ИНГИБИТОРЫ КОРРОЗИИ ДЛЯ ВОДНЫХ СИСТЕМ

Изобретение относится к способу ингибирования коррозии в водных системах. В промышленную водную систему добавляют состав на основе фосфиноянтарной кислоты, содержащий моно-, бис- и олигомерные аддукты фосфиноянтарной кислоты. Состав на основе фосфиноянтарной кислоты содержит 36-49 молярных процентов бис-аддуктов фосфиноянтарной кислоты и 27, 28, 29, 31, 34,6 или 35 молярных процентов олигомерных аддуктов фосфиноянтарной кислоты. Технический эффект - повышение эффективности ингибирования коррозии. 2 з.п. ф-лы, 3 табл.

ВОДОРАСТВОРИМЫЙ ИНГИБИТОР КОРРОЗИИ ДЛЯ ЗАЩИТЫ ЭКСПЛУАТАЦИОННЫХ ТРУБ И ТРУБОПРОВОДОВ ДЛЯ ПРИРОДНОГО ГАЗА, А ТАКЖЕ СПОСОБ ЕГО ПОЛУЧЕНИЯ

Изобретение относится к способам получения водорастворимых ингибиторов коррозии для защиты эксплуатационных трубопроводов для природного газа. Получают компонент а) – смесь модифицированных производных имидазолина, проводят реакцию конденсации диэтилентриамина с жирными кислотами и алифатическими дикарбоновыми кислотами при температуре не менее 140° C. Получают смесь аминоамидов с кислотным числом <10 мг КОН/г. При температуре выше 180° C проводят реакцию конденсации. Получают смесь соединений с кислотным числом <1 мг КОН/г в количестве 0,1-50 мас.%. Нейтрализуют смесь при комнатной температуре в реакционной среде, содержащей компонент е) - алифатические спирты в количестве 15-99,7 мас.%, алифатической и/или ароматической монокарбоновой кислотой в количестве 0,05-25 мас.%. Получают конечный продукт и добавляют к компоненту а) в количестве 0,15-75 мас.% и компоненту е) следующие компоненты: b) - оксиэтиленированные жирные амины, с) - подщелачивающий агент и f) - противовспениватель. Изобретение ...

СПОСОБ ПОДАВЛЕНИЯ ОБРАСТАНИЯ МЕТАЛЛИЧЕСКИХ ПОВЕРХНОСТЕЙ С ИСПОЛЬЗОВАНИЕМ АГЕНТА ДЛЯ МОДИФИКАЦИИ ПОВЕРХНОСТИ

Изобретение относится к способам предотвращения обрастания металлических труб, трубопровода или емкости в ходе добычи флюидов из подземного пласта. Предложен способ подавления вызываемого загрязнениями обрастания металлических труб, трубопровода или емкости в подземном пласте или отводимых из подземного пласта или подводимых к нему, при этом способ включает: (а) нанесение на оксид металла на поверхности металлических труб, трубопровода или емкости агента для модификации поверхности, который содержит якорный фрагмент и гидрофобный хвост, причем якорный фрагмент представляет собой металл или производное органической фосфорсодержащей кислоты, а гидрофобный хвост представляет собой кремнийорганический материал, фторированный углеводород или оба компонента – кремнийорганический материал и фторированный углеводород, (б) присоединение якорного фрагмента, по крайней мере, к части оксида металла, и (в) подавление обрастания компонентами флюида труб, трубопровода или емкости за счет воздействия гидрофобного ...

ИНГИБИТОР КОРРОЗИИ, ОБЛАДАЮЩИЙ ЭФФЕКТОМ ИНГИБИРОВАНИЯ ГИДРАТООБРАЗОВАНИЯ, СПОСОБ ЕГО ПОЛУЧЕНИЯ И ЕГО ПРИМЕНЕНИЕ

Настоящее изобретение относится к галогенированной соли пиридиния для обеспечения защиты против коррозии. Галогенированную соль пиридиния получают способом, включающим добавление соединения на основе бипиридина, соединения на основе пиридина и галогенированного углеводорода к растворителю и их смешивание в достаточной степени для проведения реакции с получением галогенированной соли пиридиния. При этом соединение на основе бипиридина представляет собой любое соединение, выбранное из 4,4-бипиридина и 2,2-бипиридина, соединение на основе пиридина представляет собой любое соединение, выбранное из пиридина и 2,6-диметилпиридина, и галогенированный углеводород имеет структурную формулу X-R6-X, где R6 выбран из алкиларила, который содержит 8-20 атомов углерода, и X выбран из фтора, хлора, брома и йода. Также предложены ингибитор коррозии, обладающий эффектом ингибирования гидратообразования, способ его получения и его применение. Изобретение позволяет получить ингибитор коррозии, обладающий эффектом ...

ИНГИБИТОРЫ КОРРОЗИИ ДЛЯ ВОДНЫХ СИСТЕМ

... 1. Способ ингибирования коррозии в водных системах, включающий добавление в систему состава, характеризующегося содержанием моно-, бис- и олигомерных аддуктов фосфиноянтарной кислоты. 2. Способ по п.1, отличающийся тем, что бис-аддукт присутствует в продукте реакции в количествах 20-85 молярных процентов на основе фосфора. 3. Способ по п.1, отличающийся тем, что водная система является промышленной водной системой. 4. Способ по п.1, отличающийся тем, что промышленная водная система является системой водяного охлаждения. 5. Способ по п.1, отличающийся тем, что дополнительно включает добавление в водную систему эффективного количества одного или нескольких ингибиторов коррозии черных металлов, ингибиторов коррозии желтых металлов, ингибиторов образования твердого осадка, диспергаторов, биоцидов и добавок промышленной водной системы. 6. Способ получения состава, характеризующегося содержанием моно-, бис- и олигомерных аддуктов фосфиноянтарной кислоты, характеризующийся i) добавлением гипофосфита ...

СОСТАВЫ ИНГИБИТОРОВ КОРРОЗИИ ДЛЯ ПОДАВЛЕНИЯ КОРРОЗИИ В СРЕДАХ, СОДЕРЖАЩИХ СВОБОДНУЮ СЕРУ И/ИЛИ ПОЛИСУЛЬФИДЫ

СПОСОБ ПОДАВЛЕНИЯ ОБРАСТАНИЯ МЕТАЛЛИЧЕСКИХ ПОВЕРХНОСТЕЙ С ИСПОЛЬЗОВАНИЕМ АГЕНТА ДЛЯ МОДИФИКАЦИИ ПОВЕРХНОСТИ

КОМПОЗИТЫ С РЕГУЛИРУЕМЫМ ВЫСВОБОЖДЕНИЕМ РЕАГЕНТОВ ДЛЯ ОБРАБОТКИ СКВАЖИН

... 1. Композит для обработки скважин, содержащий реагент для обработки скважин и обожженный пористый оксид металла, в котором пористость и проницаемость обожженного пористого оксида металла является такой, что реагент для обработки скважин адсорбируется во внутрипоровых пространствах пористого оксида металла, и в котором, кроме того:(a) площадь поверхности обожженного пористого оксида металла составляет от приблизительно 1 м/г до приблизительно 10 м/г;(b) диаметр частиц обожженного пористого оксида металла составляет от приблизительно 0,1 до приблизительно 3 мм; и(c) объем пор обожженного пористого оксида металла составляет от приблизительно 0,01 до приблизительно 0,10 г/см.2. Композит для обработки скважин по п. 1, который содержит от приблизительно 1 до приблизительно 50 мас.% реагента для обработки скважин.3. Композит для обработки скважин по п. 1, в котором адсорбент дополнительно содержит диоксид кремния.4. Композит для обработки скважин по п. 1, в котором реагент для обработки скважин ...

A sulfosuccinate corrosion inhibitor

A sulfosuccinate is described for use as a corrosion inhibitor. The sulfosuccinate may be used to inhibit the corrosion of a metal component that is, or will be, in contact with an aqueous fluid, in order to prevent or reduce corrosion of the metal component. The sulphosuccinate may be a mono or diester. The sulfosuccinate may be used to inhibit corrosion of a metal component in an industrial aqueous system, such as a hydrocarbon plant; a chemical plant; a water plant; or a paper manufacturing plant, and in particular in an oilfield system or a downstream oil-related system. The sulphosuccinate may be derived from a fatty alkanolamide, a fatty alcohol a fatty alkoxylated alcohol and alkoxylated terpene group or an alkyl polyglucoside.

Well treatment

Acrylonitrile-based sulfur scavenging agents for use in oilfield operations

Synergistic sulfide scavenging additives for use in oilfield operations

Systems, compositions, and methods for synergistic additives for use in the scavenging of sulfur-containing compounds encountered in oilfield operations are provided. In one embodiment, the methods comprise injecting a sulfide scavenging additive that does not comprise a significant amount of an aldehyde into at least a portion of a subterranean formation where one or more sulfur-containing species are present; and injecting a synergistic additive comprising at least one base into at least the portion of the subterranean formation.

Corrosion inhibitors

OIL FIELD CORROSION INHIBITION

An inhibitor formulation including the product obtained by reacting maleic anhydride or fumaric acid with fatty acids containing unsaturation in the presence of a suitable catalyst, such as iodine, clay, or silica, is disclosed to provide improved corrosion inhibition in oil field equipment and piping over conventional dimer/trimier based inhibitor formulations.

Corrosion inhibition for aqueous brines

A method and composition for reducing the corrosion effect of aqueous mediums such as brines on ferrous metals by incorporating in the brine an effective amount of a mixture of a sulfur compound wherein the oxidation state of the sulfur is zero or less and a reducing sugar.

Fluid chlorination for example employed in a water injection system

A water treatment apparatus for use in for example a water injection system for an off-shore oil bearing formation to process sea water so that the chlorination of the sea water can be controlled. The apparatus comprises a membrane made up from first and second electrically conductive fluid permeable layers which are separated and electrically insulated from each other by a fluid permeable electrically insulating layer. An electrical potential is applied between the first and second layers, and sea water is pumped across the membrane. The chemical characteristics of the sea water passing through the membrane are monitored to provide a control signal for controlling the potential applied between the first and second layers, thereby enabling the control of for example the redox potential of the sea water emerging from the membrane. Furthermore, the membrane and electrically insulating layer provide coarse filtration of the sea water passing through the membrane. ...

Nitrogen-containing compounds as corrosion inhibitors

Porous composites containing hydrocarbon-soluble well treatment agents and methods for using the same

Water removal from anti-agglomerate LDHIs

Inhibition of bacterial growth in pipelines

Use fresh water or water with sufficiently reduced salinity to trigger burst of bacterial cell wall due to osmotic pressure gradient. Combine the freshwater with conventional biocide treatment and pigging to increase the likelihood of killing the bacteria responsible for reservoir souring.

Environmentally friendly corrosion inhibitors for high temperature applications

Methods of inhibiting corrosion of metal surfaces by aqueous acids are described. The methods include combining an effective amount of a corrosion inhibitor composition with an aqueous acid solution to form an inhibited acid solution and contacting a metal surface with the inhibited acid solution. The corrosion inhibitor composition includes an aromatic ketone or a salt thereof.

PREVENTION OF HYDROGEN EMBRITTLEMENT OF METALS IN CORROSIVE ENVIRONMENTS

Corrosion inhibited high density fluid compositions

A corrosion inhibited, clear, high- density composition capable of long term use as a well servicing fluid under conditions of elevated temperature comprises a solution of zinc bromide, calcium bromide, and, optionally, calcium chloride in water having a density in the range of 15.0 to 20.0 ppg and a corrosion inhibiting amount of a member selected from the group consisting of ammonium thioglycolate, calcium thioglycolate, thioglycerol and mixtures thereof.

Well treating compositions for slow release of treatment agents and methods of using the same

Oil thinning compositions and oil recovery methods

A formulation comprises one or more terpenoids, soy methyl esters and glycol ether esters. The terpenoid may be D-limonene. These compositions of plant oil-based biodegradable crude oil thinning fluids have a performance especially suitable to reducing crude oil viscosity in extraction and retrieval operations. Also shown is a method to recover oil from an oil well comprising (a) providing the above formulation; (b) introducing a first portion of the formulation into the oil well; (c) recovering a mixture from the oil well comprising at least a portion of the formulation and oil from the oil well. The method for producing the formulation is also shown using a stainless steel reactor and one or more terpenoids, soy methyl esters, glycol ether esters, a first inorganic catalyst and a second inorganic catalyst.

Water removal from anti-agglomerate LDHIS

Oil field chemical delivery fluids, methods for their use in the targeted delivery of oil field chemicals to subterranean hydrocarbon reservoirs and methods

Methods and systems for wellbore remediation

Catalyzed polyamine sulfide scavengers and methods of use in subterranean treatment fluids

Improved methods and additives for eliminating or reducing concentrations of hydrogen sulfide or soluble sulfide ions for use in subterranean formations and fluids are provided. In one embodiment, the methods comprise: providing a treatment fluid comprising an oil-based liquid and a sulfide scavenging additive comprising one or more polyaliphatic amines and a catalyst comprising one or more quaternary ammonium salts; introducing the treatment fluid into at least a portion of a subterranean formation; and allowing the sulfide scavenging additive to interact with hydrogen sulfide or sulfide ions present in the treatment fluid.

Method

Decreasing corrosion on metal surfaces with apatite forming components

Corrosion to a metal surface in contact with corrosion forming components within an aqueous-based fluid system may be decreased, prevented, and/or inhibited by contacting the metal surface(s) with apatite forming components and forming at least one apatite species on the surface with the apatite forming components. The apatite forming components may be or include phosphates, organophosphates and combinations thereof. In a non- limiting embodiment, the apatite forming components may further include fluorides, chlorides, calcium, and combinations thereof.

Colloidal dispersions (SOLS) for weighting agents in fluids

A sag-resistant fluid, such as a drilling fluid, a completion fluid, or a spacer fluid, including a colloidal suspension that includes a continuous liquid phase and a solid phase suspended in the continuous liquid phase. The solid phase includes a plurality of particles, having an average diameter of the plurality of particles less than about 1000 nm. The the sag-resistant fluid has a density of from about 7 to about 30 Ibm/gal, and exhibits a density variation of less than about 0.5 Ibm/gal over a time period of at least about 16 hours. A method including circulating the sag-resistant fluid through a well.

Corrosion inhibitor

A method of making an inhibited acidic aqueous fluid

Inhibiting hydrocarbon hydrate agglomeration

A process for inhibiting the formation of gas hydrates in a hydrocarbon fluid comprising adding to the hydrocarbon fluid, a gas hydrate anti-agglomerate which is a biodegradable anti-agglomerant derived from a naturally occurring substance.

Rotary steerable drilling tool and method

Oxyalkylated polybenzoxazine emulsion breakers

A demulsifier composition comprises an oxy alkylated polybenzoxazine having repeating units of Formula (I): wherein R1 is hydrogen, a C1-30 alkyl, a C3-30 cycloalkyl, a C6-30 aryl, a C7-30 alkylarylene, a C7-30 arylalkyl, a C5-30 heteroaryl, or a C3-30 heterocycloalkyl; R2 is a C1-30 alkyl, a C3-30 cycloalkyl, a C6-30 aryl, a C7-30 alkylarylene, a C7-30 arylalkyl, a C5-30 heteroaryl, or a C3-30 heterocycloalkyl; R3 is hydrogen or a C1-10 alkyl; each occurrence of R4 is independently hydrogen or a C1- 5 alkyl; and p is at least 1.

Fatty amides and derivatives from natural oil metathesis

Fatty amines, amidoamines and their derivatives from natural oil metathesis

Extraction of hydrocarbons from hydrocarbon-containing materials and/or processing of hydrocarbon-containing materials.

Inhibiting corrosion and scaling of surfaces contacted by sulfur-containing materials.

Fatty amines, amidoamines and their derivatives from natural oil metathesis

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

FATTY AMINES, AMIDOAMINES, AND THEIR DERIVATIVES FROM NATURAL OIL METATHESIS

Inhibiting corrosion and scaling of surfaces by sulfur-containing materials

FATTY AMIDES AND DERIVATIVES FROM NATURAL OIL METATHESIS

Inhibiting corrosion and scaling of surfaces contacted by sulfur-containing materials.

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

Fatty amides and derivatives from natural oil metathesis

Extraction of hydrocarbons from hydrocarbon-containing materials and/or processing of hydrocarbon-containing materials.

Salts of mercaptoacides and imidazolines like carbonic corrosion inhibitors of iron and ferrous metals

Inhibitor compositions.

Hydrogen sulfide scavengers in fuels hydrocarbons and water using amidines and polyamidines

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

Fatty amides and derivatives from natural oil metathesis

Fatty amines, amidoamines and their derivatives from natural oil metathesis

Inhibiting corrosion and scaling of surfaces contacted by sulfur-containing materials.

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

Extraction of hydrocarbons from hydrocarbon-containing materials and/or processing of hydrocarbon-containing materials.

USE FROM WATER-SOLUBLE ALKANE SULFONE ACIDS TO THE INCREASE OF THE PERMEABILITY OF UNDERGROUND ONES, CARBONATI OIL AND/OR NATURAL GAS-PROMINENT GESTEINSFORMATIONEN AND FOR THE RELEASE OF CARBONATI AND/OR CARBONATHALTIGEN IMPURITIES DURING THE OIL PROMOTION

PROCEDURE FOR THE PRECIPITATION PREVENTION WATER AND COMPOSITIONS, THE POLYMERS FOR THE PREVENTION OF THE PRECIPITATION CONTAINING, DISPERSED FROM SALTS IN OEL.

MEANS TO THE CORROSION PREVENTING

PROCEDURE FOR THE PROTECTION OF METAL SURFACES IN RELATION TO CORROSION IN LIQUID OR GASEOUS MEDIA

PROCEDURE FOR THE TREATMENT OF A SOURCE OF OIL

NEW PHOSPHINO DERIVATIVES

USE FROM WATER-SOLUBLE ALKANE SULFONE ACIDS TO THE INCREASE OF THE PERMEABILITY OF UNDERGROUND ONES, CARBONATI OIL AND/OR NATURAL GAS-PROMINENT GESTEINSFORMATIONEN AND FOR THE RELEASE OF CARBONATI AND/OR CARBONATHALTIGEN IMPURITIES DURING THE OIL PROMOTION

USE FROM WATER-SOLUBLE ALKANE SULFONE ACIDS TO THE INCREASE OF THE PERMEABILITY OF UNDERGROUND ONES, CARBONATI OIL AND/OR NATURAL GAS-PROMINENT GESTEINSFORMATIONEN AND FOR THE RELEASE OF CARBONATI AND/OR CARBONATHALTIGEN IMPURITIES DURING THE OIL PROMOTION

USE FROM WATER-SOLUBLE ALKANE SULFONE ACIDS TO THE INCREASE OF THE PERMEABILITY OF UNDERGROUND ONES, CARBONATI OIL AND/OR NATURAL GAS-PROMINENT GESTEINSFORMATIONEN AND FOR THE RELEASE OF CARBONATI AND/OR CARBONATHALTIGEN IMPURITIES DURING THE OIL PROMOTION

USE FROM WATER-SOLUBLE ALKANE SULFONE ACIDS TO THE INCREASE OF THE PERMEABILITY OF UNDERGROUND ONES, CARBONATI OIL AND/OR NATURAL GAS-PROMINENT GESTEINSFORMATIONEN AND FOR THE RELEASE OF CARBONATI AND/OR CARBONATHALTIGEN IMPURITIES DURING THE OIL PROMOTION

USE FROM WATER-SOLUBLE ALKANE SULFONE ACIDS TO THE INCREASE OF THE PERMEABILITY OF UNDERGROUND ONES, CARBONATI OIL AND/OR NATURAL GAS-PROMINENT GESTEINSFORMATIONEN AND FOR THE RELEASE OF CARBONATI AND/OR CARBONATHALTIGEN IMPURITIES DURING THE OIL PROMOTION

USE FROM WATER-SOLUBLE ALKANE SULFONE ACIDS TO THE INCREASE OF THE PERMEABILITY OF UNDERGROUND ONES, CARBONATI OIL AND/OR NATURAL GAS-PROMINENT GESTEINSFORMATIONEN AND FOR THE RELEASE OF CARBONATI AND/OR CARBONATHALTIGEN IMPURITIES DURING THE OIL PROMOTION

USE FROM WATER-SOLUBLE ALKANE SULFONE ACIDS TO THE INCREASE OF THE PERMEABILITY OF UNDERGROUND ONES, CARBONATI OIL AND/OR NATURAL GAS-PROMINENT GESTEINSFORMATIONEN AND FOR THE RELEASE OF CARBONATI AND/OR CARBONATHALTIGEN IMPURITIES DURING THE OIL PROMOTION

USE FROM WATER-SOLUBLE ALKANE SULFONE ACIDS TO THE INCREASE OF THE PERMEABILITY OF UNDERGROUND ONES, CARBONATI OIL AND/OR NATURAL GAS-PROMINENT GESTEINSFORMATIONEN AND FOR THE RELEASE OF CARBONATI AND/OR CARBONATHALTIGEN IMPURITIES DURING THE OIL PROMOTION

Sulphydryl acid and imidazoline salts as inhibitors of carbon corrosion of iron and ferrous metals

Methods, products and uses relating to scavenging of acidic sulfide species

The use of the combination of (a) an imine compound and (b) a compound including a soft electrophilic centre to scavenge and retain acidic sulfide species at a higher temperature and/or scavenge acidic sulfide species at an increased rate compared to that achieved using the imine compound alone.

