroleum material to separate from said solid material thereby displacing said unrefined active petroleum material in contact with said solid material.18. A method of converting an unrefined active ...

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20-06-2013 дата публикации

Compositions and Methods for Treatment of Well Bore Tar

Номер: US20130153225A1
Принадлежит: Halliburton Energy Services Inc

Of the many compositions and methods provided herein, one method includes contacting tar resident in a well bore with a tar stabilizer comprising an acrylonitrile-butadiene copolymer; and allowing the tar stabilizer to interact with the tar to at least partially reduce the tendency of the tar to adhere to a surface.

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20-06-2013 дата публикации

Nano-Sized Particle-Coated Proppants for Formation Fines Fixation in Proppant Packs

Номер: US20130157906A1
Принадлежит: BAKER HUGHES INCORPORATED

A fracturing fluid, gravel pack fluid and/or frac pack fluid containing particles such as proppants, gravel and/.or sand, may contain an effective amount of a nano-sized particulate additive to fixate or reduce fines migration, where the particulate additive is an alkaline earth metal oxide, alkaline earth metal hydroxide, alkali metal oxides, alkali metal hydroxides transition metal oxides, transition metal hydroxides, post-transition metal oxides, post-transition metal hydroxides piezoelectric crystals and pyroelectric crystals. The nano-sized particulate additive is optionally bound to the particles with a coating agent such as an oil, alcohol, glycol, glycol ethers, ketones, terpenes, etc. The particle size of the magnesium oxide or other agent may be nanometer scale but may be a larger scale than nanometer but still relatively small, which scale may provide unique particle charges that help fixate the formation fines. The carrier fluid used in the treating fluid may be aqueous, brine, alcoholic or hydrocarbon-based. 1. A fluid comprising:a base fluid selected from the group consisting of water-based fluids, alcohol-based fluids and oil-based fluids,particles selected from the group consisting of sand, gravel, ceramic beads, glass beads, and combinations thereof; andan effective amount of a particulate additive to reduce fines migration, the particulate additive having a mean particle size of 5000 nm or less, and being selected from the group consisting of alkaline earth metal oxides, alkaline earth metal hydroxides, alkali metal oxides, alkali metal hydroxides, transition metal oxides, transition metal hydroxides, post-transition metal oxides, post-transition metal hydroxides, piezoelectric crystals, pyroelectric crystals, and mixtures thereof, and being coated on the particles.2. The fluid of where:the alkaline earth metal is selected from the group consisting of magnesium, calcium, strontium, and barium,the alkali metal is selected from the group consisting ...

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27-06-2013 дата публикации

AMINE ADDUCTS, DERIVATIVES THEREOF, METHODS FOR MAKING SUCH ADDUCTS AND DERIVATIVES, AND METHODS FOR USING SUCH ADDUCTS AND DERIVATIVES

Номер: US20130161014A1
Принадлежит: Rhodia Operations

An amine adduct is made by (1) forming an addition intermediate by heating a mixture comprising at least one diene and at least one unsaturated fatty acyl compound, and reacting the addition intermediate with a diamine to form the amine adduct, or by (2) reacting at least one unsaturated fatty acyl compound with at least one diamine to form an amine intermediate, and heating a mixture of the amidoamine intermediate and at least one diene to form the amine adduct, or by (3) reacting at least one unsaturated fatty tertiary amine compound with at least at least one diene to form the amine adduct. A surfactant composition is derived from the amine adduct and is particularly useful in a method for enhancing the recovery of oil from a reservoir having a production wellbore, comprising introducing an aqueous flooding fluid into the reservoir at one or more locations different from the location of the production wellbore, said fluid comprising the surfactant composition and recovering the oil through the production wellbore. 1. An amine adduct , comprising the product obtained by: '(b) reacting the addition intermediate with a diamine to form the amine adduct, or', '(1)(a) forming an addition intermediate by heating a mixture comprising at least one diene and at least one unsaturated fatty acyl compound, and'} '(b) heating a mixture of the amidoamine intermediate and at least one diene to form the amine adduct, or', '(2)(a) reacting at least one unsaturated fatty acyl compound with at least one diamine to form an amidoamine intermediate, and'}(3) reacting at least one unsaturated fatty tertiary amine compound with at least at least one diene to form the amine adduct.2. The amine adduct of wherein the adduct is an amidoamine product claim 1 , obtained by: '(b) reacting the addition intermediate with a diamine to form the amidoamine product, or', '(1)(a) forming an addition intermediate by heating a mixture comprising at least one diene and at least one unsaturated fatty acyl ...

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04-07-2013 дата публикации

Method and system for enhancing oil recovery (eor) by injecting treated water into an oil bearing formation

Номер: US20130168097A1
Принадлежит: Shell Oil Co

A process and a system for enhancing recovery of oil from an oil-bearing formation are provided in which water having a total dissolved solids content is filtered to remove some solids in a filter assembly, the filtered water is treated to remove some ions in a capacitive deionization assembly, and the filtered deionized water is injected into the oil-bearing formation to mobilize crude oil and enhance oil recovery from the formation.

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11-07-2013 дата публикации

Method of controlling reservoir particles using electrolytic composite materials

Номер: US20130175037A1
Принадлежит: Baker Hughes Inc

A method of reducing the presence of particles in a downhole environment, comprising contacting sediment particles contained in a downhole environment, with a composition comprising: a metallic composition, an inorganic oxide-based polymer, and a solvent; the contacting occurring in the presence of a fluid capable of decomposing the metallic composition

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11-07-2013 дата публикации

Nanoparticle Kinetic Gas Hydrate Inhibitors

Номер: US20130175046A1
Принадлежит: Halliburton Energy Services Inc

Inhibiting gas hydrate formation while transporting hydrocarbon fluids may include providing a kinetic gas hydrate inhibitor, adding the kinetic gas hydrate inhibitor to a fluid capable of producing gas hydrates, and transporting the fluid that comprises the kinetic gas hydrate inhibitor. Generally a kinetic gas hydrate inhibitor may include a heterocyclic compound comprising nitrogen, e.g., poly(vinyl pyrrolidone).

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25-07-2013 дата публикации

ADDITIVES FOR IMPROVING HYDROCARBON RECOVERY

Номер: US20130186627A1
Принадлежит:

Processes for recovering hydrocarbons from subterranean formations are disclosed. The hydrocarbon can be contacted with water or steam and one or more additives, and subsequently recovered. The hydrocarbon can be selected from the group consisting of heavy or light crude oil, bitumen, an oil sand ore, a tar sand ore and combinations thereof. The additive can be, for example, a fluorinated hydrocarbon, one or more alcohols, combinations of alcohols, and combinations of one or more alcohols and one or more fluorinated hydrocarbons. Compositions or mixtures including hydrocarbons, water or steam, and additives are also disclosed. 1. A process for recovering a hydrocarbon from a subterranean formation comprising the steps of:contacting the hydrocarbon from a subterranean formation with steam or water,contacting the hydrocarbon with an additive, wherein the additive comprises one or more alcohols, optionally wherein the additive further comprises one or more fluorinated hydrocarbons,wherein the hydrocarbon is contacted with the steam or water, the one or more alcohols, and the optional one or more fluorinated hydrocarbons inside of the subterranean formation or outside of the subterranean formation, andrecovering the hydrocarbon.2. The process of claim 1 , wherein the hydrocarbon is selected from the group consisting of heavy or light crude oil claim 1 , bitumen claim 1 , an oil sand ore claim 1 , a tar sand ore and combinations thereof.3. The process of claim 1 , further comprising the step contacting the hydrocarbon with the steam or water and/or the additive at any time during extraction of the hydrocarbon.4. The process of claim 1 , further comprising the step of contacting the hydrocarbon with the additive wherein the one or more alcohols and the optional one or more fluorinated hydrocarbons have atmospheric boiling points of less than or equal to about 300° C.5. The process of claim 1 , wherein the optional one or more fluorinated hydrocarbons are selected from the ...

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25-07-2013 дата публикации

Asphaltene Inhibitors for Squeeze Applications

Номер: US20130186629A1
Принадлежит: BAKER HUGHES INCORPORATED

Reaction products of polymeric alkyl phenol formaldehyde resins are useful as additives to inhibit or prevent the deposition or precipitation of asphaltenes in hydrocarbon fluids, particularly crude oil produced from a subterranean formation. These reaction products are formed by reacting a polymeric alkyl phenol formaldehyde resin with a co-reactant having functional groups including, but not necessarily limited to, amines, esters, silanes, ketones, epoxides, alkoxides, aryloxides, halogens, alkali metals, alkali earth metals, acetamides, non-metal oxides, metal oxides, where the co-reactant optionally has a carbon chain length between 1 and 22 and the reaction is conducted in the presence of at least one of various solvents. In one non-limiting embodiment, the co-reactant is a silicon derivative. The asphaltene inhibitors have utility when injected into a subterranean formation while oil production temporarily halts, a process called “squeezing,” because they are retained to a degree in the formation as the crude oil is produced. 1. A method of inhibiting or preventing asphaltene deposition in a hydrocarbon fluid containing asphaltenes , the method comprising introducing to the hydrocarbon fluid an amount of asphaltene inhibitor effective to inhibit or prevent asphaltene deposition therein , where the asphaltene inhibitor comprises a reaction product of:an organic polymer which inhibits the precipitation of asphaltenes, where the organic polymer is selected from the group alkylphenol formaldehyde resins, alkylphenol formaldehyde amine resins, polyalkylsuccinic anhydrides, polyalkylsuccinic anhydride pentaerythritol condensate polymers, maleic anhydride alpha olefin polyesters, maleic anhydride fatty amine polyamides, sorbitan polyesters, alkyl polyacrylate esters, and combinations therein, witha co-reactant having functional groups selected from the group consisting of amines, esters, silanes, ketones, epoxides, alkoxides, aryloxides, halogens, alkali metals, ...