POLYMER COMPOSITION CONTAINING LEACHABLE REAGENT

Microemulsion containing oilfield chemicals useful for oil and gas field applications

Use of polyester polyamine and polyester polyquaternary ammonium compounds as corrosion inhibitors

The present invention relates to the use of a polyesteramine or a polyester polyquaternary ammonium compound as a corrosion inhibitor for metal surfaces, and to a method for protecting a metal surface from corrosion by contacting the metal surface with said corrosion inhibitor.

Mercaptoalcohol corrosion inhibitors

Oil well treatment

Synergistic sulfide scavenging additives for use in oilfield operations

Systems, compositions, and methods for synergistic additives for use in the scavenging of sulfur-containing compounds encountered in oilfield operations are provided. In one embodiment, the methods comprise injecting a sulfide scavenging additive that does not comprise a significant amount of an aldehyde into at least a portion of a subterranean formation where one or more sulfur-containing species are present; and injecting a synergistic additive comprising at least one base into at least the portion of the subterranean formation.

Organic disulfide based corrosion inhibitors

Disclosed are corrosion inhibitor compounds and compositions useful in applications relating to the production, transportation, storage, and separation of crude oil and natural gas. Also disclosed are methods of using the compounds and compositions as corrosion inhibitors, particularly in applications relating to the production, transportation, storage, and separation of crude oil and natural gas.

Controlling microbial activity and growth in mixed phase system

A system and methods for controlling microbial activity and growth in a mixed phase system. The method includes providing a rare-earth compound. The method also includes injecting the rare-earth compound into a mixed phase system, wherein the rare earth compound binds with a phosphate in an aqueous phase to adsorb the phosphate. The method also includes separating the rare-earth compound from the mixed phase system.

Systems and methods for generation of reactive oxygen species and applications thereof

Reactive oxygen species formulations as well as methods for making and using such formulations. Reactive oxygen species formulations comprising one or more parent oxidants, such as peroxides, or peroxyacids, and one or more reactive oxygen species. (ROS). The formulations optionally contain in addition one or more reactive species other than ROS. The reactive oxygen species and other reactive species when present provide chemical reactivity, oxidative activity and/or antimicrobial activity not provided otherwise by the parent oxidant.

Methods and systems for suppressing corrosion of sensitive metal surfaces

Certain metal surfaces are often unable to be effectively contacted with fluids containing hydrofluoric acid due to significant corrosion issues. Titanium and titanium alloy surfaces represent but one example. Corrosion inhibitor compositions comprising boric acid and an N-(phosphonoalkyl)iminodiacetic acid or any salt thereof can be used to suppress metal corrosion, including that taking place on titanium and titanium alloy surfaces. Methods for suppressing corrosion of a metal surface can comprise: contacting a metal surface with a corrosive environment, the metal surface comprising titanium or a titanium alloy and the corrosive environment comprising hydrofluoric acid; introducing a corrosion inhibitor composition to the corrosive environment, the corrosion inhibitor composition comprising boric acid and an N-(phosphonoalkyl)iminodiacetic acid or any salt thereof; contacting the metal surface with the corrosion inhibitor composition; and allowing the corrosion inhibitor composition to ...

Polyester polyamine and polyester polyquaternary ammonium corrosion inhibitors

The present invention relates to the use of a product obtainable by the reaction of a fatty acid, or mixture of acids, having the formula R ...

Corrosion inhibiting compositions to mitigate corrosion in environments containing elemental sulfur and/or polysulfides

A corrosion inhibiting composition is provided which comprises a salt of a fatty acid-amine condensate and an aromatic solvent. The composition can be used in reducing, inhibiting or preventing corrosion of a metal surface used in recovery, transportation, refining or storage of a hydrocarbon fluid containing elemental sulfur or polysulfide.

Inhibiting corrosion in a downhole environment

A method and system for inhibiting corrosion of a surface in a well including introducing a composition into the well, the composition comprising an acidic medium and Dihydrogen (ethyl) [4- [4- [ethyl(3 -sulphonatobenzyl)amino] (4-hydroxy-2- sulphonatobenzhydrylidene]cyclohexa-2,5-dien-l-ylidene](3- sulphonatobenzyl)ammonium), contacting the metal surface with the composition, and inhibiting corrosion of the metal surface with the Dihydrogen (ethyl)[4-[4-[ethyl(3- sulphonatobenzyl)amino](4-hydroxy-2-sulphonatobenzhydrylidene]cyclohexa-2,5-dien- 1 -ylidene] (3 -sulphonatobenzyl)ammonium).

Decreasing corrosion on metal surfaces with apatite forming components

Corrosion to a metal surface in contact with corrosion forming components within an aqueous-based fluid system may be decreased, prevented, and/or inhibited by contacting the metal surface(s) with apatite forming components and forming at least one apatite species on the surface with the apatite forming components. The apatite forming components may be or include phosphates, organophosphates and combinations thereof. In a non- limiting embodiment, the apatite forming components may further include fluorides, chlorides, calcium, and combinations thereof.

The preparation method and application of a Mannich base quaternary ammonium salt

Abstract The invention provides a preparation method and application of a Mannich base quaternary ammonium salt. The invention also provides the application of the Mannich base quaternary ammonium salt compound in the corrosion and sterilization of steel pipelines in oil exploitation. As a bactericidal and corrosion inhibitor, the Mannich base quaternary ammonium salt compound of the invention can simplify the complicated combination of a variety of corrosion inhibitors and fungicides, it has excellent corrosion inhibition performance and certain bactericidal ability, simple synthesis method, mild reaction conditions, low cost, and various available raw material source.

Corrosion inhibition

CORROSION INHIBITOR FROM REACTION OF ALDEHYDE WITH AMINE, PREFERABLEY QUATERNISED

Process for treating an oil well

Coated products and use thereof in oil fields

Use of decahydro pyrazino (2,3-b) pyrazine for the reduction of the proportion of free or combined hydrogen sulphide present in a fluid

CORROSION INHIBITION OF AQUEOUS BRINES

CORROSION INHIBITORS

COATED TOOLS FOR USE IN OIL WELL PIPES

WELL TREATMENT AND COMPOSITION THEREFOR

Water removal from anti-agglomerate ldhis

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.

Polymeric corrosion inhibitors

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.

Corrosion inhibitors for oil and gas applications

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.

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

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.

Compositions and Methods for Protecting Metal Surfaces from Corrosion

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 ...

Compositions and Methods for Protecting Metal Surfaces from Corrosion

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.

Compositions and Methods for Protecting Metal Surfaces from Corrosion

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 ...

Composition and Methods for Protecting Metal Surfaces from Corrosion

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 ...

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

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).

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

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. ...

Nitrogen-containing compounds as corrosion inhibitors

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 ...

System and process for inhibitor injection

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.

Constraining Pyrite Activity in Shale

Degeneration of shale caused by oxygen in aqueous drilling, fracturing and completion fluids is minimized by introducing imidazolines modified so that they will be attracted efficiently to pyrites in the shale, thereby forming a protective coating on the pyrites. Inhibiting oxidation of the pyrites sharply reduces physical degradation of the shale, and the generation of undesirable oxides, in the presence of drilling, fracturing and completion fluids carrying oxygen. The imidazoline is an ionic salt of a monocarboxylic acid. 1. (canceled)2. (canceled)3. (canceled)4. (canceled)5. (canceled)6. (canceled)7. (canceled)8. (canceled)9. (canceled)10. (canceled)11. (canceled)12. (canceled)13. (canceled)14. (canceled)15. (canceled)16. (canceled)17. (canceled)18. (canceled)19. (canceled)20. (canceled)22. Method of wherein said linear monocarboxylic acid (b) comprises oleic acid.23. Method of wherein said linear monocarboxylic acid (b) comprises acetic acid.24. Method of wherein Rcomprises a residue of carboxylic acid having 16-19 carbon atoms and carboxylic acid (b) comprises acetic acid.25. Method of wherein Rcomprises a residue of a carboxylic acid having 16-19 carbon atoms and carboxylic acid (b) comprises butyric acid.26. Method of wherein said ionic salt is added to said fluid in an amount to provide 0.1% to 5% by weight of said imidazoline in said fluid.27. Method of including adding to said fluid 0.1% to 2% by weight of a viscosity enhancing polymer.30. Method of wherein n is 1 and y is 0.31. Method of wherein R is derived from tall oil.33. The hydrocarbon bearing formation of wherein said aqueous fracturing fluid includes 0.1% to 2% by weight of a viscosity enhancing polymer.34. The hydrocarbon bearing formation of wherein said aqueous fracturing fluid includes a proppant. The present application is a divisional of U.S. Nonprovisional patent application Ser. No. 13/198,847, filed Aug. 5, 2011. The prior application is incorporated by reference herein.In the recovery ...

CORROSION INHIBITORS FOR OIL AND GAS APPLICATIONS

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. 3. The corrosion inhibitor composition of claim 2 , comprising (1) claim 2 , (2) claim 2 , (3) claim 2 , (4) claim 2 , (5) claim 2 , and (6).4. The corrosion inhibitor of claim 1 , further comprising at least one dispersant.5. The corrosion inhibitor of claim 4 , wherein the at least one dispersant comprises at least one oxyalkylate polymer.6. The corrosion inhibitor of claim 1 , further comprising at least one solvent.7. The corrosion inhibitor of claim 6 , wherein the at least one solvent comprises at least one selected from: methanol claim 6 , ethanol claim 6 , propanol claim 6 , isopropanol claim 6 , butanol claim 6 , isobutanol claim 6 , aromatic hydrocarbons claim 6 , monoethyleneglycol claim 6 , ethyleneglycolmonobutylether claim 6 , and combinations thereof.8. The corrosion inhibitor composition of claim 1 , comprising about 10 wt % to about 100 wt % of corrosion inhibitor actives.9. A method of inhibiting corrosion on a surface in an oil or gas application claim 1 , the method comprising contacting an effective dosage of the corrosion inhibitor of with the surface.10. The method of claim 9 , wherein the effective dosage range is between about 10 ppm to about 10 claim 9 ,000 ppm.11. The method of claim 9 , further comprising dosing the corrosion inhibitor into an annulus of a well; allowing the dosed corrosion inhibitor to travels into the well; and recovering the corrosion inhibitor with a produced fluid thereby avoiding entering a formation.12. The method of claim 9 , further comprising treating a ...

Chitin nanocrystal containing wellbore fluids

The current invention relates to the use of chitin nanocrystals and chitin nanocrystal derivatives. More specifically, the present invention relates to the use of chitin nanocrystals and chitin nanocrystals used in oil and gas operations. The chitin nanocrystals and chitin nanocrystals derivatives can be used as additives to cement and wellbore fluids and can be used to inhibit corrosion in pipelines, on downhole tools and on other oil and gas related equipment.

MICROBIAL VISCOSITY BREAKER COMPOSITIONS

A well treatment fluid composition that includes a tetrakis(hydroxyorgano)phosphonium salt and at least one oxidizing viscosity breaker. Methods for preparing a microbial viscosity breaker composition and treating a subterranean formation are also presented. 1. A well treatment fluid composition comprising a tetrakis(hydroxyorgano)phosphonium salt and at least one oxidizing viscosity breaker.2. The composition of claim 1 , wherein the tetrakis(hydroxyorgano)phosphonium salt is selected from the group consisting of tetrakis(hydroxymethyl)phosphonium sulphate claim 1 , tetrakis(hydroxymethyl)phosphonium chloride claim 1 , tetrakis(hydroxymethyl)phosphonium phosphate claim 1 , tetrakis(hydroxymethyl)phosphonium nitrate and tetrakis(hydroxymethyl)phosphonium oxalate.3. The composition of claim 1 , wherein the tetrakis(hydroxyorgano)phosphonium salt is present in an amount from about 40 ppm to about 250 ppm.4. The composition of further comprising a quaternary ammonium compound.5. The composition of claim 4 , wherein the quaternary ammonium compound is present in an amount from about 5 ppm to about 50 ppm.6. The composition of further comprising a polymer of an unsaturated carboxylic acid or a copolymer of an unsaturated carboxylic add with a sulphonic acid claim 1 , said polymer or copolymer being terminated by a mono- or di-phosphonated unsaturated carboxylic add group or having such monomers incorporated into the polymer backbone.7. The composition of claim 6 , wherein the polymer or copolymer is terminated by vinylphosphonic acid (VPA) or vinylidene-1 claim 6 ,1-diphosphonic acid (VDPA) or has such monomers incorporated into the polymer backbone.8. The composition of claim 1 , wherein the oxidizing viscosity breaker is selected from the group consisting of hydrogen peroxide claim 1 , sodium persulfate claim 1 , encapsulated ammonium persulfate claim 1 , and sodium chlorite.9. The composition of claim 1 , wherein the oxidizing viscosity breaker is present in an amount ...

METHOD FOR ADJUSTING THE LEVEL OF INHIBITORS IN AN OIL OR GAS WELL

A method for adjusting, to a pre-determined value, the level of a mineral deposition or corrosion inhibitor injected into a gas or oil well. Using of the time-resolved fluorescence method for detecting and quantifying a mineral deposition or corrosion inhibitor in a fluid from an oil or gas production well. 1. Method for adjusting to a predetermined value the level of a mineral deposition or corrosion inhibitor injected into a gas or oil well , comprising the following successive steps:the tagging of the inhibitor using a lanthanide,the detecting and the quantifying of the tagged inhibitor, via time-resolved fluorescence, in the fluid extracted from the production well, andif necessary, the injecting into the well of an additional quantity of inhibitor making it possible to reach said predetermined value.2. Method according to claim 1 , wherein the lanthanide is chosen from: Pr claim 1 , Nd claim 1 , Sm claim 1 , Eu claim 1 , Tb claim 1 , Dy claim 1 , Ho claim 1 , Er claim 1 , Tm and Yb claim 1 , as well as mixtures and/or alloys thereof.3. Method according to claim 1 , wherein the mineral deposition inhibitor is chosen from:polyphosphates,organophosphonates,carboxylic polyacides,polymers with a sulphonic acid function, in particular styrene sulphonic acid and maleic acid copolymers,optionally sulphonated polyphosphinocarboxylic acid (PPCA),polyethyleneimine,silicone polymers functionalised by amine groups, andcopolymers made from quaternary ammonium.4. Method according to claim 1 , wherein the corrosion inhibitor is chosen from cyclohxylamine claim 1 , hxylamine claim 1 , morpholine claim 1 , octadecylamine claim 1 , diethylaminoethanol and betaines.5. Method according to claim 1 , wherein the tagging of the inhibitor is carried out by grafting claim 1 , on the skeleton of the inhibitor claim 1 , a molecule complexing the lanthanide.6. Method according to claim 1 , wherein the tagging of the inhibitor is carried out via complexation of the lanthanide using the ...

METAL-CHELATE COMPLEX HYDROGEN SULFIDE SCAVENGERS

This disclosure provides a method for scavenging hydrogen sulfide (HS) from a fluid containing HS and metal ions by introducing into the fluid at least one metal chelant in an amount effective to chelate metal ions in the fluid to form at least one metal-chelate complex; and removing at least a portion of the HS from the fluid with an effective amount of the at least one metal-chelate complex. The method may further comprise the step of introducing at least one enzyme having an ability to scavenge HS into the fluid in an amount effective to scavenge HS from the fluid, where the amount of the at least one metal-chelate complex is effective to influence the ability of the at least one enzyme to scavenge HS. 1. A method for scavenging hydrogen sulfide (HS) from a fluid containing HS and metal ions comprising:introducing into the fluid at least one metal chelant in an amount effective to chelate metal ions in the fluid to form at least one metal-chelate complex; and{'sub': '2', 'removing a portion of the HS from the fluid with an effective amount of the at least one metal-chelate complex.'}2. The method of further comprising introducing at least one enzyme having an ability to scavenge HS into the fluid in an amount effective to remove a portion of the HS from the fluid claim 1 , where the amount of the at least one metal-chelate complex is effective to influence the ability of the at least one enzyme to scavenge HS.3. The method of where the at least one enzyme is selected from the group consisting of Sulfide Quinone Reductase (SQR) claim 2 , Cysteine Synthase claim 2 , and combinations thereof.4. The method of where the metal ions in the fluid are selected from the group consisting of Hg claim 1 , Cd claim 1 , Pb claim 1 , Zn claim 1 , Cu claim 1 , Fe claim 1 , Ca claim 1 , Mg claim 1 , Hg claim 1 , Fe claim 1 , Mn claim 1 , Sr claim 1 , Be claim 1 , Ba claim 1 , Bi claim 1 , and combinations thereof.5. The method of where the metal ions are incidentally present in ...

Multi-Functional Compositions for Enhanced Oil and Gas Recovery and Other Petroleum Industry Applications

The subject invention provides multi-functional biochemical compositions, as well as their use in enhancing oil recovery from an oil-bearing subterranean formation. Advantageously, the compositions and methods of the subject invention are operationally-friendly, cost-effective, and environmentally-friendly. More specifically, in preferred embodiments, the subject invention provides a multi-functional composition for enhanced oil recovery (EOR) comprising one or more surfactants, one or more chelating agents, and one or more solvents. 1. A composition for enhancing oil recovery an oil-bearing formation , the composition comprising one or more surfactants , one or more chelating agents , and one or more solvents.2. The composition of claim 1 , wherein the one or more surfactants are produced by microorganisms.3. The composition of claim 2 , wherein the one or more surfactants are biosurfactants selected from glycolipids claim 2 , cellobiose lipids claim 2 , lipopeptides claim 2 , fatty acid ester compounds claim 2 , flavolipids claim 2 , phospholipids claim 2 , high-molecular-weight biopolymers claim 2 , lipoproteins claim 2 , lipopolysaccharide-protein complexes claim 2 , and/or polysaccharide-protein-fatty acid complexes.5. The composition of claim 4 , wherein the fatty acid ester compounds comprise oleic fatty acid ethyl esters and/or oleic fatty acid methyl esters.7. The composition of claim 1 , wherein the one or more chelating agents are selected from dimercaptosuccinic acid (DMSA) claim 1 , 2 claim 1 ,3-dimercaptopropanesulfonic acid (DMPS) claim 1 , alpha lipoic acid (ALA) claim 1 , thiamine tetrahydrofurfuryl disulfide (TTFD) claim 1 , penicillamine claim 1 , ethylenediaminetetraacetic acid (EDTA) claim 1 , sodium acetate claim 1 , sodium citrate and citric acid.8. The composition of claim 7 , wherein the chelating agents comprise a mixture of EDTA claim 7 , sodium citrate and citric acid.9. The composition of claim 1 , wherein the one or more solvents are ...

Corrosion resistance when using chelating agents in carbon steel-containing equipment

The present invention relates to the use of solutions containing glutamic acid N,N-diacetic acid or a salt thereof (GLDA) and/or methylglycine N,N-diacetic acid or a salt thereof (MGDA) in treating subterranean formations, wherein the solutions contact carbon steel-containing equipment, and to a system containing a carbon steel-containing material in contact with a solution containing glutamic acid N,N-diacetic acid or a salt thereof (GLDA) and/or methylglycine N,N-diacetic acid or a salt thereof (MGDA), at elevated temperatures and/or employing carbon steel types as usually found in subterranean formations. 1. A method of treating subterranean formations using a solution containing glutamic acid N ,N-diacetic acid or a salt thereof (GLDA) and/or methylglycine N ,N-diacetic acid or a salt thereof (MGDA) , comprising contacting carbon steel-containing equipment with the solution at a temperature of at least 100° C.2. The method of claim 1 , wherein the carbon steel-containing equipment is cleaned or descaled.3. The method of claim 1 , wherein the solution is an acidic solution.4. The method of claim 1 , wherein the subterranean formation is used in oil and/or gas production claim 1 , in pickling claim 1 , completions claim 1 , stimulation by acidizing claim 1 , or fracturing.5. The method of claim 1 , wherein the solution in addition contains water and a corrosion inhibitor.6. The method of claim 5 , wherein the amount of corrosion inhibitor is more than 0 up to 3 vol % on total volume of the solution.7. The method of claim 1 , wherein the solution in addition contains one or more of water claim 1 , solvents claim 1 , alcohols claim 1 , glycols claim 1 , organic solvents claim 1 , mutual solvents claim 1 , soaps claim 1 , surfactants claim 1 , dispersants claim 1 , emulsifiers claim 1 , pH control additives claim 1 , acids or bases claim 1 , biocides/bactericides claim 1 , water softeners claim 1 , bleaching agents claim 1 , enzymes claim 1 , brighteners claim 1 , ...