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25-07-2013 дата публикации

METHOD AND COMPOSITION FOR ENHANCED OIL RECOVERY

Номер: US20130190543A1
Принадлежит:

A method is provided for treating a hydrocarbon containing formation. The method comprises providing a hydrocarbon recovery composition comprising a mixture of branched internal olefin sulfonate molecules, and contacting hydrocarbons in the hydrocarbon containing formation with the hydrocarbon recovery composition. The mixture of branched internal olefin sulfonate molecules has an average number of carbon atoms of between 19 and 23, and an average number of branches of at least 0.6 per molecule. A hydrocarbon composition produced from a hydrocarbon containing formation, and a hydrocarbon recovery composition comprising a mixture of branched internal olefin sulfonate molecules are also provided. 1. A method of treating a hydrocarbon containing formation , comprising:providing a hydrocarbon recovery composition comprising a mixture of branched internal olefin sulfonate molecules, the mixture having an average number of carbon atoms of between 19 and 23, and an average number of branches of at least 0.6 per molecule; andcontacting hydrocarbons in the hydrocarbon containing formation with the hydrocarbon recovery composition.2. The method of claim 1 , wherein the mixture of branched internal olefin sulfonate molecules has an average number of carbon atoms of between 20 and 23.3. The method of claim 1 , wherein the mixture of branched internal olefin sulfonate molecules has an average number of carbon atoms of between 21 and 22.4. The method of claim 1 , wherein at least 50% of the branched internal olefin sulfonate molecules have between 19 and 23 carbon atoms.5. The method of claim 1 , wherein at least 65% of the branched internal olefin sulfonate molecules have between 19 and 23 carbon atoms.6. The method of claim 1 , wherein the average molecular weight of the mixture of branched internal olefin sulfonate molecules is from 265 to 325.7. The method of claim 1 , wherein the average molecular weight of the mixture of branched internal olefin sulfonate molecules is from ...

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01-08-2013 дата публикации

FLOW ADDITIVE FOR LIGHT OR HEAVY CRUDE OILS, USE OF THE ADDITIVE AND PROCESS TO IMPROVE THE EXTRACTION, PUMPING AND/OR TRANSPORT OF LIGHT OR HEAVY CRUDE OILS

Номер: US20130196882A1
Автор: Firmano Junior Lino
Принадлежит:

The present invention refers to a flow additive useful to improve the extraction and displacement of light or heavy crude oils, which comprises an aqueous emulsion containing hollow or solid synthetic microspheres, a component able to alter the superficial tension, high molecular weight polyelectrolytes, a glycol-type antifreeze and fluidity improvement agent and a thickening agent. The additive according to the present invention improves the flow of crude oil pumped from the wells to storage tanks and also cleans and prevents against incrustations of paraffin and heavy hydrocarbons derived from the perforation of the petroleum wells drilling, even though in low temperatures (below of 0 Celsius degrees). 1. Flow additive for light or heavy crude oils characterized by comprising an aqueous emulsion containing hollow or solid synthetic microspheres , a superficial tension alteration component and high molecular weight polyelectrolytes , an antifreeze and flow enhancer selected from glycol and thickening agent.2. Additive claim 1 , according to claim 1 , characterized by the fact that the aqueous emulsion comprises from 0.1% to 40% in solids of microspheres.3. Additive claim 1 , according to claim 1 , characterized by the fact that the microspheres have external diameter equal or inferior than 1 claim 1 ,000 microns.4. Additive claim 1 , according to claim 1 , characterized by the fact that the microspheres are based on alkaline borosilicates or silicates claim 1 , ceramic such as alumina or silica-alumina claim 1 , polymers such as PVDC claim 1 , metallic claim 1 , zirconium oxides or mixtures thereof.5. Additive claim 1 , according to claim 1 , characterized by the fact that the superficial tension alteration component is based on anionic claim 1 , cationic and/or non ionic fluorated compounds.6. Additive claim 5 , according to claim 5 , characterized by the fact that the fluorated compounds are selected from the group that consists of perfluoroctanes claim 5 , ...

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01-08-2013 дата публикации

SURFACTANT SYSTEMS FOR ENHANCED OIL RECOVERY

Номер: US20130196886A1
Принадлежит:

The invention relates to a hydrocarbon recovery composition comprising a combination of an internal olefin sulfonate and an alkoxy glycidyl sulfonate, more specifically a hydrocarbon recovery composition comprising surfactant and water, wherein the surfactant comprises a combination of an internal olefin sulfonate with a chain length of greater than C20 and an alkoxy glycidyl sulfonate selected from an ethoxylated glycidyl sulfonate and a propoxylated glycidyl sulfonate. Further, the invention relates to a method of treating a hydrocarbon containing formation, comprising (a) providing a hydrocarbon recovery composition to at least a portion of the hydrocarbon containing formation, wherein the composition comprises a blend of an internal olefin sulfonate and an alkoxy glycidyl sulfonate; and (b) allowing the composition to interact with hydrocarbons in the hydrocarbon containing formation. 1. A hydrocarbon recovery composition comprising a combination of an internal olefin sulfonate (IOS) and an alkoxy glycidyl sulfonate (AGS).2. The composition of claim 1 , wherein the IOS is selected from one or more IOS having a chain length selected from the group consisting of: C15-C18; C20-C24; and C24-C28.3. The composition of claim 1 , wherein the IOS has a chain length of greater than C20.4. The composition of claim 1 , wherein the IOS has a chain length of C20-C24.5. The composition of claim 1 , wherein the AGS is an ethoxylated glycidyl sulfonate.6. The composition of claim 1 , wherein the AGS is an ethoxylated glycidyl sulfonate with an ethoxy chain length of between 1 and 9.7. The composition of claim 1 , wherein the AGS is a propoxylated glycidyl sulfonate.8. The composition of claim 1 , wherein the AGS is a propoxylated glycidyl sulfonate with a propoxy chain length of between 1 and 6.9. The composition of claim 1 , wherein the AGS is selected from one or more AGS having an alcohol hydrophobe chain length selected from the group consisting of: C12 claim 1 ,13; C12-15; ...

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08-08-2013 дата публикации

METHOD AND COMPOSITION FOR ENYHANCED HYDROCARBONS RECOVERY

Номер: US20130199788A1
Принадлежит:

A method of treating a formation containing crude oil is described. The method includes (a) providing a hydrocarbon recovery composition to at least a portion of a formation containing crude oil wherein the composition comprises a high molecular weight internal olefin sulfonate and a viscosity reducing compound; and (b) allowing the composition to interact with hydrocarbons in the crude oil containing formation. 1. A method of treating a formation containing crude oil comprising:(a) providing a hydrocarbon recovery composition to at least a portion of the crude oil containing formation, wherein the composition comprises at least one high molecular weight internal olefin sulfonate and at least one viscosity reducing compound; and(b) allowing the composition to interact with hydrocarbons in the crude oil containing formation.2. The method of wherein the hydrocarbon recovery composition is provided to the crude oil containing formation by first admixing it with water and/or brine from the formation from which crude oil is to be extracted to form an injectable fluid claim 1 , wherein the internal olefin sulfonate comprises from 0.05 to 1.0 wt % claim 1 , preferably from 0.1 to 0.8 wt % of the injectable fluid claim 1 , and then injecting the injectable fluid into the formation.3. The method of wherein the composition comprises at least two high molecular weight internal olefin sulfonates selected from the group consisting of Cinternal olefin sulfonates claim 1 , Cinternal olefin sulfonates claim 1 , Cinternal olefin sulfonates and Cinternal olefin sulfonates.4. The method of wherein the viscosity reducing compound is selected from the group consisting of ethanol claim 1 , iso-butyl alcohol claim 1 , sec-butyl alcohol claim 1 , 2-butoxy ethanol claim 1 , diethylene glycol butyl ether and mixtures thereof.5. A method of reducing the viscosity of a high active matter surfactant comprising contacting a composition comprising at least one high molecular weight internal ...

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15-08-2013 дата публикации

Gas evolving oil viscosity diminishing compositions for stimulating the productive layer of an oil reservoir

Номер: US20130206413A1
Принадлежит: Tctm Ltd

The invention is directed to a chemical system of gas evolving oil viscosity diminishing compositions (GEOVDC) for stimulating the productive layer of an oil reservoir, that is to chemical compositions for a thermochemical treatment of an oil reservoir, more specifically for initiating a chemical reaction in the productive layer zone of the oil reservoir to produce heat and evolve gases so that the extraction of oil (petroleum) is improved. The invention is further directed to a method of thermochemically treating an oil reservoir by means of this chemical system, and to an apparatus for performing thermochemical treatment of an oil reservoir.

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15-08-2013 дата публикации

Process for the preparation of water-in-oil and oil-in-water nanoemulsions

Номер: US20130209527A1
Принадлежит: Individual

Process for the preparation of a water-in-oil or oil-in-water nanoemulsion wherein the dispersed phase is distributed in the dispersing phase in the form of droplets having a diameter ranging from 1 to 500 nm, comprising: 1) the preparation of a homogeneous water/oil blend (I) characterized by an interface tension lower than 1 mN/m, comprising water in an amount of 30 to 70% by weight, at least two surface-active agents having a different HLB, selected from non-ionic, anionic, polymeric surface-active agents, said surface-active agents being present in such a quantity as to make the blend homogeneous; 2) the dilution of the blend (I) in a dispersing phase consisting of oil or water with the addition of a surface-active agent, selected from non-ionic, anionic, polymeric surface-active agents, the quantity of the dispersing phase and surface--active agent being such as to obtain a nanoemulsion having a HLB different from that of the blend (I).