TETRAZOLE BASED CORROSION INHIBITORS

Disclosed are corrosion inhibitor compounds and compositions useful for preventing or inhibiting corrosion of surfaces found in cooling water applications. In some embodiments, the surfaces may include mild steel, aluminum, brass, copper, galvanized steel, a copper alloy, admirality brass, or any combination thereof. Also disclosed are methods of using the compounds and compositions as corrosion inhibitors. In some embodiments, the corrosion inhibitor compounds and compositions are used in cooling water applications. 2. The composition of claim 1 , wherein{'sub': 6', '10', '2', '2', '1', '6', '1', '6', '1', '6', '2', '2', '1', '6, 'sup': 3', '4', '3', '4, 'L is C-C-alkylenyl substituted or unsubstituted with 1 to 3 substituents independently selected from the group consisting of —F, —Cl, —NO, —CN, —OH, —NH, C-Calkyl, C-Chaloalkyl, C-Calkoxy, —COR, and —CON(R), wherein Rand R, at each occurrence, are each independently selected from the group consisting of hydrogen and C-Calkyl.'}3. The composition of claim 1 , wherein L is unsubstituted C-C-alkylenyl.4. The composition of claim 1 , wherein L is C-C-alkylenyl substituted with one claim 1 , two claim 1 , or three tetrazolyl groups claim 1 , wherein said tetrazolyl groups are substituted or unsubstituted.5. The composition of claim 1 , wherein the compound of formula (II) is selected from the group consisting of:1,6-di(1H-tetrazol-5-yl)hexane (“HDTZ”);1,7-di(1H-tetrazol-5-yl)heptane (“HeDTZ”);1,8-di(1H-tetrazol-5-yl)octane (“ODTZ”); and5,5′,5″-(hexane-1,3,6-triyl)tris(1H-tetrazole) (“TCH-TZ”).6. The composition of claim 1 , further comprising one or more components claim 1 , each component independently selected from the group consisting of:a solvent;a tracer;a scale inhibitor;a dispersant;an acid; anda base.7. The composition of claim 1 , wherein the composition comprises about 40% by weight of one or more compounds of formula (II).8. The composition of claim 1 , wherein the composition is a stable water-based ...

AQUEOUS SOLUTION AND METHOD FOR USE THEREOF

Oilfield treatment compositions contain water, hydrochloric acid at a concentration between 15 wt % and 45.7 wt % and a first and second fixing agent. The first fixing agent comprises urea, a urea derivative or both. The second fixing agent may be a mixture or amines and alcohols. These compositions provide corrosion inhibition when exposed to steel. The compositions may also contain an inhibitor aid. 1. A composition , comprising:(i) water at a concentration lower than or equal to 20 wt %;(ii) hydrochloric acid at a concentration between 15 wt % and 45.7 wt %;(iii) a first fixing agent comprising urea, a urea derivative or both; and(iv) a second fixing agent,wherein the first fixing agent:hydrochloric acid molar ratio is between 0.4 and 3.0 inclusive.2. The composition of claim 1 , wherein the urea derivative comprises 1 claim 1 ,1-dimethylurea claim 1 , 1 claim 1 ,3-dimethylurea claim 1 , 1 claim 1 ,1-diethylurea claim 1 , 1 claim 1 ,3-diethylurea claim 1 , 1 claim 1 ,1-diallylurea claim 1 , 1 claim 1 ,3-diallylurea claim 1 , 1 claim 1 ,1-dipropylurea claim 1 , 1 claim 1 ,3-dipropylurea claim 1 , 1 claim 1 ,1-dibutylurea claim 1 , 1 claim 1 ,3-dibutylurea claim 1 , 1 claim 1 ,1 claim 1 ,3 claim 1 ,3-tetramethylurea claim 1 , 1 claim 1 ,1 claim 1 ,3 claim 1 ,3-tetraethylurea claim 1 , 1 claim 1 ,1 claim 1 ,3 claim 1 ,3-tetrapropylurea claim 1 , 1 claim 1 ,1 claim 1 ,3 claim 1 ,3-tetrabutylurea claim 1 , ethyleneurea claim 1 , propyleneurea claim 1 , 1 claim 1 ,3-dimethylpropyleneurea or 1 claim 1 ,3-dimethylethyleneurea claim 1 , or combinations thereof.3. The composition of claim 1 , wherein the second fixing agent comprises a mixture of amines and alcohols.4. The composition of claim 3 , wherein the concentration of the second fixing agent is between 0.1 wt % and 0.5 wt % inclusive.5. The composition of claim 3 , further comprising an inhibitor aid comprising a mixture of phenyl ketones and quarternary amines.6. The composition of claim 5 , wherein the ...

FATTY AMINES, AMIDOAMINES, AND THEIR DERIVATIVES FROM NATURAL OIL METATHESIS

Fatty amine compositions made from a metathesis-derived C10-C17 monounsaturated acid, octadecene-1,18-dioic acid, or their ester derivatives are disclosed. In another aspect, fatty amidoamines made by reacting a metathesis-derived C10-C17 monounsaturated acid, octadecene-1,18-dioic acid, or their ester derivatives with an aminoalkyl-substituted tertiary amine are disclosed. The fatty amines or amidoamines are advantageously sulfonated, sulfitated, oxidized, or reduced. In other aspects, the ester derivative is a modified triglyceride made by self-metathesis of a natural oil or an unsaturated triglyceride made by cross-metathesis of a natural oil with an olefin.

QUATERNIZED FATTY AMINES, AMIDOAMINES AND THEIR DERIVATIVES FROM NATURAL OIL METATHESIS

Quaternary ammonium, betaine, or sulfobetaine compositions derived from fatty amines, wherein the fatty amine is made by reducing the amide reaction product of a metathesis-derived C-Cmonounsaturated acid, octadecene-1,18-dioic acid, or their ester derivatives and a secondary amine, are disclosed. Quaternary ammonium, betaine, or sulfobetaine compositions derived from fatty amidoamines, wherein the amidoamine is made by reacting of a metathesis-derived C-Cmonounsaturated acid, octadecene-1,18-dioic acid, or their ester derivatives and an aminoalkyl-substituted tertiary amine, are also disclosed. The quaternized compositions are advantageously sulfonated or sulfitated. In one aspect, the ester derivative of the C-Cmonounsaturated acid or octadecene-1,18-dioic acid is a lower alkyl ester. In other aspects, the ester derivative is a modified triglyceride made by self-metathesis of a natural oil or an unsaturated triglyceride made by cross-metathesis of a natural oil with an olefin. The quaternary ammonium, betaine, and sulfobetaine compositions and their sulfonated or sulfitated derivatives are valuable for a wide variety of end uses, including cleaners, fabric treatment, hair conditioning, personal care (liquid cleansing products, conditioning bars, oral care products), antimicrobial compositions, agricultural uses, and oil field applications.

Use Of A Composition Containing At Least One Biodegradable Sugar-Amide-Compound In Combination With At Least One Sulfur-Based Synergist For Corrosion Inhibition Of A Metallic Equipment In Oilfield Applications

In this invention the use of glucamides in combination with at least one sulfur-based synergist chosen from the group of thiols, thioethers, thiosulfates, thioglycolic acids, thiourea or derivatives thereof in a formulation for corrosion inhibition in the gas and oil industry is described. 214.-. (canceled)17. The process according to claim 15 , in which Ra is an alkyl or alkenyl group with 7 to 21 carbon atoms.18. The process according to claim 15 , in which Rb is methyl.19. The process according to claim 15 , in which the sulfur synergist is represented by the formula R—S—Rwherein Ris hydrogen claim 15 , and Ris an alkyl group with 1 to 12 carbon atoms that may contain oxygen or nitrogen atoms.20. The process according to claim 15 , in which the sulfur synergist is represented by the formula R—S—Rwherein{'sup': '1', 'Ris an alkyl group having 1 to 4 carbon atoms, that may contain oxygen or nitrogen atoms and'}{'sup': '2', 'Ris an alkyl group having 2 to 26 carbon atoms, that may contain oxygen or nitrogen atoms'}21. The process according to claim 15 , wherein one of Rand Rcomprises a carboxylic acid group.22. The process according to claim 21 , in which the sulfur synergist is represented by the formula M(HSCHCOO)wherein{'sub': '4', 'a) x=1 and M is selected from the group consisting of Li, Na, K, Ag, Cu or NH, and tertiary amines with alkyl, alkylene or alkoxyalkyl side groups, that may also be cyclic and may contain the heteroatoms O or N;'}b) x=2 and M is selected from the group consisting of Mg, Ca, Sr, Cu, Zn, Pb or Fe and tertiary amines with alkyl, alkylene or alkoxyalkyl side groups, that may also be cyclic and may contain the heteroatoms O or N;c) x=3 and M is selected from the group consisting of Al, Bi or Fe.23. The process according to claim 15 , in which the sulfur synergist is claim 15 , represented by the formula M(SO) wherein{'sub': '4', 'x=2 and y=1 and M=Li, Na, K, Ag, Cu or NH; or'}x=1 and y=1 and M=Mg, Ca, Sr, Cu, Zn, Pb or Fe; orx=2 and y=3 ...

COMPOSITIONS AND METHODS FOR SCAVENGING H2S

A method of treating a fluid, which method includes the steps of: (a) contacting a fluid containing at least one sulfide with a sulfide-reducing amount of a composition comprising an lignocellulosic liquor comprising one or more lignin-derived compounds and one or more hemicellulose sugar monomers and/or oligomers and (b) allowing the lignocellulosic liquor to react with at least a portion of the sulfide in the fluid. 112.-. (canceled)13. A method of treating a fluid comprising the steps of: (a) contacting a fluid containing at least one sulfide with a sulfide-reducing amount of a composition comprising a lignocellulosic liquor comprising one or more lignin-derived compounds and one or more hemicellulose sugar monomers and/or oligomers; and (b) allowing the lignocellulosic liquor to react with at least a portion of the sulfide in the fluid.14. The method of claim 13 , wherein the at least one sulfide is present at a first concentration in step (a); and in step (b) claim 13 , the concentration of sulfide is reduced to a second concentration that is lower than the first concentration.15. A method of treating a fluid comprising the steps of: (a) introducing a composition comprising a lignocellulosic liquor comprising one or more lignin-derived compounds and one or more hemieellulose sugar monomers and/or oligomers into at least a portion of a subterranean formation; and (b) allowing the lignocellulosic liquor to react with at least a portion of the sulfide compounds in the fluid.16. A method of drilling comprising: (a) using a drilling fluid comprising a lignocellulosic liquor comprising one or more lignin-derived compounds and one or more hemicellulose sugar monomers and/or oligomers to drill at least a portion of a well bore penetrating at least a portion of a subterranean formation; and (b) allowing the lignocellulosic liquor to react with at least a portion of the sulfide compounds in the drilling fluid.17. The method according to claim 13 , wherein the composition ...

ALKYL LACTONE-DERIVED CORROSION INHIBITORS

Disclosed are alkyl lactone-derived hydroxyamide and alkyl lactone-derived hydroxyester used in compositions and methods for inhibiting corrosion. The alkyl lactone-derived hydroxyamide and alkyl lactone-derived hydroxyester are reaction products of an alkyl lactone and an amine, and an alkyl lactone and an alcohol, respectively. 1. A composition comprising at least one alkyl lactone-derived hydroxyamide or alkyl lactone-derived hydroxyester to inhibit corrosion , the at least one alkyl lactone-derived hydroxyamide formed by a reaction between an alkyl lactone with an amine , and the alkyl lactone-derived hydroxyester formed by a reaction between an alkyl lactone with an alcohol.2. The composition of claim 1 , wherein the alkyl lactone comprises a 1-30 carbon atom-containing alkyl substituent.3. The composition of claim 1 , wherein the alkyl lactone is a δ undecalactone claim 1 , a γ undecalactone or a γ octalactone.4. The composition of claim 1 , wherein the amine is a dimethylaminopropylamine.6. The composition of claim 1 , wherein the composition further comprises one or more asphaltene inhibitors claim 1 , paraffin inhibitors claim 1 , scale inhibitors claim 1 , emulsifiers claim 1 , water clarifiers claim 1 , dispersants claim 1 , emulsion breakers claim 1 , or any combination thereof.7. The composition of claim 1 , wherein the alkyl lactone-derived hydroxyamide or alkyl lactone-derived hydroxyester comprises a reduced toxicity compared to compositions not containing alkyl lactone derived hydroxyamide or alkyl lactone-derived hydroxyester.8Daphnia magna. The composition of claim 1 , wherein the alkyl lactone derived hydroxyamide or alkyl lactone-derived hydroxyester comprises a ECo value with greater than or equal to 10 mg/ml.9Daphnia magna. The composition of claim 1 , wherein the alkyl lactone derived hydroxyamide or alkyl lactone-derived hydroxyester comprises a 48-hour ECo value with from about 10-100 mg/ml.10. The composition of claim 1 , wherein the alkyl ...

QUATERNIZED FATTY AMINES, AMIDOAMINES AND THEIR DERIVATIVES FROM NATURAL OIL METATHESIS

Quaternary ammonium, betaine, or sulfobetaine compositions derived from fatty amines, wherein the fatty amine is made by reducing the amide reaction product of of a metathesis-derived C-Cmonounsaturated acid, octadecene-1,18-dioic acid, or their ester derivatives and a secondary amine, are disclosed. Quaternary ammonium, betaine, or sulfobetaine compositions derived from fatty amidoamines, wherein the amidoamine is made by reacting of a metathesis-derived C-Cmonounsaturated acid, octadecene-1,18-dioic acid, or their ester derivatives and an aminoalkyl-substituted tertiary amine, are also disclosed. The quaternized compositions are advantageously sulfonated or sulfitated. In one aspect, the ester derivative of the C-Cmonounsaturated acid or octadecene-1,18-dioic acid is a lower alkyl ester. In other aspects, the ester derivative is a modified triglyceride N made by self-metathesis of a natural oil or an unsaturated triglyceride made by cross-metathesis of a natural oil with an olefin. The quaternary ammonium, betaine, and sulfobetaine compositions and their sulfonated or sulfitated derivatives are valuable for a wide variety of end uses, including cleaners, fabric treatment, hair conditioning, personal care (liquid cleansing products, conditioning bars, oral care products), antimicrobial compositions, agricultural uses, and oil field applications. 173-. (canceled)74. A quaternary ammonium , betaine , or sulfobetaine composition derived from a fatty amidoamine , wherein the amidoamine is made by reacting a metathesis-derived C-Cmonounsaturated acid , octadecene-1 ,18-dioic acid , or their ester derivatives and an aminoalkyl-substituted tertiary amine; {'br': None, 'sup': 4', '3', '2', '+', '1', '−, 'sub': 2', 'n, 'R(R)(R)N(CH)NH(CO)RX'}, 'wherein the quaternary ammonium composition has the formula{'sup': 1', '5', '+', '2', '3', '4', '−', '2', '3', '4', '−', '5, 'sub': 9', '16', '16', '30', '2', 'n', '1', '6', '1', '7, 'wherein Ris —CH—Ror —CH—(CO)NH(CH)N(R)(R)RX; each ...

BIOCIDE COMPOSITION AND USE THEREOF

The present disclosure relates to biocide compositions, formulations and methods for using formulations. In particular the present disclosure relates to biocide compositions and their use in effecting biocidal activity in subterranean oil and gas wells being drilled, completed, worked over or produced. 1. A process for reducing a bacterial population in a gas or oil well comprising ,a. treating the gas or oil well with a stabilized hypochlorous acid solution, andb. treating the gas or oil well with a water soluble bromide ion source.2. A process for treating flowback water in a gas or oil well comprising ,a. treating the flowback water with a stabilized hypochlorous acid solution, andb. treating the flowback water with a water soluble bromide ion source.38.-. (canceled)9. A composition for use in the drilling , completion , work over or production of subterranean oil and gas wells comprising hypobromous acid (HOBr) formed from contacting a stabilized hypochlorous acid solution with a water soluble bromide ion source.10. The process of claim 1 , wherein the stabilized hypochlorous acid solution is formed by contacting a chlorine source with a stabilizing agent in an aqueous solution.11. The process of claim 10 , wherein the chlorine source is an alkali or alkaline earth metal hypochlorite claim 10 , or chlorine gas.12. The process of claim 10 , wherein the stabilizing agent is selecter from the group consisting of urea claim 10 , thiourea claim 10 , creatinine claim 10 , mono or di-ethanolamine claim 10 , organic sulfonamide claim 10 , biuret claim 10 , sulfamic acid claim 10 , organic sulfamate claim 10 , and melamine.13. The process of claim 1 , wherein the water soluble bromide ion source is selected from the group consisting of sodium bromide claim 1 , potassium bromide claim 1 , lithium bromide claim 1 , chlorine bromide claim 1 , and bromine.14. The process of claim 2 , wherein the stabilized hypochlorous acid solution is formed by contacting a chlorine source ...

Method of scavenging hydrogen sulfide and mercaptans using well treatment composites

Hydrogen sulfide and mercaptans may be removed from a fluid or gaseous stream by introducing a composite to the fluid or gaseous stream containing a hydrogen sulfide scavenger adsorbed onto a water-insoluble adsorbent.

FATTY AMINES, AMIDOAMINES, AND THEIR DERIVATIVES FROM NATURAL OIL METATHESIS

Fatty amine compositions made from a metathesis-derived C10-C17 monounsaturated acid, octadecene-1,18-dioic acid, or their ester derivatives are disclosed. In another aspect, fatty amidoamines made by reacting a metathesis-derived C10-C17 monounsaturated acid, octadecene-1,18-dioic acid, or their ester derivatives with an aminoalkyl-substituted tertiary amine are disclosed. The fatty amines or amidoamines are advantageously sulfonated, sulfitated, oxidized, or reduced. In other aspects, the ester derivative is a modified triglyceride made by self-metathesis of a natural oil or an unsaturated triglyceride made by cross-metathesis of a natural oil with an olefin. 171-. (canceled)72. A glyphosate formulation , a water-soluble herbicide composition , an agricultural solvent , or an anionic emulsifier for agricultural compositions , each comprising: {'br': None, 'sup': 3', '2', '1, 'sub': 2', 'n, 'R(R)N(CH)NH(CO)R'}, '(a) a fatty amidoamine having the formula{'sup': 1', '4', '2', '3', '2', '3', '4', '4', '9, 'sub': 9', '16', '16', '30', '2', 'n', '1', '7', '1', '7, 'wherein Ris —CH—Ror —CH—(CO)NH(CH)N(R)R; each of Rand Ris independently substituted or unsubstituted alkyl, aryl, alkenyl, oxyalkylene, or polyoxyalkylene; Ris hydrogen or C-Calkyl; and n=2-8; wherein when Ris C-Calkyl, the fatty amidoamine has at least 1 mole % of trans-Δunsaturation; or'}(b) a derivative made by sulfonating, sulfitating, or oxidizing the fatty amidoamine.73. A hard-surface cleaner , or a personal cleanser or handsoap , each comprising: {'br': None, 'sup': 3', '2', '1, 'sub': 2', 'n, 'R(R)N(CH)NH(CO)R'}, '(a) a fatty amidoamine having the formula{'sup': 1', '4', '2', '3', '2', '3', '4', '4', '9, 'sub': 9', '16', '16', '30', '2', 'n', '1', '7', '1', '7, 'wherein Ris —CH—Ror —CH—(CO)NH(CH)N(R)R; each of Rand Ris independently substituted or unsubstituted alkyl, aryl, alkenyl, oxyalkylene, or polyoxyalkylene; Ris hydrogen or C-Calkyl; and n=2-8; wherein when Ris C-Calkyl, the fatty amidoamine ...

Methods of preparing treatment fluids comprising anhydrous ammonia for use in subterranean formation operations

Methods comprising preparing a gelled fluid comprising a base fluid, a first gelling agent, and particulates; introducing the gelled fluid into a process stream, the process stream in fluid communication with a subterranean formation; introducing anhydrous ammonia into the gelled fluid at a downstream location in the process stream, thereby forming a particulate-containing treatment fluid; and introducing the particulate-containing treatment fluid into the subterranean formation from the process stream and through the wellhead.

METHODS AND CEMENT COMPOSITIONS FOR REDUCING CORROSION OF WELLBORE CASINGS

A corrosion inhibiting cement composition for reducing corrosion of wellbore casings is disclosed that includes from 10 weight percent to 70 weight percent cement precursor, from 5 weight percent to 70 weight percent water, from 0.1% to 60% by weight of cement amine corrosion inhibitor, where the amine corrosion inhibitor comprises a polyethylene polyamine. A method for reducing corrosion of wellbore casings includes dispensing the corrosion inhibiting cement compositions into the annulus and allowing the corrosion inhibiting cement composition to cure to form a hardened cement, where the corrosion inhibiting cement composition includes a cement composition and the amine corrosion inhibitor. 1. A method for reducing corrosion in tubular strings installed in wellbores , the method comprising:dispensing a corrosion inhibiting cement composition into an annulus defined between a tubular string and an inner wall of a wellbore or between two tubular strings, where the corrosion inhibiting cement composition comprises a polyethylene polyamine and a cement composition comprising a cement precursor and water; andallowing the corrosion inhibiting cement composition to cure in the annulus to form a cured cement, where the polyethylene polyamines in the corrosion inhibiting cement composition react with a metal of the tubular string, the reaction forming a protective layer on the surfaces of the tubular string, the protective layer preventing dissolution of iron from the metal of the tubular string.2. The method of claim 1 , further comprising drilling a portion of a wellbore and placing a tubular string in the wellbore.3. The method of claim 1 , further comprising preparing the corrosion inhibiting cement composition claim 1 , where preparing the corrosion inhibiting cement composition comprises:preparing the cement composition;combining the polyethylene polyamine and the cement composition to produce the corrosion inhibiting cement composition; andmixing the corrosion ...