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15-08-2013 дата публикации

METHOD OF REMOVING WATER-BASED FILTER CAKE

Номер: US20130210684A1
Автор: Ballard David Anthony
Принадлежит: M-I DRILLING FLUIDS U.K. LIMITED

A method of removing a water-based filter cake from a wellbore, the method comprising: contacting the filter cake with a mixture comprising: a non-aqueous, polar solvent; an agent selected to breakdown the filter cake; said mixture comprising <5 wt % water and preferably being essentially anhydrous. The low water content of the mixture actually slows the degradation of the filter cake which has surprisingly been found to be more effective as it allows a more even removal of the filter cake and a more efficient use of the mixture; without the tendency to create local holes in the filter cake where the mixture could escape. Embodiments of the present invention use a polar solvent with a dielectric constant of more than (15), preferably more than (30) such as (15) monoethylene glycol (MEG). In preferred embodiments the agent comprises a salt based on potassium EDTA (ethylenediaminetetraacetic acid). 1. A method of removing a water-based filter cake from a wellbore , the method comprising:contacting the filter cake with a mixture comprising:a non-aqueous, polar solvent;an agent selected to breakdown the filter cake;said mixture comprising <5 wt % water.2. A method as claimed in claim 1 , wherein the mixture comprises <2 wt % water.3. A method as claimed in claim 1 , wherein the mixture comprises >50 wt % non-aqueous polar solvent.4. A method as claimed in claim 1 , wherein the dielectric constant of the polar solvent is at least 15 preferably at least 30.5. A method as claimed in claim 1 , wherein the non-aqueous claim 1 , polar solvent comprises an oxygenate.6. A method as claimed in claim 5 , wherein the oxygenate comprises an alcohol group.7. A method as claimed in claim 5 , wherein the oxygenate group comprises a glycol.8. A method as claimed in claim 7 , wherein the glycol comprises at least one of monoethylene glycol (MEG) claim 7 , propylene glycol claim 7 , glycerine and dimethylene glycol.9. A method as claimed in claim 1 , wherein the agent comprises a salt ...

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22-08-2013 дата публикации

MITIGATION OF H2S IN STEAM INJECTION TECHNOLOGY USING AMINES OF NATURAL ORIGIN

Номер: US20130213651A1
Принадлежит:

A method for mitigation of HS during a steam injection hydrocarbon producing process includes the steps of injecting steam and an additive comprising soluble molasses condensate (SMC) and amines of natural origin into a steam injection well; and producing hydrocarbons from a hydrocarbon producing well in subterranean fluid communication with the steam injection well, wherein the additive reduces HS content in the hydrocarbon produced from the hydrocarbon producing well. 1. A method for mitigation of HS during a steam injection hydrocarbon producing process , comprising the steps of:injecting steam and an additive comprising soluble molasses condensate (SMC) and amines of natural origin into a steam injection well; and{'sub': '2', 'producing hydrocarbons from a hydrocarbon producing well in subterranean fluid communication with the steam injection well, wherein the additive reduces HS content in the hydrocarbon produced from the hydrocarbon producing well.'}2. The method of claim 1 , wherein the soluble molasses condensate (SMC) contains carboxylic acids claim 1 , lactones claim 1 , alcohols claim 1 , aldehydes claim 1 , phenols and combinations thereof.3. The method of claim 1 , wherein the amines of natural origin are obtained from fish processing residue.4. The method of claim 3 , wherein the fish processing residue contains at least one of methyldiethanolamine (MDEA) claim 3 , monoethanolamine (MEA) claim 3 , diethanolamine (DEA) and combinations thereof.5. The method of claim 3 , wherein the additive further comprises histamine.6. The method of claim 1 , wherein the additive comprises water claim 1 , methyldiethanolamine (MDEA) and soluble molasses condensate (SMC).7. The method of claim 1 , wherein the injection is carried out at a temperature of between 200 and 300° C.8. The method of claim 1 , wherein the additive has a pH of between 10 and 11 and a density at 25° C. of about 1.05 g/cm claim 1 , and contains active amines in an amount between 0.5 and 70% w/w. ...

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29-08-2013 дата публикации

PETROLEUM ASHPHALTENE HANDLER ADDITIVE COMPOUND

Номер: US20130225454A1
Принадлежит: Geo Estratos, S.A. de C.V.

This invention refers to the manufacture and use of a petroleum asphaltene handler additive compound, which when applied in heavy oil, it makes asphaltenes to remain in suspension or dissolve, producing a viscosity reduction effect, this way avoiding formation of asphaltenic conglomerates precipitation in oil wells, storage tanks, as well as keeping pipelines from being obstructed. 1. A petroleum asphaltene handler additive compound characterized by an additive composition with a melting point of −5° C. and a density of 0.86 g/ml , prepared at a temperature of 25° C. , formulated with 50% toluene , 21% methyl oleate , 21.5% methyl linoleate , 5.5% methyl palmitate and 2% methyl stearate.2. A petroleum asphaltene handler additive compound characterized because just as described in claim 1 , when applied to heavy and extra heavy oil claim 1 , said additive compound stabilizes asphaltenes by keeping them in suspension claim 1 , avoiding the formation of asphaltenic aggregates and their precipitation to the bottom of wells or storage tanks.3. A petroleum asphaltene handler additive compound characterized because just as described in claim 1 , when applied to heavy and extra heavy oil claim 1 , said additive compound has the capacity of dissolving asphaltenes.4. A petroleum asphaltene handler additive compound characterized because just as described in and claim 1 , said additive compound produces a viscosity reduction effect measured in centipoises (cP) of heavy and extra heavy oil claim 1 , from 47% to 81% applying a dose between a range of 1% to 5%.5. A petroleum asphaltene handler additive compound characterized because just as described in claim 4 , said additive compound reduces the viscosity of heavy and extra heavy oil when mixed inside the oil well or during its transportation in pipelines.6. A petroleum asphaltene handler additive compound characterized because just as described in claim 5 , the reduction in viscosity of heavy and extra heavy oil produced by ...