NOVEL DOWNHOLE METHODS

A method for the fracking or stimulation of a hydrocarbon-bearing formation, said method comprising the steps of: 2. The method according to claim 1 , wherein the breakdown acidic composition comprises an acid selected from the group consisting of: mineral acids; organic acids; and combinations thereof.3. The method according to claim 1 , wherein the breakdown acidic composition comprises an acid selected from the group consisting of: HCl; methanesulphonic acid; toluenesulfonic acid; sulfamic acid; HCl:amino acid; and HCl:alkanolamine.4. The method according to claim 1 , wherein the breakdown acidic composition is an acid comprising an HCl:amino acid claim 1 , where the amino acid is selected from the group consisting of: lysine; lysine monohydrochloride; alanine; asparagine; aspartic acid; cysteine; glutamic acid; histidine; leucine; methionine; proline; serine; threonine; valine; and combinations thereof.5. The method according to claim 1 , wherein the breakdown acidic composition is an acid comprising an HCl:alkanolamine wherein the alkanolamine is selected from the group consisting of: monoethanolamine; diethanolamine; triethanolamine and combinations thereof.6. The method according to claim 1 , wherein the breakdown acidic composition is an acid comprising HCl:monoethanolamine.8. The method according to claim 7 , wherein the breakdown acidic composition comprises an acid selected from the group consisting of: mineral acids; organic acids; and combinations thereof.9. The method according to claim 7 , wherein the breakdown acidic composition comprises an acid selected from the group consisting of: HCl; methanesulphonic acid; toluenesulfonic acid; sulfamic acid; HCl:amino acid; and HCl:alkanolamine.10. The method according to claim 7 , wherein the breakdown acidic composition is an acid comprising an HCl:amino acid claim 7 , where the amino acid is selected from the group consisting of: lysine; lysine monohydrochloride; alanine; asparagine; aspartic acid; cysteine ...

H2S SCAVENGERS WITH SYNERGISTIC CORROSION INHIBITION

Triazine hydrogen sulfide (HS) scavengers consume HS and form dithiazines by-products which are corrosion inhibitors. Triazine HS scavengers may be formulated with other corrosion inhibitors and used in HS-containing fluids so that the dithiazine by-products may together with the at least one additional corrosion inhibitor form give synergistically better inhibiting of corrosion of iron and/or iron alloys in contact with the fluid to an extent greater than additive of the corrosion inhibition of the dithiazine and the corrosion inhibition of the at least one additional corrosion inhibitor, taken separately. The dithiazine may have the formula: 1. A method for scavenging hydrogen sulfide (HS) from and providing corrosion inhibition to a fluid in contact with iron and/or iron alloys comprising:{'sub': '2', 'claim-text': [{'sub': '2', 'a triazine that reacts with HS to form a dithiazine capable of and in an amount effective for inhibiting corrosion in the fluid, and'}, 'at least one additional corrosion inhibitor capable of and in an amount effective for inhibiting corrosion in the fluid;, 'introducing to a HS-containing fluid in any order{'sub': '2', 'at least partially reacting the triazine with HS forming the dithiazine;'}contacting the dithiazine with the at least one additional corrosion inhibitor, andinhibiting corrosion of iron and/or iron alloys in contact with the fluid to an extent greater than additive of the corrosion inhibition of the dithiazine and the corrosion inhibition of the at least one additional corrosion inhibitor, taken separately.2. The method of further comprising introducing the fluid into a wellbore.4. The method of where R is —R—OH claim 1 , where Ris an alkylene group.5. The method of where Ris an alkylene group of C-C.6. The method of where the at least one additional corrosion inhibitor is selected from the group consisting of:(a) an alkyl, alkylaryl or arylamine quaternary salt with an alkyl or alkylaryl halide;(b) a mono or polycyclic ...

CORROSION INHIBITOR COMPOSITION FOR PIPELINES

The present invention relates to the low cost high performing corrosion inhibitor composition and process for preparation thereof. The corrosion inhibitor comprises of an ester of cashew nut shell liquid (CNSL), a dimer fatty acid (DFA), a long chain amine and a solvent. The corrosion inhibitor composition prevents corrosion of internal metal surface of pipelines due to petroleum products. 2. The composition as claimed in claim 1 , wherein the ester of cashew nut shell liquid (CSNL) is present in the range of 0.01 to 10% by weight.3. The composition as claimed in claim 1 , wherein the dimer fatty acid (DFA) is present in the range of 50 to 95% by weight.4. The composition as claimed in claim 1 , wherein the long chain amine is present in the range of 0.1 to 20% by weight.5. The composition as claimed in claim 1 , wherein the solvent is present in the range of 10 to 45% by weight.6. The composition as claimed in claim 1 , wherein the dimer fatty acid (DFA) is having alkyl chain of carbon atoms in the range of 30 to 50.7. An additive composition as claimed in claim 1 , wherein the dimer fatty acid (DFA) is a mixture of fatty acids having alkyl chain of 16 to 24 carbon atoms.8. The composition as claimed in claim 1 , wherein the long chain amine is having carbon atoms in the range of 10 to 18.9. The composition as claimed in claim 1 , wherein the ester of cashew nut shell liquid include ester of technical CNSL or hydrogenated CNSL or mixture thereof.10. The composition as claimed in claim 1 , wherein the solvent is an aromatic solvent or a aliphatic solvent or a petroleum solvent.11. The composition as claimed in claim 10 , wherein the solvent is selected from the group comprising of xylene claim 10 , toluene claim 10 , alkylated benzene claim 10 , isopropanol claim 10 , butanol claim 10 , pentanol claim 10 , pre-fractionator rerun column bottom claim 10 , or a combination thereof.12. A process for preparation of a corrosion inhibitor composition claim 10 , the process ...

NOVEL CORROSION INHIBITION PACKAGE

An inhibition corrosion package for use with an acidic composition, where the package comprises a terpene component; a propargyl alcohol or derivative thereof; at least one amphoteric surfactant; and a solvent. Also disclosed are acidic compositions combining the corrosion inhibition package according to a preferred embodiment of the present invention for use in various industrial operations including but not limited to oil and gas operations. Also disclosed are methods of use of such compositions. 1. A corrosion inhibition package for use with an aqueous acid composition , said package comprising:a terpene;a propargyl alcohol or derivative thereof;at least one amphoteric surfactant; anda solvent.2. The corrosion inhibition package as claimed in claim 1 , wherein the terpene is selected from the group consisting of:citral;ionone;ocimene; andcymene.3. The corrosion inhibition package as claimed in claim 1 , wherein the at least one amphoteric surfactant is selected from the group consisting of:a sultaine surfactant; a betaine surfactant; and combinations thereof.4. The corrosion inhibition package as claimed in claim 3 , wherein the sultaine surfactant and betaine surfactant are selected from the group consisting of:an amido betaine surfactant; an amido sultaine surfactant; and combinations thereof.5. The corrosion inhibition package as claimed in claim 4 , wherein the amido betaine surfactant and is selected from the group consisting of:an amido betaine comprising a hydrophobic tail from C8 to C16.6. The corrosion inhibition package as claimed in claim 5 , wherein the amido betaine surfactant comprising a hydrophobic tail from C8 to C16 is cocamidobetaine7. The corrosion inhibition package as claimed in claim 1 , further comprising an anionic surfactant.8. The corrosion inhibition package as claimed in claim 7 , wherein the anionic surfactant is a carboxylic surfactant or a sulfonic surfactant.9. The corrosion inhibition package as claimed in claim 8 , wherein the ...

Corrosion Resistance When Using Chelating Agents in Chromium-Containing Equipment

The present invention relates to process to reduce the corrosion of equipment containing a chromium-containing alloy in the oil and/or gas industry, comprising a step of contacting the equipment based on a chromium-containing alloy with a solution containing at least 1 wt % on total weight of the solution of glutamic acid N,N-diacetic acid or a salt thereof (GLDA) and/or methylglycine N,N-diacetic acid or a salt thereof (MGDA) having an acidic pH, the use of the above solutions in equipment containing a chromium-containing alloy to reduce corrosion, and to a system containing a piece of equipment used in the oil and/or gas industry made at least partly from chromium-containing alloy in contact with an acidic solution containing at least 1 wt % of glutamic acid N,N-di acetic acid or a salt thereof (GLDA) and/or methylglycine N,N-di acetic acid or a salt thereof (MGDA). 1. A process to reduce the corrosion of equipment containing a chromium-containing alloy in the oil and/or gas industry , comprising a step of contacting the equipment containing a chromium-containing alloy with a solution containing between 2 and 50 wt % on total weight of the solution of glutamic acid N ,N-diacetic acid or a salt thereof (GLDA) and/or between 2 and 40 wt % methylglycine N ,N-diacetic acid or a salt thereof (MGDA) having an acidic pH.2. A process to reduce the corrosion of equipment containing a chromium-containing alloy in the treatment of a subterranean formation wherein an acidic solution is introduced into the formation and at least part of the acid in the acidic solution is glutamic acid N ,N-diacetic acid or a salt thereof (GLDA) and/or methylglycine N ,N-diacetic acid or a salt thereof (MGDA) , and the acidic solution comes into contact with the equipment containing a chromium-containing alloy.3. The process of wherein the amount of GLDA and/or MGDA is at least 1 wt % on total weight of the solution.4. A process for preventing or reducing corrosion in equipment containing a ...

POLYMERIC SURFACTANT CONTAINING A PROTEIN HEAD GROUP AND LIPID TAIL GROUP

A treatment fluid comprising: a base fluid; and a surfactant, wherein the surfactant: (i) is a polymer; and (ii) comprises a hydrophilic head group and a hydrophobic tail group, wherein the hydrophilic head group comprises a protein, and wherein the hydrophobic tail group comprises a lipid. A method of treating a subterranean formation comprising: introducing the treatment fluid into a well, wherein the well penetrates the subterranean formation. 1. A method of treating a subterranean formation comprising:introducing a treatment fluid into a well, wherein the well penetrates the subterranean formation, and wherein the treatment fluid comprises:a base fluid; and (i) is a polymer; and', '(ii) comprises a hydrophilic head group and a hydrophobic tail group, wherein the hydrophilic head group comprises a protein, and wherein the hydrophobic tail group comprises a lipid., 'a surfactant, wherein the surfactant2. The method according to claim 1 , wherein the base fluid is water claim 1 , and wherein the water is selected from the group consisting of freshwater claim 1 , brackish water claim 1 , saltwater claim 1 , and any combination thereof.3. The method according to claim 2 , wherein the base fluid further comprises a water-soluble salt claim 2 , wherein the salt is selected from the group consisting of sodium chloride claim 2 , calcium chloride claim 2 , calcium bromide claim 2 , potassium chloride claim 2 , potassium bromide claim 2 , magnesium chloride claim 2 , sodium bromide claim 2 , cesium formate claim 2 , cesium acetate claim 2 , and any combination thereof.4. The method according to claim 1 , wherein the base fluid is a hydrocarbon liquid.5. The method according to claim 4 , wherein the hydrocarbon liquid is selected from the group consisting of: a fractional distillate of crude oil; a fatty derivative of an acid claim 4 , an ester claim 4 , an ether claim 4 , an alcohol claim 4 , an amine claim 4 , an amide claim 4 , or an imide; a saturated hydrocarbon; an ...

Downhole fluids and methods of use thereof

The present disclosure relates to downhole fluid additives including a clay, a hydroxylated polymer, a cation, and water. The disclosure further relates to downhole fluids, including drilling fluids, spaces, cements, and proppant delivery fluids containing such as downhole fluid additive and methods of using such fluids. The downhole fluid additive may have any of a variety of functions in the downhole fluid and may confer any of a variety of properties upon it, such as salt tolerance or desired viscosities even at high downhole temperatures.

Reduced Corrosion Chlorine Dioxide for Oil & Gas Well Clenaing and Sanitization

Preparation of an aqueous chlorine dioxide solution that reaches a first chlorine dioxide concentration during a first time period, and reaches a terminal concentration thereafter. A dilute solution of aqueous sodium chlorite or chlorate with predetermined concentration is produced, which yields the terminal chlorine dioxide concentration once an acid activator is added. The dilute solution is transferred through a conduit into a sanitization zone. The acid activator is injected into the conduit at a rate and concentration selected to reach the first chlorine dioxide concentration at the end of the first time period, with a flow rate such that the activated dilute solution of aqueous sodium chlorite has passed through the conduit prior to reaching the first chlorine dioxide concentration, which thereby limits exposure of the conduit to levels less than the first chlorine dioxide concentration. 1. A method of preparing an aqueous chlorine dioxide solution that reaches a first chlorine dioxide concentration during a first time period , and reaches a terminal chlorine dioxide concentration thereafter , the method comprising the steps of:preparing a dilute solution of aqueous sodium chlorite having a predetermined sodium chlorite concentration sufficient to achieve the terminal chlorine dioxide concentration once activated with an acid activator;transferring the dilute solution of aqueous sodium chlorite at a flow rate through a conduit and process equipment, and into a sanitization zone;injecting the acid activator into the conduit at a rate and concentration selected to achieve the first chlorine dioxide concentration at the end of the first time period;selecting the flow rate such that the activated dilute solution of aqueous sodium chlorite has passed through the conduit and process equipment prior to reaching the first chlorine dioxide concentration, thereby limiting exposure of the conduit and process equipment to levels less than the first chlorine dioxide ...

Novel Modified Acid Compositions as Alternatives to Conventional Acids in the Oil and Gas Industry

An aqueous modified acid composition for industrial activities, said composition comprising: an alkanolamine and strong acid in a molar ratio of not less than 1:15, preferably not less than 1:10; it can also further comprise a metal iodide or iodate. Said composition demonstrates advantages over known conventional acids and modified acids. 1. An aqueous modified acid composition comprising:a mineral acid and an alkanolamine in a molar ratio of not more than 15:1.2. A aqueous modified acid composition comprising:hydrochloric acid and an alkanolamine in a molar ratio of not more than 15:1.3. The aqueous modified acid composition according to claim 2 , wherein the hydrochloric acid and alkanolamine are present in a molar ratio of not more than 10:1.4. The aqueous modified acid composition according to claim 2 , wherein the hydrochloric acid and alkanolamine are present in a molar ratio of not more than 7.0:1.5. The aqueous modified acid composition according to claim 2 , wherein the hydrochloric acid and alkanolamine are present in a molar ratio of not more than 4.1:1.6. The aqueous modified acid composition according to claim 2 , wherein the hydrochloric acid and alkanolamine are present in a molar ratio of not less than 3:1.7. The aqueous modified acid composition according to any one of to claim 2 , wherein the alkanolamine is selected from the group consisting of: monoethanolamine; diethanolamine; triethanolamine and combinations thereof.8. The aqueous modified acid composition according to any one of to claim 2 , wherein the alkanolamine is monoethanolamine.9. The aqueous modified acid composition according to any one of to claim 2 , wherein the alkanolamine is diethanolamine.10. The aqueous modified acid composition according to any one of to claim 2 , further comprising a metal iodide or iodate.11. The composition according to claim 1 , wherein the mineral acid is selected from the group consisting of: HCl claim 1 , nitric acid claim 1 , sulfuric acid claim 1 , ...

THIOL ADDUCTS FOR CORROSION INHIBITION

Compounds, compositions and methods are provided for inhibiting corrosion at a surface in the production, transportation, storage, and separation of fluids such as crude oil and natural gas, the compounds having the formula: 5. The composition of claim 4 , wherein the component comprises the organic solvent claim 4 , and the organic solvent comprises an alcohol claim 4 , a hydrocarbon claim 4 , a ketone claim 4 , an ether claim 4 , an alkylene glycol claim 4 , a glycol ether claim 4 , an amide claim 4 , a nitrile claim 4 , a sulfoxide claim 4 , an ester claim 4 , or a combination thereof claim 4 , and the composition optionally comprises water.6. The composition of claim 4 , wherein the component comprises the organic solvent claim 4 , and the organic solvent comprises methanol claim 4 , ethanol claim 4 , propanol claim 4 , isopropanol claim 4 , butanol claim 4 , 2-ethylhexanol claim 4 , hexanol claim 4 , octanol claim 4 , decanol claim 4 , 2-butoxyethanol claim 4 , methylene glycol claim 4 , ethylene glycol claim 4 , 1 claim 4 ,2-propylene glycol claim 4 , 1 claim 4 ,3-propylene glycol claim 4 , diethyleneglycol monomethyl ether claim 4 , diethylene glycol monoethyl ether claim 4 , ethylene glycol monobutyl ether claim 4 , ethylene glycol dibutyl ether claim 4 , pentane claim 4 , hexane claim 4 , cyclohexane claim 4 , methylcyclohexane claim 4 , heptane claim 4 , decane claim 4 , dodecane claim 4 , diesel claim 4 , toluene claim 4 , xylene claim 4 , heavy aromatic naphtha claim 4 , cyclohexanone claim 4 , diisobutylketone claim 4 , diethyl ether claim 4 , propylene carbonate claim 4 , N-methylpyrrolidinone claim 4 , N claim 4 ,N-dimethylformamide claim 4 , or a combination thereof.7. The composition of claim 4 , wherein the component comprises the corrosion inhibitor claim 4 , and the corrosion inhibitor comprises an imidazoline compound claim 4 , a quaternary ammonium compound claim 4 , a pyridinium compound claim 4 , or a combination thereof.8. The composition of ...

Compositions For Use In Corrosion Protection

The invention relates to compositions, methods and preparation of such compositions to protect metals from corrosion, especially acid corrosion. The compositions of this invention may be added to acids to protect metals from their corrosive influence, particularly at elevated temperatures. These compositions are of particular utility in the oil and gas (petroleum) industry. Also disclosed are “corrosion inhibition intensifiers” to enhance the corrosion inhibition properties of other corrosion inhibitors. Formulations which control ferric ions in acidic solutions are also disclosed. These may be combined with inhibited acids and some compositions provide both corrosion inhibition and ferric ion control. 1. A composition comprising an acidic solution with a corrosion inhibiting additive , the corrosion inhibiting additive comprising a low water solubility material which is dispersible in an aqueous medium as particles whose surfaces are modified by a surface functionalization agent with a molecular weight of at least 60.2. The composition of wherein the low water solubility material comprises a cuprous salt.3. The composition of claim 1 , wherein the surface functionalization agent is selected from at least one of PVP claim 1 , PVP copolymer claim 1 , surfactant claim 1 , an organic acid and a salt of an organic acid.4. The composition of where the corrosion inhibiting additive further comprises at least three materials selected from the following categories claim 1 , wherein at least one material is selected from each of these categories:(a) cationic surfactant;(b) phenylpropanoid, and(c) and a material selected from at least one of a monomeric material and a nitrogen containing material.5. The composition of wherein the corrosion inhibiting additive comprises at least one additional metal compound selected from a Cu compound which is different from the cuprous salt in and compounds of a metal selected from Li claim 1 , Na claim 1 , K claim 1 , V claim 1 , Co claim 1 ...

WATER REMOVAL FROM ANTI-AGGLOMERATE LDHIS

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. 1. A method of controlling corrosion in a subsea pipeline comprising:supplying a low dose inhibitor stream (“LDHI”) comprising a quaternary amine;combining an internal desiccant with the LDHI stream to form a dried LDHI stream; andinjecting the dried LDHI into the subsea pipeline.3. The method of claim 2 , wherein R1 and R2 comprise a heterocyclic claim 2 , polycyclic claim 2 , or substituted aromatic ring.4. The method of claim 3 , wherein R1 and R2 are selected from the group consisting of acetic anhydride claim 3 , succinic anhydride claim 3 , maleic anhydride claim 3 , propionic anhydride claim 3 , butanoic anhydride claim 3 , ethanoic anhydride claim 3 , benzoic anhydride claim 3 , methanoic-propane anhydride claim 3 , phthalic anhydride claim 3 , and mixtures thereof.5. The method of claim 1 , wherein the internal desiccant is a metal oxide.6. The method of claim 5 , wherein the internal desiccant is selected from the group consisting of a barium oxide claim 5 , sodium pentoxide claim 5 , or phosphorus pentoxide.7. The method of claim 1 , wherein the internal desiccant is supplied continuously.8. The method of claim 1 , further comprising filtering the LDHI stream or the dried LDHI stream before injecting.9. The method of claim 8 , further comprising before the step of injecting the dried LDHI stream:monitoring a water content in the LDHI stream.10. A method of controlling corrosion in a subsea pipeline comprising:providing an LDHI stream, the LDHI stream containing water;determining a first maximum allowable water content of the LDHI stream;determining that a water content in the LDHI stream exceeds the first maximum allowable water content;drying the LDHI stream based upon the water content in the LDHI stream exceeding the first maximum allowable water content, so as to ...

CORROSION INHIBITOR SYSTEMS FOR LOW, MODERATE AND HIGH TEMPERATURE FLUIDS AND METHODS FOR MAKING AND USING SAME

A corrosion control system is disclosed including an anionic oxygen inhibitor, a cationic acid inhibitor or dispersant, and a noxious species inhibitor or scavenger for use in a fluid in contact with a metallic surface at low temperature, moderate temperature and especially at high temperature. A drilling fluid, a completion fluid, a production fluid and a geothermal fluid including an effective amount of the corrosion control system is also disclosed as well as methods for making and using same. 1. An aqueous drilling fluid comprising:water andeffective amount of a corrosion control system including an anionic scale inhibitor, a cationic acid inhibitor or dispersant, and a noxious species inhibitor or scavenger to a fluid in contact with a metallic surface.2. The drilling fluid of claim 1 , further comprising:a density reduction additive.3. The drilling fluid of claim 1 , further comprising:a shale inhibitor.4. The drilling fluid of claim 1 , further comprising:a pH modifier present in an amount sufficient to adjust the pH of the drilling fluid to pH 10.0.5. A corrosion control system comprising an anionic scale inhibitor claim 1 , a cationic acid inhibitor or dispersant claim 1 , and a noxious species inhibitor or scavenger to a fluid in contact with a metallic surface6. The system of claim 5 , further comprising:a pH modifier.7. The system of claim 6 , wherein the pH modifier is KOH or lime.8. The system of claim 5 , wherein the system has a pH of about 10.0.9. A corrosion control system comprising an anionic oxygen inhibitor claim 5 , a cationic acid inhibitor or dispersant claim 5 , and a noxious species inhibitor or scavenger for use in an oil or gas well fluid during drilling claim 5 , completion claim 5 , production claim 5 , fracturing or second oil recovery operations.10. A water-base drilling fluid for use in drilling wells through a formation containing a clay which swells in the presence of water claim 5 , the drilling fluid comprising:(a) a weight ...

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

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 of inhibiting the corrosive and toxic effects of a reactive sulfur species in a sulfur-containing hydrocarbon containing material from a natural geological formation containing , comprising:providing a substantially surfactant-free, non-aqueous turpentine liquid selected from the group consisting of natural turpentine, synthetic turpentine, mineral turpentine, pine oil, α-pinene, β-pinene, α-terpineol, β-terpineol, γ-terpineol, terpene resins, α-terpene, β-terpene, γ-terpene, geraniol, 3-carene, dipentene (p-mentha-1,8-diene), nopol, pinane, 2-pinane hydroperoxide, terpin hydrate, 2-pinanol, dihydromycenol, isoborneol, p-menthan-8-ol, α-terpinyl acetate, citronellol, p-menthan-8-yl acetate, 7-hydroxydihydrocitronellal, menthol, anethole, camphene; p-cymene, anisaldeyde, 3,7-dimethyl-1,6-octadiene, isobornyl acetate, ocimene, alloocimene, alloocimene alcohols, 2-methoxy-2,6-dimethyl-7,8-epoxyoctane, camphor, citral, 7-methoxydihydro-citronellal, 10-camphorsulphonic acid, cintronellal, menthone, and mixtures thereof;contacting the sulfur-containing hydrocarbon-containing material with the substantially surfactant-free, non-aqueous turpentine liquid such that at least a portion of the reactive sulfur species from said sulfur-containing hydrocarbon containing material is extracted into the substantially surfactant-free, non-aqueous turpentine liquid from the natural geological formation; andrecovering hydrocarbon containing material from which reactive sulfur species has been removed such that the corrosive and toxic effects of ...

FLUORO-INORGANICS FOR ACIDIFICATION OR NEUTRALIZATION OF WATER SYSTEMS

The present invention generally relates to methods for reducing the pH of aqueous mixtures with the advantage of preventing formation of deposits and scales on internal surfaces in contact with the aqueous systems. These methods also that the advantages that they reduce pH with less corrosion or metal loss of the internal surface as compared with a conventional strong acid used to reduce the pH in such systems. The methods use an acid composition comprising a salt of a nitrogen base having a fluoro inorganic anion. 1. A method for reducing the pH of an aqueous system comprising contacting an acid composition with an internal surface of a piece of equipment ,wherein the acid composition comprises a salt of a nitrogen base having a fluoro inorganic anion.2. A method for reducing the pH of an aqueous system comprising contacting an acid composition with an aqueous mixture that contacts an internal surface of a piece of equipment ,wherein the acid composition comprises a salt of a nitrogen base having a fluoro inorganic anion.3. The method of claim 1 , wherein the aqueous system is a produced water claim 1 , a feedwater claim 1 , a surface water claim 1 , a ground water claim 1 , or a combination thereof.4. The method of claim 1 , wherein the acid composition further comprises a surfactant.5. The method of claim 4 , wherein the surfactant is a nonionic surfactant.6. The method of claim 3 , wherein the acid composition further comprises a corrosion inhibitor.79.-. (canceled)10. The method of claim 1 , wherein the acid composition removes inorganic deposits.11. The method of claim 10 , wherein the piece of equipment is a boiler claim 10 , a steam generator claim 10 , an evaporator claim 10 , a heat exchanger claim 10 , a tube bundle claim 10 , a cooling coil claim 10 , a chiller claim 10 , a tank claim 10 , a sump claim 10 , a containment vessel claim 10 , a pump claim 10 , a distributor plate claim 10 , a geothermal injection well claim 10 , a geothermal production well ...

SYSTEM AND METHOD FOR GENERATION OF POINT OF USE REACTIVE OXYGEN SPECIES

Systems and methods for generating reactive oxygen species formulations useful in various oxidation applications. Exemplary formulations include singlet oxygen or superoxide and can also contain hydroxyl radicals or hydroperoxy radicals, among others. Formulations can contain other reactive species, including other radicals. Exemplary formulations containing peracids are activated to generate singlet oxygen. Exemplary formulations include those containing a mixture of superoxide and hydrogen peroxide. Exemplary formulations include those in which one or more components of the formulation are generated electrochemically. Formulations of the invention containing reactive oxygen species can be further activated to generate reactive oxygen species using activation chosen from a Fenton or Fenton-like catalyst, ultrasound, ultraviolet radiation or thermal activation. Exemplary applications of the formulations of the invention among others include: cleaning in place applications, water treatment, soil decontamination and flushing of well casings and water distribution pipes. 127-. (canceled)28. A superoxide formulation comprising:an aqueous mixture of a hydrogen peroxide and a superoxide;wherein the mixture has a molar ratio of superoxide to hydrogen peroxide ranging from 0.01:1 to 10:1 and a pH from 8 to a pH of 13.29. The superoxide formulation of claim 28 , wherein the formulation is electrochemically generated.30. The superoxide formulation of claim 28 , wherein the pH is from pH 11 to pH 13.31. The superoxide formulation of claim 30 , wherein the formulation is stable.32. The superoxide formulation of claim 28 , wherein the superoxide formulation comprises an acid concentrate.33. The superoxide formulation of claim 28 , wherein the superoxide formulation comprises an additives concentrate.34. The superoxide formulation of claim 33 , wherein said additives concentrate comprise salts claim 33 , surfactants claim 33 , co-solvents claim 33 , stabilizers and/or emulsifiers ...

SYNTHETIC CORROSION LOGS THROUGH SUBSURFACE SPATIAL MODELING

Systems and methods include a computer-implemented method for generating synthetic corrosion logs. Processed corrosion log data is generated from historical corrosion logs of previously-drilled wells. A subset of the historical corrosion logs is selected, including selecting metal loss points to use as seed points for generating a corrosion model. The corrosion model is generated using the seed points, including using spatial interpolation to fill gaps between seed points. The corrosion model is validated by iteratively comparing seed logs and test logs to the corrosion model to ensure that the corrosion model fits the seed points within a threshold. A confidence interval is computed for each target location of a target well as a function of synthetic values associated with the seed points. A synthetic log is generated for the target well using the corrosion model, the target locations, and corresponding confidence intervals at each depth level of the target well. 1. A computer-implemented method , comprising:generating processed corrosion log data from historical corrosion logs of previously-drilled wells;selecting a subset of the historical corrosion logs from the processed corrosion log data, including selecting metal loss points from the subset to use as seed points for generating a corrosion model;generating the corrosion model using the seed points, including using spatial interpolation to fill gaps between seed points;validating the corrosion model by iteratively comparing seed logs and test logs to the corrosion model to ensure that the corrosion model fits the seed points within a threshold;computing a confidence interval for each target location of a target well as a function of synthetic values associated with the seed points; andgenerating a synthetic log for the target well using the corrosion model, the target locations, and corresponding confidence intervals at each depth level of the target well.2. The computer-implemented method of claim 1 , wherein ...

Corrosion inhibitors

The present invention provides the use of a sulfosuccinate as a corrosion inhibitor. In particular, the sulfosuccinate may be used to inhibit the corrosion of a metal component that is, or will be, in contact with an aqueous fluid, in order to prevent or reduce corrosion of the metal component. The sulfosuccinate may be used to inhibit corrosion of a metal component in an industrial aqueous system, such as a hydrocarbon plant; a chemical plant; a water plant; or a paper manufacturing plant, and in particular in an oilfield system or a downstream oil-related system.

Controlled-Release Chemical Particulate Composition for Well Treatment

The present disclosure relates to a composition comprising an active chemical agent adsorbed into a non-water-soluble carrier composed, at least in part, of corn grit. The present composition is useful for inhibiting scale or other undesirable formations. The composition may be introduced into the target during the stimulation or production treatment of an oil or gas well. The composition may be formed by adsorbing a liquid chemical agent onto a solid substrate of corn-based material called corn grit. The crush resistance and liquid-insolubility of corn grit help enable the composition to release the treatment chemical into the well over time. The liquid chemical combined with the solid substrate can be used as a well treatment agent for scale inhibitors, corrosion inhibitors, surfactants, non-emulsifiers, halite inhibitors, wettability modifiers, paraffin and asphaltene inhibitors, and water and oil-soluble tracers. 1. An oil or gas well-treating composition comprising:a first non-water-soluble carrier comprising corn grit, and a first active chemical agent adsorbed by the first non-water-soluble carrier;wherein the first non-water-soluble carrier provides a controlled release of the first active chemical agent.2. The composition of wherein the controlled release provides about 12 months of continuous treatment.3. The composition of claim 1 , wherein the first non-water-soluble carrier is a natural milled or ground particulate from woody rings of corn cobs.4. The composition of claim 1 , wherein the first active chemical agent is designed to inhibit at least one of scale claim 1 , corrosion claim 1 , emulsions claim 1 , salt formation claim 1 , clay swelling claim 1 , fine migration claim 1 , paraffin claim 1 , asphaltenes claim 1 , biological growth claim 1 , gels claim 1 , or cross-linking.5. The composition of claim 1 , further comprising a second active chemical agent adsorbed by the first non-water-soluble carrier.6. The composition of claim 5 , wherein the ...

Organoclay compositions and oil-based drilling fluid comprising the clays

An organoclay composition comprising a mineral clay mixture which has been treated with a combination of quaternary ammonium salts, said mixture comprising: mineral clay (a) comprising about 15 to about 60 wt. %, based on the weight of the mineral clay mixture, of sepiolite; mineral clay (b) comprising about 40 to about 85 wt. % based on the weight of the mineral clay mixture, of montmorillonite; an alkyl or alkenyl quaternary ammonium salt and an alkoxylated quaternary ammonium salt.

METHODS OF CONTROLLING VISCOSITY OF ACIDS

A method is described for treating a subterranean formation penetrated by a wellbore including injecting into the formation a treatment fluid including a rheological modifier; at least one viscoelastic surfactant (VES) at a concentration of between about 0.1 and about 10 percent by weight; and a formation-dissolving agent selected from the group consisting of hydrochloric acid, formic acid, acetic acid, lactic acid, glycolic acid, sulfamic acid, malic acid, citric acid, tartaric acid, maleic acid, methylsulfamic acid, chloroacetic acid, aminopolycarboxylic acids, 3-hydroxypropionic acid, polyaminopolycarboxylic acids, salts thereof and mixtures of said acids and salts. 1. A method of treating a subterranean formation penetrated by a wellbore comprising: at least one viscoelastic surfactant (VES) at a concentration of between about 0.1 and about 10 percent by weight; and', 'a formation-dissolving agent selected from the group consisting of hydrochloric acid, formic acid, acetic acid, lactic acid, glycolic acid, sulfamic acid, malic acid, citric acid, tartaric acid, maleic acid, methylsulfamic acid, chloroacetic acid, aminopolycarboxylic acids, 3-hydroxypropionic acid, polyaminopolycarboxylic acids, salts thereof and mixtures of said acids and salts, and', 'a rheology modifier., 'injecting into said formation a treatment fluid comprising2. The method of wherein said treatment fluid is a matrix acidizing fluid.3. The method of wherein said treatment fluid is an acid fracturing fluid.4. The method of wherein said treatment fluid is a diversion fluid.5. The method of wherein the VES comprises a zwitterionic surfactant.8. The method of wherein R is CH claim 7 , and n=3 and p=1.9. The method of wherein R is CH claim 7 , and n=3 and p=1.10. The method of wherein the rheology modifier is a surfactant claim 1 , polymer or corrosion inhibitor.11. The method of wherein the surfactant is anionic claim 10 , cationic or nonionic claim 10 , or a mixture thereof.12. The method of ...

DOWNHOLE FLUIDS AND METHODS OF USE THEREOF

The present disclosure relates to downhole fluid additives including a clay, a hydroxylated polymer, a cation, and water. The disclosure further relates to downhole fluids, including drilling fluids, spaces, cements, and proppant delivery fluids containing such as downhole fluid additive and methods of using such fluids. The downhole fluid additive may have any of a variety of functions in the downhole fluid and may confer any of a variety of properties upon it, such as salt tolerance or desired viscosities even at high downhole temperatures. 133-. (canceled)34. A spacer , comprising:a clay;a hydroxylated polymer;a cation;the clay, the hydroxylated polymer, and the cation together in an amount sufficient to render the downhole fluid thermally stable at a temperature of 400° F.; andat least one additional downhole fluid component.35. The spacer of claim 34 , wherein the clay comprises a phyllosilicate clay.36. The spacer of claim 35 , wherein the phyllosilicate clay comprises a smectite clay claim 35 , a sepiolite clay or a palygorskite clay.37. The spacer of claim 34 , further comprising salt water.38. The spacer of claim 34 , further comprising a surfactant claim 34 , a defoamer claim 34 , a salt claim 34 , a viscosifier or any combinations thereof.39. The spacer of claim 38 , wherein the salt comprises sodium chloride or calcium chloride.40. The spacer of claim 38 , wherein the viscosifier comprises nanoparticles of 100 nm or less in size.41. The spacer of claim 34 , wherein the at least one additional downhole fluid component is an aqueous component with a pH of at least 9.42. The spacer of claim 34 , wherein the spacer has a transition temperature of around 150° F. at which viscosity rapidly increases.43. The spacer of claim 34 , wherein the hydroxylated polymer comprises microcellulose or nanocellulose.44. A system for introducing a spacer into a subterranean formation claim 34 , the system comprising: a clay;', 'a hydroxylated polymer;', 'a cation;', 'the clay ...

INVERSE POLYMER EMULSION WITH SPECIFIC EMULSIFIER PACKAGE FOR POLYMER FLOODING

A method to manufacture stable water-in-oil polymer emulsion with low viscosity by using special stabilizing surfactant package is disclosed. 1. A method for treatment of subterranean oil and gas reservoirs comprising the steps of:(i) providing a water-in-oil polymer emulsion containing water-soluble polymer in the aqueous phase, the aqueous phase finely dispersed in the continuous hydrophobic organic phase and the droplets stabilized by a surfactant package containing a first surfactant having a HLB-value between 3 and 9 and a second surfactant being an alkyl polyglycoside having a HLB-value of greater than 11 or a mixture of alkyl polyglycosides having a HLB-value of greater than 11,(ii) preparing an aqueous treatment fluid by inversion of said emulsion into water that may contains salts and optionally an inverter surfactant composition,(iii) optionally adding additives, e.g. oxygen and/or radical scavenger and(iv) introducing the aqueous treatment fluid into the subterranean oil and gas reservoir formation.2. The method of claim 1 , wherein the aqueous phase which includes the water-soluble polymer is present in an amount from 40 to 90 wt.-% claim 1 , preferable 60 to 75 wt.-% claim 1 , based on the total emulsion.3. The method of claim 1 , wherein the polymer claim 1 , preferably the copolymer or terpolymer claim 1 , content of the water-in-oil emulsion is from 20 to 50 wt.-% claim 1 , preferably between 25 to 35 wt.-% claim 1 , based on the total emulsion.4. The method of claim 1 , wherein the water-soluble polymer is a synthetic polymer claim 1 , preferably a synthetic copolymer or terpolymer.6. The method of claim 5 , wherein the synthetic copolymer is selected from the group consisting of polymers containing:(I) 10 to 90% by weight of structural formula I, preferred from 20 to 70% by weight,(II) 0 to 95% by weight of structural formula II, preferred from 10 to 80% by weight, more preferred from 20 to 60% by weight,(III) 0 to 30% by weight of structural ...

METHOD OF REMOVING MINERAL SCALES FROM A SUBSTRATE WITH MINIMIZED CORROSION OF THE SUBSTRATE

A method of removing mineral scales from a substrate with minimized corrosion of the substrate includes the steps of providing an acid solution providing a corrosion inhibitor solution, applying the acid solution to the substrate to remove mineral scales therefrom, and applying the corrosion inhibitor solution to the substrate to minimize corrosion thereof. The acid solution includes a mineral acid, an organic acid, or a combination thereof. The corrosion inhibitor solution includes an alpha-beta unsaturated aldehyde, a hydrophobic amine, and an oxime. The corrosion inhibitor solution optionally includes formic acid, a surfactant, and a solvent. 1. A method of removing mineral scales from a substrate with minimized corrosion of the substrate , said method comprising the steps of:providing an acid solution comprising a mineral acid, an organic acid, or a combination thereof; an alpha-beta unsaturated aldehyde;', 'a hydrophobic amine; and', 'an oxime; and optionally formic acid;', 'a surfactant; and', 'a solvent;, 'providing a corrosion inhibitor solution comprisingapplying the acid solution to the substrate to remove mineral scales therefrom; andapplying the corrosion inhibitor solution to the substrate to minimize corrosion thereof.2. The method of wherein the alpha-beta unsaturated aldehyde is cinnamaldehyde.3. The method of wherein the corrosion inhibitor solution further comprises the formic acid claim 1 , the surfactant claim 1 , and the solvent.4. The method of wherein the hydrophobic amine is chosen from oleyl-propanediamine claim 1 , cocopropanediamine claim 1 , soyapropanediamine claim 1 , tallowpropanediamine claim 1 , and combinations thereof.5. The method of wherein the hydrophobic amine is oleyl-propanediamine.6. The method of wherein the oxime is chosen from methyl ethyl ketoxime claim 1 , cyclohexanone oxime claim 1 , and combinations thereof.7. The method of wherein the oxime is methyl ethyl ketoxime.8. The method of further comprising the step of ...

CAPSULES, SYSTEMS AND METHODS FOR TARGETED DELIVERY OF CHEMICALS INTO MULTIPHASE ENVIRONMENTS

Capsules, systems and methods for delivering chemical components to multiphase environments are disclosed. The systems and methods utilize delivery capsules within which the chemical components are encapsulated. The chemical components may be corrosion inhibitors or biocides and the multiphase environment an oil/water environment, for example, within an oil transport pipeline. The systems and methods allow delivery of the capsules to targeted areas of the multiphase environment, for example, to a water phase or a water/metal interface. 1. A chemical component delivery system , said system comprising a plurality of delivery capsules , said delivery capsules comprising one or more chemical components encapsulated within shells , said shells being degradable and/or soluble in an aqueous environment.2. A method of delivering chemical components to a water phase or water/vessel wall interface of a multiphase environment comprising the steps of:introducing one or more delivery capsules to a multiphase environment, said capsules comprising one or more chemical components encapsulated within shells, said shells being degradable and/or soluble in an aqueous environment;allowing the capsules to migrate to the water phase or water/vessel wall interface; andallowing the components to be released from the delivery capsules.3. A system according to or a method according to , wherein the chemical components comprise one or more corrosion inhibitors , one or more biocides , or mixtures thereof.4. A system according to or a method according to , wherein at least a first fraction of capsules comprise one or more of a first set of chemical components encapsulated therein , and at least a second fraction of capsules comprise one or more of a second set of chemical components encapsulated therein , wherein the second set of chemical components comprise at least some chemicals which are different to those of the first set.5. A system according to or a method according to , comprising at ...

NANOPARTICLE BIOCIDE IN INDUSTRIAL APPLICATIONS

A method includes providing a measured dose amount of manufactured metallic nanoparticle material and adding the measured dose amount of the manufactured metallic nanoparticle material to a sub-surface earth activity material to a sub-surface earth activity material for treatment corresponding to the sub-surface earth activity. A composition of silver in the form of silver nanoparticles in suspension having an interior of non-metallic material and a surface of silver dioxide, a maximum diameter less than about 100 nanometers, a minimum diameter of greater than about 2 nanometers, and biocidal properties. 1. A method for using a metallic nanoparticle material in conjunction with sub-surface earth activity , the method comprising:providing a measured dose amount of manufactured metallic nanoparticle material, wherein the metallic nanoparticle material comprises nanoparticles with a non-metallic core and a metallic shell; andadding the measured dose amount of the manufactured metallic nanoparticle material to a sub-surface earth activity material for treatment corresponding to the sub-surface earth activity.2. The method of claim 1 , wherein the sub-surface earth activity material comprises a pre-drilling material prepared prior to use in the sub-surface earth activity.3. The method of claim 1 , wherein the sub-surface earth activity material comprises an active drilling material supplied into an active environment of the sub-surface earth activity.4. The method of claim 1 , wherein the sub-surface earth activity material comprises a post-drilling material for treatment of a product of the sub-surface earth activity.5. The method of claim 1 , further comprising using the sub-surface earth activity material and the manufactured metallic nanoparticle material to chemically decompose at least a portion of hydrogen sulfide (HS) and/or hydrosulfide ions (HS) exposed to the sub-surface earth activity material and the manufactured metallic nanoparticle material.6. The method ...