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05-09-2013 дата публикации

Oil Thinning Compositions And Retrieval Methods

Номер: US20130228329A1
Автор: Chesky Sheldon R.
Принадлежит:

The present invention relates to compositions of plant oil-based biodegradable crude oil thinning fluids having a performance especially suitable to reducing crude oil viscosity in extraction and retrieval operations. 1. A method to recover oil from an oil well , comprising the steps of: a) providing a formulation comprising: one or more terpenoid compounds , soy methyl esters , and glycol ether esters; b) introducing a first portion of said formulation into said oil well; and c) recovering a mixture from said oil well , said mixture comprising at least a portion of said formulation and oil from said oil well.2. The method of claim 1 , wherein said oil well is not producing oil using standard extraction techniques.3. The method of claim 1 , wherein said oil well is producing oil using standard extraction techniques.4. The method of claim 3 , wherein the method further comprises claim 3 , prior to said introducing of step b) claim 3 , the step of discontinuing extraction of materials from said oil well by said standard extraction techniques.5. The method of claim 4 , wherein the method further comprises claim 4 , after said recovering of step c) claim 4 , the step of recirculating said oil well.6. The method of claim 5 , wherein the method further comprises claim 5 , after said recirculating claim 5 , the step of returning said oil well to service and extracting oil by standard extraction techniques.7. The method of claim 1 , wherein said formulation comprises approximately 30-45 weight percent of said one or more terpenoid compounds claim 1 , approximately 30-45 weight percent of said methyl esters claim 1 , and the balance of weight percent of said glycol ether esters.8. The method of claim 1 , further comprising the step of separating said formulation from said mixture for re-use.9. The method of claim 1 , wherein said one or more terpenoid compounds comprises at least D-limonene.10. The method of claim 5 , further comprising after said recirculating step the ...

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05-09-2013 дата публикации

DERIVATIVES OF TRIS(2-HYDROXYPHENYL)METHANES, PREPARATION THEREOF AND USE THEREOF FOR MINERAL OIL PRODUCTION

Номер: US20130228332A1
Принадлежит:

Novel derivatives of tris(2-hydroxyphenyl)methanes which have, as functional groups, polyalkoxy groups unmodified or modified with terminal hydrophilic groups, preparation of such compounds and use thereof, especially for mineral oil production. 124-. (canceled)26. The compound according to claim 25 , wherein Ris a —COORgroup and Ris a methyl and/or ethyl group.27. The compound according to claim 25 , wherein Ris a —COORgroup and Ris H claim 25 , an alkali metal ion or an ammonium ion.28. The compound according to claim 25 , wherein Ris a —CH—O—(—CH—CH(R)—O—)—Rgroup where at least 50 mol % of the Rradicals present are H claim 25 , and Ris a methyl or ethyl group and z is a number from 2 to 10.29. The compound according to claim 25 , wherein compounds (I) claim 25 , as well as (IVa) radicals claim 25 , further comprise —CH—CH(R)— (IVb) radicals where Ris H claim 25 , methyl and ethyl.30. The compound according to claim 29 , wherein Ris H.31. The compound according to claim 25 , wherein the Rradicals are each independently radicals of the general formula{'br': None, 'sub': 2', 'a', '2', 'b, 'sup': 7b', '8, '—(—CH—CH(R)—O—)—(—CHCH(—COOR)—O—)—H \u2003\u2003(V)'}{'sup': 7b', '8, 'claim-ref': {'@idref': 'CLM-00025', 'claim 25'}, 'where the alkylene oxide blocks are arranged in the sequence specified, Rand Rare each as defined in and a and b are each numbers from 1 to 49, where the sum of a+b is 2 to 50.'}32. The compound according to claim 31 , wherein a is 2 to 30 and b is 1 to 20 in the formula (V) claim 31 , with the proviso that a>b.33. The compound according to claim 31 , wherein Ris H claim 31 , an alkali metal ion or an ammonium ion.34. The compound according to claim 25 , wherein X is an acidic group selected from the group consisting of carboxyl groups —COOM claim 25 , sulfo groups —SOM claim 25 , sulfate groups —OSOM claim 25 , phosphonic acid groups —POMand phosphoric acid groups —OPOM claim 25 , where M is H or a k-valent counterion 1/kY.35. The compound ...

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05-09-2013 дата публикации

Wellbore Servicing Compositions and Methods of Making and Using Same

Номер: US20130228333A1
Автор: Matthew Lynn Miller
Принадлежит: Halliburton Energy Services Inc

A method of servicing a wellbore comprising identifying lost circulation zone within a wellbore; and placing in the wellbore a composition comprising a wax and a water-based mud wherein placement of the composition reduces or prevents a loss of fluids to the lost circulation zone. A wellbore servicing fluid comprising a water-based mud, a sized calcium carbonate particle and a wax.

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05-09-2013 дата публикации

Stabilized Acid Precursor and Acid-Enzyme Formulations for Drilling Mud Cake Removal

Номер: US20130231268A1
Принадлежит: Epygen Labs FZ LLC

Enzyme formulations should stay active and devoid of all possible inactivation processes during transport and long-term storage. The stabilization of enzymatic activity, especially in presence of critical functional components for specialized application, has been a long-standing obstacle when stored over an extended period of time. One such obstacle is the stability of enzyme in presence of weak acids in formulation, which is often desired to efficiently break down biopolymer filtercake embedded in a carbonate matrix, in the open-hole section of a horizontal well, for hydrocarbon production. The invention comprises methods and compositions to enhance the long-term storage stability of an enzyme formulation consisting of an in-situ acid precursor system, where in-situ generated precursors are mainly ester compounds that dissociate by slow hydrolysis to generate organic acid, shifting the pH of the formulation outside the pKa of the enzyme protein. The methods and compositions include the addition of high concentrations of metal halide salts, a pH control additive, and a water activity reducing agent. The methods and compositions of the invention provide a high degree of stability for enzyme formulation at long-term storage conditions.

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12-09-2013 дата публикации

Increasing oil production

Номер: US20130233539A1
Принадлежит: Individual

A method of recovering petroleum from dormant oil wells or increasing the production of oil wells. An alkali or alkali earth carbonate is introduced into a water layer associated with a subterranean petroleum reservoir and/or an explosive composition is introduced into an oil layer associated with a subterranean petroleum reservoir. CO 2 gas is produced by reacting the alkali or alkali earth carbonate with an acid and/or by detonating the explosive composition.

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12-09-2013 дата публикации

Nitrogen-containing compounds as corrosion inhibitors

Номер: US20130233543A1
Принадлежит: AKZO NOBEL N.V.

The present invention relates to nitrogen-containing hydroxyethyl substituted compounds to be used as corrosion inhibitors for metal surfaces, for example in aqueous systems and in particular in oil-field applications, e.g. in oil or gas wells, and which could be used under sweet-well conditions as well as under sour-well conditions. It may also be used in oil-field acidizing and fracture-acidizing well stimulation treatment. The compounds belong to the group of partly ethoxylated fatty alkylamines, partly ethoxylated alkyletheramines and partly or fully hydroxyethyl substituted alkylamidopropylamines. The corrosion inhibitors have the formula (I) where R is a hydrocarbyl or an acyl group having 14-24 carbon atoms, or the group R′OCHCHCHwhere R′ is a hydrocarbyl group with 14-24 carbon atoms; X is hydrogen, CHOH or the group Y is hydrogen or CHOH and n is 0-3, with the proviso that at least one of the symbols X and Y is CHOH, at most one of the symbols X is n is at least one when R is an acyl group, and when R is a hydrocarbyl group or the group R′OCHCHCHat least one of the symbols X and Y is hydrogen. 113.-. (canceled)15. The corrosion inhibiting composition of claim 14 , where R is a hydrocarbyl group having 16-22 carbon atoms.16. The corrosion inhibiting composition of claim 14 , where n is 0-2.17. The corrosion inhibiting composition of claim 14 , where n is 1-2.18. The corrosion inhibiting composition of claim 14 , where R is the group R′OCHCHCH claim 14 , where R′ has the same meaning as in .19. The corrosion inhibiting composition of wherein said aqueous environment is acidic.20. The corrosion inhibiting composition of wherein said oilfield application is under sweet-well conditions.21. The corrosion inhibiting composition of wherein said oilfield application is under sour-well conditions.22. The corrosion inhibiting composition of claim 14 , further comprising a water-miscible solvent.23. The corrosion inhibitor of which comprises a mixture of ethoxylated ...

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12-09-2013 дата публикации

System and process for inhibitor injection

Номер: US20130233544A1
Принадлежит: HRD Corp

A method for introducing inhibitor into a fluid to be treated by forming a dispersion comprising droplets, particles, or gas bubbles of inhibitor dispersed in a continuous phase of a carrier, wherein forming the dispersion comprises subjecting a mixture of the inhibitor and the carrier to a shear rate of greater than about 20,000 s −1 in a high shear device comprising at least one generator comprising a rotor and a complementarily-shaped stator, wherein the rotor and the stator each comprise grooves, and wherein the grooves of the stator and the grooves of the rotor of each generator are disposed in alternating directions, and using at least a portion of the dispersion to inhibit corrosion.