Foaming composition with wettability modifying and corrosion inhibitory properties for high temperature and ultra-high salinity

The present invention relates to a method of obtaining and using foaming compositions with wettability-modifying and corrosion inhibitory properties that control the channeling of fluids in naturally fractured carbonate reservoirs, favorably alter the rock wettability in crude oil enhanced recovery processes and control uniform corrosion problems occurring in production rigs under high temperature and ultra-high salinity conditions by the synergistic effect resulting from the supramolecular interaction of alkyl amido propyl hydroxysultaines or alkyl hydroxysultaines with sodium alkyl hydroxysulfonates and sodium alkenyl sulfonates having the formula (1). The foaming compositions with wettability-modifying and corrosion inhibitory properties are tolerant to high concentrations of divalent ions such as calcium, magnesium, strontium and barium and are suitable for use in the reservoir, seawater and/or congenital water characteristic of the reservoir for transporting the crude oil from the reservoir.

In-line treatment cartridge and methods of using same

An in-line treatment cartridge and methods of using same are disclosed. The in-line treatment cartridge can include a cylindrical body configured to allow fluid to flow therethrough and a plurality of particulates contained within the body. At least one particulate of the plurality of particulates can include a chemical treatment agent. The at least one chemical treatment agent can separate from the at least one particulate upon contact with a fluid.

ANTICORROSIVE COMPOSITION

The present invention relates to the discovery that melanoidins, and higher molecular weight fractions of products containing melanoidins, provide significant corrosive inhibition, which render these melanoidins suitable for use as anticorrosive agents in corrosive environments. In addition to being highly anticorrosive, the melanoidins of the present invention are environmentally friendly and non-toxic, and can be found in animal food and in human foodstuffs. 1. A method of reducing the corrosion caused by a chloride salt , the method comprising the steps of:obtaining a molecular weight fraction of a product containing melanoidins, wherein the molecular weight fraction comprises melanoidins having a molecular weight greater than or equal to 12,400;forming an aqueous solution including the molecular weight fraction of a product containing melanoidins; andapplying the solution to a metal surface, wherein the molecular weight fraction of a product containing melanoidins reduces corrosion at the metal surface caused by the chloride salt.2. The method of claim 1 , wherein the metal surface contains iron.3. The method of claim 1 , wherein the product containing melanoidins is selected from the group consisting of sugar cane and sugar beets.4. The method of claim 1 , wherein the product containing melanoidins is selected from the group consisting of molasses claim 1 , corn steep liquor claim 1 , brewers condensed solubles claim 1 , and distillers condensed solubles.5. The method of claim 1 , wherein the metal surface is a roadway.6. The method of claim 1 , wherein the metal surface is an oil well surface.7. The method of claim 1 , wherein the chloride salt is at least one selected from the group consisting of sodium chloride claim 1 , magnesium chloride claim 1 , calcium chloride claim 1 , and potassium chloride.8. The method of claim 1 , wherein the chloride salt is an industrial brine.9. The method of claim 1 , further comprising the step of adding a carbohydrate having ...

USE OF SULFONIUM SALTS AS CORROSION INHIBITORS

The present invention generally relates to the use of aryl sulfonium salts as a corrosion inhibitor in a water injection system, a hydrocarbon extraction system, or a hydrocarbon production system. Treating oilfield injection and produced fluids with aryl sulfonium salts can significantly decrease microbially induced corrosion. Thus, these aryl sulfonium salts can be effectively used as corrosion inhibitors in oilfield fluids. 1. A method of inhibiting corrosion at a surface , the method comprising contacting the surface with an effective amount of an anticorrosion composition comprising an aryl sulfonium salt or mixture of aryl sulfonium salts , wherein the surface is in contact with a hydrocarbon-containing fluid.2. The method of claim 1 , wherein the anticorrosion composition is effective to reduce microbially induced corrosion.4. (canceled)5. The method of claim 3 , wherein the aryl sulfonium salt comprises a cation of Formula 2.6. The method of claim 3 , wherein the aryl sulfonium salt comprises a dication of Formula 3.7. The method of claim 3 , wherein the aryl sulfonium salt comprises a cation of Formulae 1 and 2.8. The method of claim 3 , wherein the aryl sulfonium salt comprises a cation of Formula 1 and a dication of Formula 3.9. The method of claim 3 , wherein the aryl sulfonium salt comprises a cation of Formula 2 and a dication of Formula 3.10. The method of claim 3 , wherein the aryl sulfonium salt comprises a cation of Formulae 1 and 2 claim 3 , and a dication of Formula 3.11. (canceled)12. The method of claim 10 , wherein one to three of R-Rare independently alkyl and the balance are hydrogen.13. The method of claim 10 , wherein R-Rare hydrogen.14. The method claim 3 , wherein the counterion for the aryl sulfonium salt is chloride claim 3 , bromide claim 3 , fluoride claim 3 , iodide claim 3 , nitrate claim 3 , perchlorate claim 3 , sulfonate claim 3 , carbonate claim 3 , chromate claim 3 , hexafluoroarsenate claim 3 , hexafluorophosphate claim 3 , p ...

AMIDODIAMINE CORROSION INHIBITORS

Methods for providing corrosion inhibition in conduits, containers, and wellbores penetrating subterranean formations are provided. In some embodiments, the methods comprise contacting a metal surface with a fluid comprising a corrosion inhibitor additive. In certain embodiments, the corrosion inhibitor additive comprises a compound comprising a hydrophobic cation moiety, one or more lipophilic tails, and a linking moiety. 2. The method of claim 1 , wherein X is selected from the group consisting of: a carboxylate claim 1 , a halide claim 1 , a sulfate claim 1 , an organic sulfonate claim 1 , a hydroxide claim 1 , a phosphate claim 1 , a borate claim 1 , and any combination thereof.3. The method of claim 1 , further comprising the step of introducing the corrosion inhibitor additive to the fluid.4. The method of claim 1 , wherein at least one of R claim 1 , R claim 1 , and Rcomprise a heteroatom.5. The method of claim 1 , wherein the metal surface comprises carbon steel.6. The method of claim 1 , wherein the corrosion inhibitor additive is present in an amount from about 25 ppm to about 500 ppm based on the volume of the fluid.7. The method of claim 1 , wherein the fluid has a pH of from about 4 to about 10.8. The method of claim 1 , wherein each of Rand Ris a Cto Chydrocarbyl group resulting from a reaction between an acrylate or a methacrylate and an amine.9. The method of claim 8 , wherein the amine is a synthetic primary or secondary amine selected from the group consisting of: butylamine claim 8 , hexylamine claim 8 , octylamine claim 8 , dodecylamine claim 8 , N-methyldodecylamine claim 8 , N-methyloctylamine claim 8 , didodecylamine claim 8 , and any combination thereof.10. The method of claim 8 , wherein the amine is a primary or secondary fatty amine derived from one or more fatty acids selected from the group consisting of: tallow claim 8 , corn oil claim 8 , canola oil claim 8 , coconut oil claim 8 , safflower oil claim 8 , sesame oil claim 8 , palm oil ...

Composition to Reduce Friction Reducer Fouling in Wellbores

A method of spearheading an acid into a wellbore is adapted to avoid the gelation of a friction reducer polymer. The method comprises injecting a synthetic or modified acid composition down a wellbore, the composition comprising: a synthetic or modified acid; a solvent; and a chelating agent. Optionally the composition may comprise a corrosion inhibitor package. The method further includes allowing sufficient time for the synthetic or modified acid composition to react with material which require acidic treatment and injecting a fracturing composition comprising a liquid and a friction reducing polymer down the wellbore. 1. A method of spearheading an acid into a wellbore adapted to avoid the gelation of a friction reducer polymer , wherein said method comprises:injecting a synthetic acid composition down a wellbore, said composition comprising: a synthetic or modified acid; a solvent; and a chelating agent compound, optionally, the composition may comprise a corrosion inhibitor package;allowing sufficient time for the synthetic or modified acid composition to react with material which require acidic treatment;injecting a fracturing composition comprising a liquid and a friction reducing polymer down the wellbore.2. A method of spearheading an acid into a wellbore adapted to reduce the gelation of a friction reducer polymer , wherein said method comprises:injecting a synthetic or modified acid composition down a wellbore, said composition comprising: a synthetic or modified acid; a solvent; and a chelating agent compound, optionally, the composition may comprise a corrosion inhibitor package;allowing sufficient time for the synthetic or modified acid composition to react with material which require acidic treatment;injecting a fracturing composition comprising a liquid and a friction reducing polymer down the wellbore.3. The method according to where the modified acid is selected from the group consisting of: Urea-HCl; amino acid-HCl; and alkanolamine-HCl.4. The ...

Method of inhibiting fouling on a metallic surface using a surface modifying treatment agent

Fouling caused by contaminants onto a metallic tubular, flow conduit or vessel in an underground reservoir or extending from or to an underground reservoir may be inhibited by applying onto the surface of the metallic tubular, flow conduit or vessel a treatment agent comprising a hydrophobic tail and an anchor. The anchor attaches the treatment agent onto the surface of the metallic tubular, flow conduit or vessel.

Compounds with at least one cyclic urea moiety and their use in corrosion prevention

A compound comprises at least one cyclic urea moiety including a head portion and a tail portion connected through an amide moiety or a cyclic amidine moiety, wherein the head portion comprises a polyalkylenepolyamine structure comprising 3 to 10 C2-C4 alkylene moieties present between nitrogen atoms, wherein the alkylene moieties may be the same or different and may be substituted with one or more C1 to C3 alkyl groups, wherein at least one of the alkylene moieties together with its adjoining nitrogen atoms is in the form of a cyclic alkylene urea moiety of the formulawherein A is a C2 to C4 alkylene moiety which may be substituted with one or more C1 to C3 alkyl groups and wherein the tail portion includes an alkyl or alkenyl group with 6 to 24 carbon atoms which may be substituted.

SYSTEM AND METHOD FOR GENERATION OF POINT OF USE REACTIVE OXYGEN SPECIES

Systems and methods for generating reactive oxygen species formulations useful in various oxidation applications. Exemplary formulations include singlet oxygen or superoxide and can also contain hydroxyl radicals or hydroperoxy radicals, among others. Formulations can contain other reactive species, including other radicals. Exemplary formulations containing peracids are activated to generate singlet oxygen. Exemplary formulations include those containing a mixture of superoxide and hydrogen peroxide. Exemplary formulations include those in which one or more components of the formulation are generated electrochemically. Formulations of the invention containing reactive oxygen species can be further activated to generate reactive oxygen species using activation chosen from a Fenton or Fenton-like catalyst, ultrasound, ultraviolet radiation or thermal activation. Exemplary applications of the formulations of the invention among others include: cleaning in place applications, water treatment, soil decontamination and flushing of well casings and water distribution pipes. 1. A method for generating a reactive oxygen species formulation , the method comprising:generating an alkaline hydrogen peroxide solution;mixing the alkaline hydrogen peroxide solution with an acyl donor such that a peracid concentrate is produced, wherein the peracid concentrate has minimal hydrogen peroxide residual;adjusting the pH of the peracid concentrate to the activated pH range for generating the reactive oxygen species.2. The method of wherein the alkaline hydrogen peroxide solution is generated from the combination of an alkali and a hydrogen peroxide concentrate or wherein the alkaline hydrogen peroxide solution is generated electrochemically.3. The method of wherein the reactive oxygen species formulation is a singlet oxygen precursor formulation.4. The method of wherein the acyl donor is an acetyl donor.5. The method of wherein the hydrogen peroxide solution is generated using a molar ...

FUNCTIONALIZED HYDROGEN SULFIDE SCAVENGERS

Functionalized alpha-hydroxy alkyl ethers have been found to perform as non (or anti-) scaling hydrogen sulfide scavengers. A method of scavenging hydrogen sulfide includes contacting a fluid containing hydrogen sulfide with a treatment fluid including a functionalized alpha-hydroxy alkyl ether. Accordingly, the alpha-hydroxy alkyl ether reacts with the hydrogen sulfide to reduce the amount of hydrogen sulfide in the fluid. The functionalized alpha-hydroxy alkyl ether is functionalized with a phosphate group, phosphonate group, sulfate group, or sulfonate group. A broad range of alpha-hydroxy alkyl ethers are disclosed. 1. A method , comprising:contacting a fluid containing hydrogen sulfide with a treatment fluid including a functionalized alpha-hydroxy alkyl ether, wherein the hydrogen sulfide reacts with the functionalized alpha-hydroxy alkyl ether to reduce an amount of the hydrogen sulfide in the fluid, and wherein the functionalized alpha-hydroxy alkyl ether is functionalized with a phosphate group, phosphonate group, sulfate group, or sulfonate group.2. The method of claim 1 , wherein the alpha-hydroxy alkyl ether is the reaction product on an alcohol and an aldehyde claim 1 , and wherein the alcohol claim 1 , the aldehyde claim 1 , or both the alcohol and the aldehyde are functionalized.3. The method of claim 2 , wherein the alcohol is selected from mono-alcohols claim 2 , a di-alcohols claim 2 , oligomeric alcohols claim 2 , and polymeric alcohols.4. The method of claim 2 , wherein the aldehyde is selected from a mono-aldhydes claim 2 , di-aldehydes claim 2 , oligomeric aldehydes claim 2 , and polymeric aldehydes.5. The method of claim 1 , wherein the alpha-hydroxy alkyl ether has no nitrogen or basic nitrogen.6. The method of claim 1 , wherein the alpha-hydroxy alkyl ether includes two phosphate groups claim 1 , two phosphonate groups claim 1 , two sulfate groups claim 1 , or two sulfonate groups.7. The method of claim 1 , wherein the alpha-hydroxy alkyl ...

Well treatment composites for use in well treatment fluids

A well treatment composite comprising a well treatment agent adsorbed onto a water-insoluble adsorbent may be prepared by precipitating the well treatment agent, in the presence of a metal salt, from a liquid while the well treatment agent is being adsorbed onto the water-insoluble adsorbent. After a treatment fluid containing the composite is introduced into a well or a subterranean formation, the well treatment agent is slowly released from the composite. The composite permits a continuous supply of the well treatment agent into a targeted area and is particularly effective in high pH treatment fluids.

Rotary Steerable Drilling Tool and Method

A directional drilling system includes a rotary steerable tool. The rotary steerable tool includes an extendable member configured to extend outwardly from the rotary steerable tool upon actuation, and a geolocation electronics device configured to track a position of the rotary steerable tool and the extendable member and control actuation of the extendable member. The geolocation electronics device and extendable member are configured to rotate with the rotary steerable tool. 1. A directional drilling system for drilling a directional well , comprising:a drill string; and drill bit;', 'a tool body;', 'extendable members coupled to the tool body and each independently movable between an extended position and a retracted position with respect to the tool body;', 'a sensor configured to measure a position of the directional drilling system; and', 'a processor in communication with the sensor and operable to receive measurements from the sensor and, based on the measurements, to control actuation of the extendable members independently of each other., 'a tool string connected with the drill string and comprising2. The system of claim 1 , further comprising valves each being independently actuable by the processor to control movement of a respective extendable member via communication of hydraulic pressure from a hydraulic source.3. The system of claim 2 , wherein each valve is actuable to provide communication between one of the extendable members and an annulus outside of the tool body to allow the respective extendable member to move from the extended position to the retracted position.4. The system of claim 2 , further comprising:first flow paths, each connecting one of the valves and one of the extendable members; andsecond flow paths, each connecting one of the valves and an annulus outside of the tool body.5. The system of claim 4 , further comprising a restriction along each of the second flow paths to restrict fluid flow from one of the valves to the annulus.6 ...

GREEN COMPOSITIONS FOR USE IN DOWNHOLE AND INDUSTRIAL APPLICATIONS

Crude oil may be treated with an additive made with Tire Pyrolysis Oil and naphtha, condensate, or both naphtha and condensate. Also disclosed herein are compositions including Tire Pyrolysis Oil wherein the composition is selected from the group consisting of: pipeline cleaner, tank cleaner, paraffin inhibitor or modifier, asphaltene inhibitor or modifier, scale inhibitor, corrosion inhibitor, stimulation fluid, crude oil density reducer, and crude oil viscosity reducer. The Tire Pyrolysis Oil is a green product recovered from recycling tires. 1. A composition comprising Pyrolysis Oil wherein the composition is selected from the group consisting of: pipeline cleaner , tank cleaner , paraffin inhibitor or modifier , asphaltene inhibitor or modifier , scale inhibitor , corrosion inhibitor , stimulation fluid , crude oil density reducer , and crude oil viscosity reducer.2. The composition of wherein the composition is a pipeline cleaner.3. The composition of wherein the composition is a tank cleaner.4. The composition of wherein the composition is a paraffin inhibitor or modifier.5. The composition of wherein the composition is an asphaltene inhibitor or modifier.6. The composition of wherein the composition is a scale inhibitor.7. The composition of wherein the composition is a corrosion inhibitor.8. The composition of wherein the composition is a stimulation fluid.9. The composition of wherein the composition is a crude oil density reducer.10. The composition of wherein the composition is a crude oil viscosity reducer.11. The composition of where in the Pyrolysis Oil is prepared using the method of U.S. Pat. No. 6 claim 1 ,835 claim 1 ,861.12. The composition of where in the Pyrolysis Oil is prepared using the method of U.S. Patent Publication No. 2008/0096787.13. A crude oil additive comprising naphtha and Pyrolysis Oil.14. A crude oil additive comprising condensate and Pyrolysis Oil.15. A method for reducing the viscosity of crude oil comprising introducing a ...

Multifunctional composition base 1,3-oxazinan-6-ones with corrosion inhibition and heavy organic compounds inhibition and dispersants and obtaining process

Base compounds including 1,3-oxazinan-6-one derivatives of N-alkyl or N-alkenyl or N-cycloalkyl or N-aryl propionic acids and paraformaldehyde, and their application as corrosion inhibitors with multifunctional properties serving as inhibitory/dispersant of asphaltene in production processes, transportation, refining and storage of crude oil and derivatives. The corrosion inhibitor with inhibitory/dispersant of asphaltenes properties comprises an active substance base of 1,3-oxaninan-6-ones and hydrocarbon solvents such as benzene, toluene, mixed xylenes, o-xylene, m-xylene and p-xylene, diesel, kerosene, jet fuel, alcohols, aliphatic branched and unbranched alcohols containing from 3 to 10 carbon atoms, such as isopropanol, butanol and pentanol, and mixtures of hydrocarbon solvents with aliphatic branched or unbranched liquid fuels. In addition, a process for obtaining 1,3-oxazinan-6-ones derivatives of N-alkyl or N-alkenyl or N-cycloalkyl or N-aryl propionic acids and paraformaldehyde is described. 2. The synthesis process of claim 1 , wherein the molar ratio of amine alkyl or alkenyl or aromatic carboxylic acid with respect to alpha-beta unsaturated may vary is in the range of 1:5 to 5:1 claim 1 , preferably in the range of 1:1 to 2:1 in the absence of solvents.3. The synthesis process of claim 1 , wherein the reaction time varies in the range of 1 to 24 hours.4. The synthesis process of claim 1 , wherein the reaction temperature varies in the range of 80 to 200° C.5. The synthesis process of claim 1 , wherein the compound I is an alkyl or alkenyl amine or aromatic or cycloalkyl claim 1 , selected from the group consisting of hexylamine claim 1 , heptylamine claim 1 , octylamine claim 1 , nonylamine claim 1 , decylamine claim 1 , undecylamine claim 1 , dodecylamine claim 1 , tridecylamine claim 1 , tetradecylamine claim 1 , pentadecylamine claim 1 , hexadecylamine claim 1 , heptadecylamine claim 1 , octadecylamine claim 1 , oleylamine claim 1 , linoleylamine ...

Methods and Compositions for Treating a Subterranean Formation with a Polymeric Additive Composite

Methods and compositions for treating a subterranean formation are provided. The method can include introducing a treatment fluid into the subterranean formation containing an aqueous downhole fluid. The treatment fluid can contain one or more polymers, a particulate additive containing one or more additives, and one or more organic solvents. The polymer is at least partially dissolved in the organic solvent and the particulate additive is at least partially suspended in the organic solvent. The method can also include combining the treatment fluid with the aqueous downhole fluid to produce a polymeric additive composite and a fluid mixture within the subterranean formation. The polymeric additive composite contains the particulate additive at least partially embedded in the polymer to prevent an uncontrolled release of the particulate additive into the fluid mixture. 1. A method for treating a subterranean formation having an aqueous downhole fluid , comprising:introducing a treatment fluid into the subterranean formation, wherein the treatment fluid comprises a polymer, a particulate additive, and an organic solvent, wherein the polymer is at least partially dissolved in the organic solvent, and wherein the particulate additive is at least partially suspended in the organic solvent; andcombining the treatment fluid with the aqueous downhole fluid to produce a polymeric additive composite and a fluid mixture within the subterranean formation, wherein the polymeric additive composite comprises the particulate additive at least partially embedded in the polymer to prevent an uncontrolled release of the particulate additive into the fluid mixture.2. The method of claim 1 , wherein the treatment fluid comprises about 40 wt % to about 90 wt % of the polymer and about 10 wt % to about 60 wt % of the particulate additive claim 1 , based on a combined solids weight of the polymer and the particulate additive.3. The method of claim 2 , wherein the treatment fluid further ...

IN-SITU NEUTRALIZATION MEDIA FOR DOWNHOLE CORROSION PROTECTION

Inhibiting or preventing corrosion of metallic components downhole may be accomplished by introducing neutralization media into a wellbore in the proximity of downhole metallic components, where the neutralization media comprises magnesium and where the method further includes subsequently contacting the neutralization media with a potentially corrosive environment comprising at least 5 volume % water, where the water has a pH of less than 11. This contacting activates the neutralization media with the water thereby releasing magnesium ions, and the magnesium ions react with hydroxyl ions of the water to give magnesium hydroxide in an amount effective to raise the pH of the water present to be between about 8 and 12 thereby inhibiting or preventing corrosion of metallic components downhole. 1. A method for inhibiting or preventing corrosion of metallic components downhole , the method comprising:introducing neutralization media into a wellbore in proximity of downhole metallic components, the neutralization media comprising magnesium and where the neutralization media is selected from the group consisting of controlled electrolytic metallic (CEM) nanostructured material, media produced by additive manufacturing, and combinations thereof, where additive manufacturing is selected from the group consisting of 3D printing, rapid prototyping, direct digital manufacturing, layered manufacturing, stereolithography, multi-iet modeling, fused deposition modeling and selective layer sintering;{'sub': 2', '2, 'sensing a change in the corrosive fluid by a sensor, which sensor initiates contacting the neutralization media with the potentially corrosive fluid comprising water, where the water has a pH of less than about 11; where sensing a parameter change is selected from the group consisting of detecting the pH of the corrosive fluid falling, detecting a presence of HS, detecting a presence of CO, detecting a temperature increase above a pre-set threshold, detecting an oxygen ...

USING SYNTHETIC ACID COMPOSITIONS AS ALTERNATIVES TO CONVENTIONAL ACIDS IN THE OIL AND GAS INDUSTRY

A synthetic acid composition for use in oil industry activities, said composition comprising: urea and hydrogen chloride in a molar ratio of not less than 0.1:1; a metal iodide or iodate; an alcohol or derivative thereof. Optionally, formic acid or a derivative thereof; propylene glycol or a derivative thereof, ethylene glycol glycerol or a mixture thereof; cinnamaldehyde or a derivative thereof; and a phosphonic acid derivative can be added to the composition. 1. A synthetic acid composition for use in oil industry activities , said composition comprising:urea and hydrogen chloride in a molar ratio of not less than 0.1:1;a metal iodide or iodate;an alcohol or derivative thereof; andoptionally, a phosphonic acid derivative.2. The synthetic acid composition according to claim 1 , further comprising formic acid or derivative thereof.3. The synthetic acid composition according to claim 1 , further comprising propylene glycol or derivative thereof claim 1 , ethylene glycol claim 1 , glycerol or a mixture thereof.4. The synthetic acid composition according to claim 1 , further comprising cinnamaldehyde or a derivative thereof.5. The synthetic acid composition according to claim 1 , wherein the urea and hydrogen chloride are in a molar ratio of not less than 0.5:1.6. The synthetic acid composition according to claim 5 , wherein the urea and hydrogen chloride are in a molar ratio of not less than 1.0:1.7. The synthetic acid composition according to claim 1 , wherein the phosphonic acid derivative is aminoalkylphosphonic salt.8. The synthetic acid composition according to claim 7 , wherein the aminoalkylphosphonic salt is amino tris methylene phosphonic acid.9. The synthetic acid composition according to claim 1 , wherein the metal iodide or iodate is cuprous iodide.10. The synthetic acid composition according to claim 1 , wherein the metal iodide or iodate is potassium iodide.11. The synthetic acid composition according to claim 1 , wherein the metal iodide or iodate is ...

Method of Using Dithiazines and Derivatives Thereof in the Treatment of Wells

Corrosion of metallic tubulars in an oil, gas or geothermal well may be inhibited by introducing into the well a dithiazine derivative of the formula: 2. The dithiazine of claim 1 , wherein Ris a C-Cstraight chain or branched alkyl group.3. The dithiazine of claim 1 , wherein X is —Cl.4. The dithiazine of claim 1 , wherein the dithiazine is of formula (IV).5. The dithiazine of claim 1 , wherein the dithiazine is of formula (V).6. The dithiazine of claim 5 , wherein Ris benzyl or naphthylmethyl.7. The dithiazine of claim 6 , wherein Ris methyl.8. The dithiazine of claim 7 , wherein Ris benzyl.9. The dithiazine of claim 1 , wherein Ris methyl.10. The dithiazine of claim 4 , wherein Ris phenyl.12. The method of claim 11 , wherein the at least one component is an alkyl or alkenyl substituted quaternary pyridine selected from the group consisting of N-butyl-4-methylpyridinium chloride claim 11 , dodecylpyridinium chloride and tetradecylpyridinium chloride claim 11 , N-methylpyridinium chloride claim 11 , N-methylpyridinium bromide claim 11 , N-ethylpyridinium chloride claim 11 , N-ethylpyridinium bromide claim 11 , 2-vinylpyridinium chloride claim 11 , 2-vinylpyridinium bromide claim 11 , 3-vinylpyridinium chloride claim 11 , 3-vinylpyridinium bromide claim 11 , 4-vinylpyridinium chloride and 4-vinylpyridinium bromide and mixtures thereof.13. The method of claim 11 , wherein the corrosion inhibiting formulation further comprises a hydrophilic solvent with the at least one component.14. The method of claim 13 , wherein the hydrophilic solvent is water or an organic solvent.15. The method of claim 11 , wherein the weight ratio of spent fluid to the corrosion inhibiting formulation is between from about 25:75 to about 75:25.16. The method of claim 15 , wherein the weight ratio of spent fluid to the corrosion inhibiting formulation is approximately 50:50.17. The method of claim 11 , wherein the mixture is introduced into the well during stimulation.18. The method of claim 11 ...

N-Alkyl-N'-Poly(Oxyalkyl)Hexahydropyrimidine-Quaternary Ammonium Salts And The Use Thereof As Corrosion Inhibitors

This invention relates to N-alkyl-N′-poly(oxyalkyl)hexapyrimidine-quaternary ammonium salts of the formulae (Ia)-(Ic) and mixtures thereof in which R 1 is C 8 -C 30 -alkyl or C 8 -C 30 -alkenyl, R 2 is hydrogen, C 1 -C 3 -alkyl, —COOH or a group selected from the formulae wherein the bonding occurs via the valence containing the B residue, B is a single bond or a C 1 to C 3 alkylene group R 3 is C 1 -C 4 -alkyl, vinyl or allyl, X − is methylsulfate or iodide, A is a 1,2-alkylene group having from 2 to 10 carbon atoms, and p is a number from 1 to 50.

Novel Acid Corrosion Inhibitor

Acids, such as hydrochloric acid, are pumped down in to the formation in acidizing treatments of oil & gas wells, thru metal pipes/tubing. Corrosion Inhibition of these metal surfaces (pipes, tubing, etc) has been extensively studied. Most known acid corrosion inhibitors (ACI) and acid corrosion inhibitors currently used in the oilfield contain ingredients that are an environmental concern or have poor Health, Safety and Environmental (HSE) characteristics. This invention relates to the discovery of a Novel Acid Corrosion Inhibitor. Aromatic Nitriles, especially Cinnamyl Nitrile, when added to the acid in effective amounts, offers acceptable rates of corrosion inhibition. 1. A Novel Acid Corrosion Inhibitor consisting of an Aromatic Nitrile compound , used independently or in conjunction with other acid corrosion inhibitors , offers excellent corrosion inhibition rates of metal surfaces that come in contact with mineral acids.2. Aromatic Nitrile compound of is Cinnamyl Nitrile3. By using Cinnamyl Nitrile claim 1 , it is possible to formulate a corrosion inhibitor which has acceptable inhibition rates without the use of conventional ingredients that have poor Health claim 1 , Safety and Environmental (HSE) characteristics. Corrosion Inhibitors currently in use contain ingredients like Methanol claim 1 , Acetylenic Compounds claim 1 , Propargyl Alcohol claim 1 , EthylOctynol claim 1 , NonylPhenol claim 1 , Formaldehyde claim 1 , Benzyl Chloride claim 1 , Antimony claim 1 , etc which are either toxic claim 1 , flammable claim 1 , corrosive claim 1 , marine pollutants claim 1 , have large half lives in the environment and/or are not biodegradable. This Invention relates to the acid stimulation of oil & gas wells, and in particular to acidizing treatments and methods of using such acid fluids in treating formations having low permeability.Using aqueous acid solutions to acidize oil & gas wells is well known. Typically, an aqueous acid solution is pumped through the well ...

DUAL FUNCTIONING CORROSION INHIBITOR AND FOAMING AGENT

A method may include: placing into a wellbore penetrating a subterranean formation a foaming agent, wherein the wellbore comprises a produced fluid from the subterranean formation; and foaming the produced fluid. 1. A method comprising:placing into a wellbore penetrating a subterranean formation a foaming agent, wherein the wellbore comprises a produced fluid from the subterranean formation; andfoaming the produced fluid.3. The method of wherein R1 is the alkyl group and wherein R1 comprises 8 carbon atoms to 12 carbon atoms.5. The method of wherein R1 is the alkyl group and wherein R1 comprises 8 carbon atoms to 12 carbon atoms.7. The method of wherein R1 is the alkyl group and wherein R1 comprises 8 carbon atoms to 12 carbon atoms.9. The method of wherein foaming agent is present in a treatment fluid claim 1 , the treatment fluid comprising the foaming agent and a carrier fluid.10. The method of wherein the carrier fluid is selected from the group consisting of water claim 9 , a liquid hydrocarbon claim 9 , an alcohol claim 9 , and combinations thereof.11. The method of further comprising placing a foaming gas in the wellbore.12. The method of wherein the foaming agent is placed in the wellbore through a production line disposed within the wellbore.14. The method of wherein foaming agent is introduced into the wellbore via an annulus drip claim 13 , a slip stream claim 13 , a capillary string claim 13 , production line claim 13 , or a combination thereof.15. The method of wherein the foaming agent has a corrosion inhibition property and slows corrosion on at least one surface of equipment disposed within the wellbore.16. The method of wherein the foaming agent is introduced into the wellbore during an artificial lift operation.17. The method of wherein the foaming agent is protonated by an acid before or during the step of introducing to form a protonated foaming agent.19. The method of wherein foaming agent is introduced into the wellbore via a production line.20 ...

Organic blend additive useful for inhibiting localized corrosion of equipment used in oil and gas production

An organic blend chemical additive comprising more than 50 wt. % organic solvent (e.g. methanol and/or ethylene glycol), less than 10 wt. % water, a nitrate salt, a maleic acid copolymer, and optionally an imidazoline may be delivered to a production well through a conduit having a stainless steel and corrosion resistant metal alloy surface, such as a capillary string or an umbilical tubing, the organic blend chemical additive being shown to be useful in inhibiting localized corrosion of and improving the repassivation of the equipment or conduit.

ORGANIC BLEND ADDITIVE USEFUL FOR INHIBITING LOCALIZED CORROSION OF EQUIPMENT USED IN OIL AND GAS PRODUCTION

An organic blend chemical additive comprising more than 50 wt. % organic solvent (e.g. methanol and/or ethylene glycol), less than 10 wt. % water, a nitrate salt, a maleic acid copolymer, and optionally an imidazoline may be delivered to a production well through a conduit having a stainless steel and corrosion resistant metal alloy surface, such as a capillary string or an umbilical tubing, the organic blend chemical additive being shown to be useful in inhibiting localized corrosion of and improving the repassivation of the equipment or conduit. 1. An organic chemical blend additive corrosion inhibitor comprising:a nitrate;a maleic acid copolymer;an organic solvent in an amount greater than 50 wt. %, based on a total amount of the organic chemical blend additive; andless than 10 wt. % water, based on a total amount of the organic chemical blend additive.2. The organic chemical blend additive corrosion inhibitor of where the nitrate is in solution form and present in the organic chemical blend additive in an amount less than 2 wt. % claim 1 , based on the total amount of the organic chemical blend additive.3. The organic chemical blend additive corrosion inhibitor of where the nitrate is selected from a group consisting of calcium nitrate claim 1 , sodium nitrate claim 1 , potassium nitrate claim 1 , and a combination thereof.4. The organic chemical blend additive corrosion inhibitor of where amount of nitrate present in the blend ranges from about 0.25% of a 45% aqueous solution of nitrate salt to about 5% of a 45% aqueous solution of the nitrate salt.5. The organic chemical blend additive corrosion inhibitor of where the maleic acid copolymer is a polycarboxylic acid having the following chemical description: propenoic acid claim 1 , ethyl ester claim 1 , polymer with ethenyl acetate and 2 claim 1 ,5 furandione claim 1 , hydrolyzed.6. The organic chemical blend additive corrosion inhibitor of where the amount of maleic acid copolymer in the organic chemical blend ...

Multifunctional surfactant and corrosion inhibitor additives

Multifunctional surfactants useful in, for example, in the oil and gas industry, are provided. In some embodiments, the multifunctional surfactants include at least one amide group and at least one thiol group in the same molecule. In some embodiments, the methods include contacting a metal surface with at least one multifunctional additive that includes at least one amide group and at least one thiol group in the same molecule; and allowing the multifunctional additive to interact with at least a portion of the metal surface.

METALLIC NANOPARTICLE BIOCIDE IN INDUSTRIAL APPLICATIONS

A method includes providing a measured dose amount of manufactured metallic nanoparticle material and adding the measured dose amount of the manufactured metallic nanoparticle material to a carrier material for pre-treatment of the carrier material prior to use of the carrier material and the manufactured metallic nanoparticle material in the sub-surface earth activity. Another method includes accessing a sub-surface earth opening that is used in conjunction with the sub-surface earth activity, introducing an amount of manufactured metallic nanoparticle material into the sub-surface earth opening, and treating a sub-surface earth condition present at a sub-surface earth location accessible via the sub-surface earth opening. The sub-surface earth condition is treated with the manufactured metallic nanoparticle material. Another method includes accessing a product from a sub-surface earth location that is extracted in conjunction with the sub-surface earth activity, measuring a dose amount of manufactured metallic nanoparticle material, introducing the measured dose amount of the manufactured metallic nanoparticle material with the product from the sub-surface earth location. 1. A method for treatment using a metallic nanoparticle material , the method comprising:accessing a material that is subject to contamination conditions by a contaminant from a sub-surface earth activity;measuring a dose amount of manufactured metallic nanoparticle material; andintroducing the measured dose amount of the manufactured metallic nanoparticle material with the material that is subject to the contamination conditions.2. The method of claim 1 , wherein the manufactured metallic nanoparticle material comprises silver nanoparticles claim 1 , wherein substantially all of the silver nanoparticles have a diameter between about 2 nanometers and about 100 nanometers.3515. The method of claim 1 , wherein manufactured metallic nanoparticle material comprises silver nanoparticles which have an ...

SULFIDE-BASED COMPOUNDS AND USES THEREOF

Disclosed are sulfide-based compounds which are a product of a Michael addition reaction between a sulfur-containing donor group and an unsaturated hydrocarbon moiety. The sulfide-based compounds may be used in compositions and methods for inhibiting corrosion. 1. A composition comprising at least one sulfide-based compound , the at least one sulfide-based compound formed by a Michael addition reaction between a sulfa-Michael donor and an olefin as a Michael acceptor.2. The composition of of claim 1 , wherein the sulfa-Michael donor comprises a mercaptoalcohol.3. The composition of claim 1 , wherein the olefin comprises α claim 1 ,β-unsaturated carbonyl compounds.4. The composition of claim 3 , wherein the α claim 3 ,βunsaturated carbonyl compounds comprises a vinyl ketone claim 3 , a vinyl sulfone claim 3 , a quinone claim 3 , an enamine claim 3 , a ketimine claim 3 , an aldimine claim 3 , an oxazolidine claim 3 , and an acrylate claim 3 , acrylate esters claim 3 , acrylonitrile claim 3 , acrylamides claim 3 , maleimides claim 3 , alkyl methacrylates claim 3 , cyanoacrylates claim 3 , vinyl ketones claim 3 , α claim 3 ,β-unsaturated aldehydes claim 3 , vinyl phosphonates claim 3 , acrylonitrile claim 3 , vinyl pyridines claim 3 , azo compounds claim 3 , β-keto acetylenes claim 3 , acetylene esters claim 3 , nitro ethylenes.6. The composition of claim 1 , further comprising a solvent claim 1 , wherein the solvent is present in the composition at about 10 wt % to 99 wt % of the composition.7. A fluid source comprising one or more corrodents and at least one sulfide-based compound as in .8. The composition of claim 7 , wherein the fluid source comprises about 0.1% to about 25% weight/weight total dissolved solids.9. The composition of claim 1 , wherein the sulfide-based compound is about is about 0.1 ppm to 10 claim 1 ,000 ppm by weight or volume of the composition.12. A method of inhibiting corrosion of metal containments in contact with a fluid source comprising the ...

Synergized Acetals Composition And Method For Scavenging Sulfides And Mercaptans

This invention provides a composition comprising I. at least one reaction product between a nitrogen-free monohydric alcohol and an aldehyde or ketone, and II. at least one reaction product between a nitrogen-free polyhydric alcohol and an aldehyde or ketone, and optionally III. at least one reaction product from III.a) formaldehyde, and III.b) an amine, selected from the group consisting of primary alkyl amines having 1 to 4 carbon atoms, and primary hydroxy alkyl amines having 2 to 4 carbon atoms, and optionally IV. at least one solid suppression agent selected from the group consisting of IV(a). alkali or alkaline earth metal hydroxides IV(b). mono-, di- or tri-hydroxy alkyl, aryl or alkylaryl amines, IV(c). mono-, di- or tri-alkyl, aryl or alkylaryl primary, secondary and tertiary amines or IV(d). multifunctional amines and IV(e). mixtures of compounds of groups IV(a) to IV(c). wherein alkyl is C 1 to C 15 , aryl is C 6 to C 15 and alkylaryl is C 7 to C 15 .

Enhancing treatment fluid placement in a subterranean formation

Energy created by a propellant can form a fracture in a subterranean formation. For example, a treatment fluid can be introduced into a subterranean formation. A propellant can be positioned in the subterranean formation. The propellant can be detonated to generate a fracture in the subterranean formation for receiving at least part of the treatment fluid. The treatment fluid may include an acid, a hydrolysable in-situ acid generator, a chelating agent, a hydrolysable in-situ chelating agent generator, or mixtures thereof.

TREATMENT FLUID CONTAINING A CORROSION INHIBITOR POLYMER OF A CARBOHYDRATE AND QUATERNARY AMINE

A treatment fluid comprises: water; a carboxylate; and a corrosion inhibitor, wherein the corrosion inhibitor is environmentally-friendly, biodegradable, and is a polymer, wherein the polymer comprises a carbohydrate backbone and a quaternary amine functional group; wherein a test fluid consisting essentially of the water, the carboxylate, and the corrosion inhibitor, and in the same proportions as in the treatment fluid, is capable of providing a corrosion weight loss to a metal plate of less than 0.05 pounds per square feet (lb/ft) under testing conditions of 200° F. (93.3° C.), a pressure of 500 psi (3.4 MPa), and a time of 24 hours whereas a substantially identical test fluid without the corrosion inhibitor provides a corrosion weight loss of greater than 0.05 lb/ftunder the testing conditions. A method of treating a portion of a well comprises: forming the treatment fluid; and introducing the treatment fluid into the well. 1. A method of treating a portion of a well comprising: (A) water;', '(B) a carboxylate, wherein the carboxylate is part of a delayed acid breaker system; and', '(C) a corrosion inhibitor, wherein the corrosion inhibitor is environmentally-friendly, biodegradable, and is a polymer, wherein the polymer comprises a carbohydrate backbone and a quaternary amine functional group, and wherein the polymer has a molecular weight such that the polymer is biodegradable;', {'sup': 2', '2, 'wherein a test fluid consisting essentially of the water, the carboxylate, and the corrosion inhibitor, and in the same proportions as in the treatment fluid, is capable of providing a corrosion weight loss to a metal plate of less than 0.05 pounds per square feet (lb/ft) under testing conditions of 200° F. (93.3° C.), a pressure of 500 psi (3.4 MPa), and a time of 24 hours whereas a substantially identical test fluid without the corrosion inhibitor provides a corrosion weight loss of greater than 0.05 lb/ftunder the testing conditions; and'}], 'forming a treatment ...

Controlled-Release Chemical Particulate Composition for Well Treatment

The present disclosure relates to a composition comprising an active chemical agent adsorbed into a non-water-soluble carrier composed, at least in part, of com grit. The present composition is useful for inhibiting scale or other undesirable formations. The composition may be introduced into the target during the stimulation or production treatment of an oil or gas well. The composition may be formed by adsorbing a liquid chemical agent onto a solid substrate of com-based material called com grit. The crush resistance and liquid-insolubility of com grit help enable the composition to release the treatment chemical into the well over time. The liquid chemical combined with the solid substrate can be used as a well treatment agent for scale inhibitors, corrosion inhibitors, surfactants, non-emulsifiers, halite inhibitors, wettability modifiers, paraffin and asphaltene inhibitors, and water and oil-soluble tracers. 1. An oil or gas well-treating composition comprising:a first non-water-soluble carrier comprising corn grit, anda first active chemical agent adsorbed by the first non-water-soluble carrier;wherein the first non-water-soluble carrier provides a controlled release of the first active chemical agent.2. The composition of claim 1 , wherein the controlled release provides about 12 months of continuous treatment.3. The composition of claim 1 , wherein the first non-water-soluble carrier is a natural milled or ground particulate from woody rings of corn cobs.4. The composition of claim 1 , wherein the first active chemical agent is designed to inhibit at least one of scaie claim 1 , corrosion claim 1 , emulsions claim 1 , salt formation claim 1 , clay swelling claim 1 , fine migration claim 1 , paraffin claim 1 , asphaltenes claim 1 , biological growth claim 1 , gels claim 1 , or cross-linking.5. The composition of claim 1 , further comprising a second active chemical agent adsorbed by the first non-water-soluble carrier.6. The composition of claim 5 , wherein ...