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12-09-2013 дата публикации

Methods for Servicing Subterranean Wells

Номер: US20130233553A1
Принадлежит:

Methods for controlling fluid flow through one or more pathways in one or more rock formations penetrated by a borehole in a subterranean well, comprise injecting into or adjacent to the formation a treatment fluid comprising at least one polysaccharide polymer; at least one crosslinker; and fibers, or a mixture of fibers and particles. The fluids are pumped into the well through a tubular body that comprises at least one flow restriction. Shearing of the treatment fluid as it passes through the flow restriction causes the viscosity to decrease, allowing the fibers to form masses that migrate to formation-rock openings such as pores, cracks, fissures and vugs. As a result, the fibrous masses are useful for curing lost circulation, providing fluid-loss control and as diverting agents. 1. A method for controlling fluid flow through one or more pathways in one or more rock formations penetrated by a borehole in a subterranean well , comprising:i. preparing a treatment fluid comprising (a) at least one polysaccharide polymer, (b) at least one crosslinker, and (c) fibers or a mixture of fibers and particles;ii. pumping the treatment fluid into the well through a tubular body that comprises at least one flow restriction; andiii. injecting the treatment fluid into or adjacent to the formation.2. A method for curing lost circulation in a subterranean well penetrated by a borehole comprising:i. preparing a treatment fluid comprising (a) at least one polysaccharide polymer, (b) at least one crosslinker, and (c) fibers or a mixture of fibers and particles;ii. pumping the treatment fluid into the well through a tubular body that comprises at least one flow restriction; andiii. injecting the treatment fluid into or adjacent to the formation.3. A method of treating a subterranean formation penetrated by a wellbore , comprising:i. preparing a treatment fluid comprising (a) at least one polysaccharide polymer, (b) at least one crosslinker, and (c) fibers or a mixture of fibers and ...

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12-09-2013 дата публикации

Consolidation

Номер: US20130233623A1
Принадлежит: BP Exploration Operating Co Ltd

A method of strengthening subterranean formation by drilling and completing a wellbore penetrating at least one unconsolidated or weakly consolidated formation, the method comprising: (a) drilling at least one interval of the wellbore that penetrates the unconsolidated or weakly consolidated formation using a drilling mud comprising a base fluid comprising an aqueous phase containing up to 25% weight by volume (% w/v) of a water soluble silicate, wherein the drilling mud has an acid-soluble particulate bridging solid suspended therein that is formed from a salt of a multivalent cation, wherein the salt of the multivalent cation is capable of providing dissolved multivalent cations when in the presence of an acid; (b) subsequently introducing a breaker fluid containing an acid and/or an acid precursor into the wellbore; (c) allowing the breaker fluid to soak in the interval that penetrates the unconsolidated or weakly consolidated formation for a predetermined period and strengthening formation by reacting with silicate now present in formation; and (d) removing the breaker fluid.

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19-09-2013 дата публикации

Solubilizing surfactants into supercritical carbon dioxide for enhanced oil recovery

Номер: US20130240046A9
Принадлежит: Dow Global Technologies LLC

Embodiments of the present disclosure include a process and a system for solubilizing a surfactant in supercritical carbon dioxide that include providing a turbulent flow of the supercritical carbon dioxide into which the surfactant solubilizes and injecting the surfactant into the turbulent flow of the supercritical carbon dioxide to achieve a Jet Mixing Number of 0.01 to 1.0. In one or more embodiments, a pump provides turbulent flow to supercritical carbon dioxide moving through at least a portion of piping, and an injector associated with the piping conveys the surfactant through surfaces defining a port in the injector to inject the surfactant into the turbulent flow of the supercritical carbon dioxide so as to achieve the Jet Mixing Number of 0.01 to 1.0.

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19-09-2013 дата публикации

EXTRACTION OF HYDROCARBONS FROM HYDROCARBON-CONTAINING MATERIALS AND/OR PROCESSING OF HYDROCARBON-CONTAINING MATERIALS

Номер: US20130240206A1
Принадлежит: Green Source Energy LLC

A method of extracting hydrocarbon-containing organic matter from a hydrocarbon-containing material includes the steps of providing a first liquid comprising a turpentine liquid; contacting the hydrocarbon-containing material with the turpentine liquid to form an extraction mixture; extracting the hydrocarbon material into the turpentine liquid; and separating the extracted hydrocarbon material from a residual material not extracted. 1. A method for increasing recovery of hydrocarbon-containing organic matter from a production well coupled to a hydrocarbon-containing sub-surface formation , the subsurface formation comprising hydrocarbon-containing material , the method comprising the steps of extracting the hydrocarbon-containing organic matter by a process comprising:providing an injection well, said injection being in fluid communication with the sub-surface formation;providing a substantially surfactant-free first liquid comprising a non-aqueous hydrocarbon-extracting liquid comprising a turpentine liquid;injecting the hydrocarbon-extracting liquid through the injection well and into the formation, wherein the hydrocarbon-extracting liquid and the hydrocarbon-containing organic matter from the hydrocarbon containing sub-surface formation form an extraction mixture comprising at least a portion of the extraction mixture hydrocarbon-containing organic matter in at least a portion of the hydrocarbon-extracting liquid;recovering the extraction mixture from the formation through the production well; andseparating the extraction mixture to produce a hydrocarbon product stream and a hydrocarbon-extracting liquid stream.2. The method of claim 1 , wherein said turpentine liquid is selected from the group consisting of natural turpentine claim 1 , synthetic turpentine claim 1 , mineral turpentine claim 1 , pine oil claim 1 , α-pinene claim 1 , β-pinene claim 1 , α-terpineol claim 1 , β-terpineol claim 1 , γ-terpineol claim 1 , terpene resins claim 1 , α-terpene claim 1 , ...

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