CORROSION INHIBITOR FORMULATIONS

The instant invention relates to a corrosion inhibitor composition that contains: (a) at least one biodegradable polyhydroxyacid and/or polyhydroxylated derivative thereof, preferably a polyhydroxyacid that may be in all or part in the form a polyhydroxylated salt and/or a polyhydroxyamide; and (b) a biodegradable cationic compound having a molecular weight of less than 500 Da, preferably between 50 and 400 Da 1. A corrosion inhibitor composition comprising:(a) at least one biodegradable polyhydroxyacid and/or polyhydroxylated derivative thereof; and(b) a biodegradable cationic compound having a molecular weight of less than 500 Da.2. The composition of claim 1 , wherein the biodegradable polyhydroxyacid and/or polyhydroxylated derivative thereof (a) is selected from the group consisting of:biodegradable polyhydroxy acids;metal salts of such biodegradable polyhydroxy acids;alkanolamine salts of such biodegradable polyhydroxy acids;polyhydroxy amides obtainable by reaction of alkanolamines with such biodegradable polyhydroxy acids; andmixtures thereof.3. The composition of claim 2 , wherein the biodegradable polyhydroxyacid and/or polyhydroxylated derivative thereof (a) is gluconic acid.4. The composition of claim 1 , wherein the biodegradable cationic compound (b) is:a choline salt (choline being trimethyl (2-hydroxyethyl) ammonium hydroxide);{'sub': 1', '3', '1', '3, 'a (C-Calkyl)trimethylammonium or di(C-Calkyl) dimethylammonium salt;'}{'sub': 1', '3, 'a dihydroxy tri(C-Calkyl) ammonium halide or dihydroxy tri(C1-C3 hydroxyalkyl) ammonium halide;'}{'sub': 1', '3, 'a cationic compound as obtained by the hydrolysis of chlorohydroxalkyl tri(C-Calkyl or hydroxalkyl) ammonium salts; or'}a mixture of two or more of said salts.5. The composition of claim 4 , wherein the biodegradable cationic compound (b) is a choline salt.6. The composition of claim 1 , further comprising:(c) an antioxidant.7. The composition of claim 1 , further comprising:(d) a pH buffer.8. The ...

TAGGED CORROSION INHIBITORS FOR USE IN SUBTERRANEAN OPERATIONS

Compositions, treatment fluids, and methods for providing corrosion inhibition in subterranean operations, pipelines, and other related operations are provided. In one embodiment, the methods comprise providing a tagged corrosion-inhibiting additive that comprises an imidazoline-based compound bonded with a detectable moiety; and introducing the tagged corrosion-inhibiting additive into at least a portion of a subterranean formation or pipeline. 1. A method comprising:providing a tagged corrosion-inhibiting additive that comprises an imidazoline-based compound bonded with a detectable moiety; andintroducing the tagged corrosion-inhibiting additive into at least a portion of a subterranean formation.2. The method of further comprising analyzing a sample of fluid from at least a portion of the subterranean formation to determine a concentration of the tagged corrosion-inhibiting additive in the fluid.3. The method of wherein an inductively coupled plasma optical emission spectrometry technique is used to analyze the fluid sample.4. The method of wherein:the concentration of the tagged corrosion-inhibiting additive in the fluid sample is less than a predetermined effective amount; andthe method further comprises introducing an additional corrosion-inhibiting additive into at least a portion of the subterranean formation.5. The method of wherein the additional corrosion-inhibiting additive comprises an additional tagged corrosion-inhibiting additive.6. The method of wherein a well bore penetrates the portion of the subterranean formation claim 1 , and at least a portion of tubing resides in the well bore.7. The method of wherein introducing the tagged corrosion-inhibiting additive into at least a portion of the subterranean formation comprises injecting the tagged corrosion-inhibiting additive into a capillary injection tube disposed in a well bore that penetrates at least a portion of the subterranean formation.8. The method of wherein introducing the tagged corrosion- ...

IDENTIFICATION AND CHARACTERIZATION OF NOVEL CORROSION INHIBITOR MOLECULES

Methods of employing corrosion inhibitors with oxidizing and/or non-oxidizing biocides, such as peroxycarboxylic acids, to provide corrosion protected compositions are disclosed. Various corrosion inhibitors further provide biocidal efficacy in addition to the corrosion protection providing further benefits for application of use. Methods of employing corrosion protected biocide compositions, such as peroxycarboxylic acid compositions, for corrosion protection are particularly well suited for treating fluids intended to flow through pipes, namely in the energy industry, water and paper industries, etc. Methods providing suitable corrosion protection in comparison to untreated systems and corrosion protected systems using conventional corrosion inhibitors, such as quaternary amines and imidazolines commonly used in the industry, are disclosed. 1. A method for inhibiting corrosion from a target treated with a biocide comprising:{'sub': 1', '22', '1', '22, 'contacting a target with a biocide comprising a C-Cperoxycarboxylic acid composition or a C-Cperoxycarboxylic acid forming composition or a non-oxidizing biocide;'}contacting the target with a corrosion inhibitor that is an alkyl pyridinium salt, cetyl pyridinium salt, polyesteramide, dimethicone, imidazole derivative, sulphonamide or combination thereof; andinhibiting corrosion, wherein the treated target has reduced corrosion in comparison to a target that is not treated with the corrosion inhibitor composition.2. The method of claim 1 , wherein the water source comprises from about 0.5 ppm to about 50 claim 1 ,000 ppm of said peroxycarboxylic acid composition or the non-oxidizing biocide claim 1 , and from about 1 ppm to about 1 claim 1 ,000 ppm of said corrosion inhibitor.3. The method of claim 1 , wherein the contacting of the biocide and the corrosion inhibitor is provided in separate contacting steps providing the biocide and the corrosion inhibitor to the target in need of treatment from at least two ...

A New Anti-Foaming Composition

The present invention relates to an anti-foaming composition comprising an alkoxylated stand oil and/or an alkoxylated blown native oil and use thereof as an anti-foaming agent. 1. A drilling fluid or completion fluid comprising(a) an alkoxylated stand oil and/or an alkoxylated blown native oil;(b) an organic and/or inorganic salt; and(c) optionally a surfactant.2. The drilling fluid or completion fluid according to claim 1 , wherein the native oil is selected from the group consisting of babussa oil claim 1 , cottonseed oil claim 1 , borage oil claim 1 , safflower oil claim 1 , peanut oil claim 1 , blackcurrant seed oil claim 1 , hazelnut oil claim 1 , herring oil claim 1 , tung oil claim 1 , jojoba oil claim 1 , coconut oil claim 1 , neat's foot oil claim 1 , bone oil claim 1 , lard liver oil claim 1 , linseed oil claim 1 , corn oil claim 1 , almond oil claim 1 , olive oil claim 1 , palm oil claim 1 , palm kernel oil claim 1 , rapeseed oil claim 1 , beef tallow claim 1 , castor oil claim 1 , sardine oil claim 1 , mustard oil claim 1 , soybean oil claim 1 , sunflower oil claim 1 , shea butter oil claim 1 , tall oil claim 1 , grapeseed oil claim 1 , whale oil claim 1 , walnut oil claim 1 , thistle oil claim 1 , wood oil claim 1 , a partially hydrogenated version of any of the aforementioned oils claim 1 , a refined version of any of the aforementioned oils claim 1 , a transesterification product of any of the aforementioned oils and mixtures thereof.3. The drilling fluid or completion fluid according to claim 1 , wherein the stand oil is a native oil polymerized under the exclusion of air.4. The drilling fluid or completion fluid according to claim 3 , wherein the stand oil has a kinematic viscosity at 40° C. of between 100 and 10 000 mm/s when determined in accordance with DIN 51562.5. The drilling fluid or completion fluid according to claim 1 , wherein the alkoxylated stand oil and/or an alkoxylated blown native oil is producible by reacting at least one alkylene ...

NITROGEN-CONTAINING ANTI-AGGLOMERANTS FOR PRESERVING THE FLUIDITY OF FLUIDS CONTAINING GAS HYDRATES

The present invention relates to the use of a specific group of acylated nitrogen-containing compounds as anti-agglomerants for gas hydrates. The anti-agglomerants are surface active nitrogen-containing compounds with 1-7 nitrogen atoms, which compounds have at least two hydrophobic groups with 6-24 carbon atoms, and where the hydrophobic groups are connected to the remainder of the molecule by an amine moiety or an amide moiety, and which compounds have at least one C2-C5 acyl group; or a salt thereof. The invention also relates to a method for inhibiting the agglomeration of gas hydrates in a conduit, and compositions comprising the gas hydrate anti-agglomerant, a corrosion inhibitor and/or a paraffin deposition inhibitor. 2. The method according to wherein the anti-agglomerant has formula I claim 1 , wherein a=2 claim 1 , m=2 and R═H; wherein G is a group E claim 1 , and wherein two of the groups E are acyl groups having 6-24 carbon atoms and two are acyl groups having 4 carbon atoms.3. The method according to wherein the anti-agglomerant has formula I claim 1 , wherein a=3 claim 1 , m=2 and R═H; wherein G is a group E claim 1 , and wherein two of the groups E are acyl groups having 6-24 carbon atoms claim 1 , two are acyl groups having 2 carbon atoms and one is an acyl group having 4 carbon atoms.4. The method according to wherein the anti-agglomerant has formula I claim 1 , wherein a=1 claim 1 , m=3 and one R is a hydrocarbyl group having 8-24 carbon atoms; wherein G is a group E claim 1 , and wherein one of the groups E is an acyl group having 6-24 carbon atoms claim 1 , one of the groups E is an acyl group having 4 carbon atoms and one of the groups E is an acyl group having 2 carbon atoms.5. The method according to wherein the anti-agglomerant has formula I claim 1 , wherein a=1 claim 1 , m=3 and one R is a hydrocarbyl group having 8-24 carbon atoms; wherein G is a group E claim 1 , and wherein one of the groups E is an acyl group having 6-24 carbon atoms ...

DETERMINING RESIDUAL FRICTION REDUCER CONCENTRATIONS FOR SUBTERRANEAN TREATMENT FLUIDS

The present disclosure relates to systems and methods for treating subterranean formations. An embodiment of the present disclosure is a method comprising: introducing a fluid comprising an aqueous base fluid and a friction reducer into a wellbore penetrating at least a portion of a subterranean formation at a pressure sufficient to create or enhance one or more fractures within the subterranean formation; recovering at least a portion of the fluid from the wellbore; adding a reactive agent to a sample of the portion of the fluid that has been recovered from the wellbore, wherein the reactive agent reacts with the friction reducer to form a photo-detectable compound in the sample; measuring a light absorbance of the sample of the fluid that has been recovered from the wellbore at a selected wavelength of light; and using the measured absorbance and a calibration curve for the selected wavelength of light to determine the concentration of the friction reducer in the fluid that has been recovered from the wellbore. 1. A method comprising:introducing a fluid comprising an aqueous base fluid and a friction reducer into a wellbore penetrating at least a portion of a subterranean formation at a pressure sufficient to create or enhance one or more fractures within the subterranean formation;recovering at least a portion of the fluid from the wellbore;adding a reactive agent to a sample of the portion of the fluid that has been recovered from the wellbore, wherein the reactive agent reacts with the friction reducer to form a photo-detectable compound in the sample;measuring a light absorbance of the sample of the fluid that has been recovered from the wellbore at a selected wavelength of light; andusing the measured absorbance and a calibration curve for the selected wavelength of light to determine the concentration of the friction reducer in the fluid that has been recovered from the wellbore.2. The method of further comprising the step of preparing the calibration curve ...

SYNERGISTIC SULFIDE SCAVENGING ADDITIVES FOR USE IN OILFIELD OPERATIONS

Systems, compositions, and methods for synergistic additives for use in the scavenging of sulfur-containing compounds encountered in oilfield operations are provided. In one embodiment, the methods comprise injecting a sulfide scavenging additive that does not comprise a significant amount of an aldehyde into at least a portion of a subterranean formation where one or more sulfur-containing species are present; and injecting a synergistic additive comprising at least one base into at least the portion of the subterranean formation. 1. A method comprising:injecting a sulfide scavenging additive that is substantially free of aldehyde, the additive comprising at least one compound selected from the group consisting of an acrylate-based compound, an acrylonitrile-based compound, and any combination thereof into at least a portion of a subterranean formation where one or more sulfur-containing species are present; andinjecting a synergistic additive comprising at least one weak base into at least the portion of the subterranean formation;wherein at least one of the sulfide scavenging additive or the synergistic additive is injected as a liquid or a mist.2. The method of wherein the synergistic additive catalyzes a reaction of the sulfide scavenging additive and the sulfur-containing species.3. The method of wherein the sulfide scavenging additive reacts with the sulfur-containing species to form products that are at least one of nonhazardous and noncorrosive.4. The method of wherein the synergistic additive reacts with the sulfur-containing species.5. The method of wherein the reaction of the synergistic additive and the sulfur-containing species forms products that are at least one of nonhazardous and noncorrosive.6. The method of wherein the synergistic additive increases a pH level of at least the portion of the subterranean formation.7. The method of wherein the at least one weak base comprises at least one amine.8. The method of wherein the sulfide scavenging ...

ANTI-CORROSION FORMULATIONS WITH STORAGE STABILITY

The present invention concerns the use of at least one compound A comprising at least one —SH or —S—, M+group, at least one —C-G-C— chain, in which G represents an atom from column 16 of the periodic table, not comprising a carboxy group —C(═O)—OH or —C(═O)—O—, and of a molar mass of between 90 g·mol-1 and 1000 g·mol-1, as an additive in a formulation inhibiting corrosion in metals used in the oil industry, and more generally in any kind of industry involving the drilling of ores or fossil compounds, such as gas or oil, in order to improve both the anti-corrosion performance and the storage stability of same. The invention also concerns said corrosion-inhibiting formulations comprising at least one compound A. 1. A corrosion-inhibiting formulation comprising:a) at least one amine or amine derivative, [{'sup': −', 'p+', 'p+, 'i. the compound A contains at least one —SH or —SM group, where M represents a cation of an alkali metal (Group 1) or of an alkaline earth metal (Group 2), or of a metal of Groups 7, 8, 9, 10, 11 or 12 of the Periodic Table of the Elements, p representing the valency of the metal and being 1, 2 or 3,'}, 'ii. the compound A comprises at least one —C-G-C— sequence, where G represents an atom of Group 16 of the Periodic Table of the Elements,', {'sup': '−', 'iii. the compound A does not contain a —C(═O)—OH or —C(═O)—O group, and'}, {'sup': −1', '−1, 'iv. the molar mass of the compound A is between 90 g·moland 1000 g·ml, limits included, and'}], 'b) at least one compound A exhibiting at least the following characteristicsc) optionally a solvent or a mixture of two or more solvents.2. The formulation as claimed in claim 1 , wherein:a) represents from 40% to 99.5% by weight, limits included, with respect to the total weight of the components a)+b)+c),b) represents from 0.5% to 30% by weight, limits included, with respect to the total weight of the components a)+b)+c),c) represents from 0% to 59.5% by weight, limits included, with respect to the total ...

CORROSION INHIBITORS FOR DRILLING FLUID BRINES

Improved corrosion inhibitors for well brines include a phosphonate or salts thereof, and a gluconic acid or salts thereof. The inhibitors are normally injected downhole into the brines. The most preferred phosphonates are amine polyphosphonates, used in combination with alkali metal salts of gluconic acid. 1. A method of inhibiting corrosion of metal surfaces in petroleum well equipment when using brines during petroleum recovery , comprising the steps of:injecting a brine selected from the group consisting of calcium chloride and calcium nitrate, and mixtures thereof, into said well for contact with said metal surfaces;mixing a corrosion inhibitor with said brine, said inhibitor comprising respective amounts of a phosphonate or salts thereof, and gluconic acid or salts thereof.3. The method of claim 1 , said inhibitor comprising from about 30-70% by weight of said phosphonate or salts thereof claim 1 , and from about 70-30% by weight of said gluconic acid or salts thereof.4. The method of claim 1 , said inhibitor being present at a level of from about 10-10 claim 1 ,000 ppm in said brine.5. The method of claim 1 , said inhibitor being mixed with said brine prior to said injection of said brine into said well.6. The method of claim 1 , including the step of individually introducing said phosphonate or salts thereof claim 1 , and said gluconic acid or salts thereof into said well.7. The method of claim 1 , said inhibitor being in the form of an aqueous dispersion and having a pH of from about 8-13.8. A corrosion inhibitor for brines selected from the group consisting of calcium chloride or calcium nitrate brines claim 1 , or mixtures thereof claim 1 , said inhibitor consisting essentially of a phosphonate or salts thereof claim 1 , and gluconic acid or salts thereof.10. The inhibitor of claim 8 , said inhibitor comprising from about 30-70% by weight of said phosphonate or salts thereof claim 8 , and from about 70-30% by weight of said gluconic acid or salts thereof. ...

Dual-Phase Acid-Based Fracturing Composition with Corrosion Inhibitors and Method of Use Thereof

A dual-phase acid-based fracturing composition with corrosion inhibitors and method for use in acid-based matrix and fracturing operations in oil and gas wells is provided. The composition includes an acid, a hydrocarbon, a hydrocarbon-soluble corrosion inhibitor, an acid-soluble corrosion inhibitor, and an acid-soluble inhibitor aid. 1. A method for inhibiting acid corrosion in matrix acidizing and acid fracturing applications in oil and gas wells , the method comprising the steps of: a strong acid operable to be diluted with treatment water and to dissolve formation rock;', 'a liquid hydrocarbon comprising 5 or more carbon atoms;', 'an emulsifier selected from the group consisting of an amine-based surfactant, linear alkyl amines and alkyl ammoniums;', 'a hydrocarbon-soluble corrosion inhibitor present in a hydrocarbon phase of the composition, the hydrocarbon-soluble corrosion inhibitor comprising an alcohol; and', 'an acid-soluble corrosion inhibitor present in an acid phase of the composition; and, 'preparing a dual-phase acid-based fracturing composition comprisinginjecting the composition into an oil and gas well to cause fracturing, etching, or a combination thereof in the formation rock;wherein the corrosion inhibitor present in the hydrocarbon phase of the dual-phase fracturing composition will be spent during the injection of stimulation fluids and the corrosion inhibitor present in the acid phase will be spent during the flowback.2. The method of claim 1 , wherein the emulsifier is present in concentrations in a range of from 0.05% to 1.5% by volume relative to the amount of liquid hydrocarbon.3. The method of claim 1 , wherein the hydrocarbon-soluble corrosion inhibitor present in a range of 0.01% to 3% by volume relative to the amount of the liquid hydrocarbon in the composition.4. The method of claim 1 , wherein the acid-soluble corrosion inhibitor is present in an amount of up to 3% by volume relative to the amount of acid in the composition.5. The ...

Corrosion Inhibition of HCL Treatment Fluids with Environmentally Compatible Solvent

A method of treating in a subterranean formation including placing a corrosion inhibitor composition into a subterranean formation, where the formation includes an acidic environment having a pH of about 5 or below, where the composition includes: an organic solvent comprising an alcohol with a flash point of at least about 75° C.; a nitrogen containing compound; an aqueous acid solution comprising HCl; and contacting a metal surface with the corrosion inhibitor composition. A corrosion inhibitor composition includes an organic solvent comprising an alcohol with a flash point of at least about 75° C.; a nitrogen containing compound; and an aqueous acid solution comprising HCl. 2. The method of claim 1 , wherein the alcohol comprises tetrahydrofurfuryl alcohol (THFA claim 1 , wherein the organic solvent is present in an amount of about 5% to about 100% by weight of the aqueous acid solution claim 1 , wherein the corrosion inhibitor composition further comprises at least one of ethylene glycol claim 1 , diethylene glycol claim 1 , propylene glycol claim 1 , surfactants claim 1 , and combinations thereof claim 1 , and wherein the surfactants are selected from the group consisting of linear alcohol ethoxylates claim 1 , amine alcohol ethoxylates claim 1 , ethoxylated amides claim 1 , ethoxylated alkyl amines claim 1 , alkylphenol claim 1 , alkyoxylated fatty acids claim 1 , and combinations thereof.3. (canceled)4. The method of claim 1 , wherein the at least one aldehyde comprises at least one aldehyde selected from the group consisting of 2-hydroxynapthaldehyde claim 1 , 7-phenyl-2 claim 1 ,4 claim 1 ,6-heptatrienal claim 1 , crotonaldehyde claim 1 , 2-hexenal claim 1 , 2-heptenal claim 1 , 2-octenal; 2-nonenal claim 1 , 2-decenal claim 1 , 2-undecenal claim 1 , 2-dodecenal claim 1 , 2 claim 1 ,4-hexadienal claim 1 , 2 claim 1 ,4-heptadienal claim 1 , 2 claim 1 ,4-octadienal claim 1 , 2 claim 1 ,4-nonadienal claim 1 , 2 claim 1 ,4-decadienal claim 1 , 2 claim 1 ,4- ...