СПОСОБ УЛУЧШЕНИЯ ПРОНИЦАЕМОСТИ ПОДЗЕМНОЙ НЕФТЕНОСНОЙ ФОРМАЦИИ

Настоящее изобретение относится к способу, который может использоваться при восстановлении проницаемости пористой нефтеносной формации. Восстановление проницаемости формации улучшает приемистость, ускоряя таким образом нефтеотдачу. Способ изобретения включает обработку формации композицией, которая включает комбинацию, по меньшей мере, одного неионного соединения, предпочтительно, алкоксилированного спирта с, по меньшей мере, одним катионным соединением, предпочтительно, соединением четвертичного аммония, в количестве, эффективном для улучшения проницаемости формации. Композиция также может необязательно содержать алкилгликозид. Техническим результатом является улучшение общей скорости извлечения нефти при вторичной добыче. 15 з.п. ф-лы.

Состав для удаления асфальтосмолопарафиновых отложений

Изобретение относится к нефтедобывающей промышленности, а именно к способам удаления и растворения асфальтосмолопарафиновых отложений - АСПО в призабойной зоне пласта (ПЗП), удаления с поверхности глубинного и устьевого нефтепромыслового оборудования, в резервуарах и нефтесборных коллекторах, магистральных нефтепроводах. Состав для удаления асфальтосмолопарафиновых отложений, содержащий гексан, неионогенное ПАВ и полярный неэлектролит, содержит в качестве неионогенного ПАВ - реагент ОП-10, в качестве полярного неэлектролита - изобутанол и дополнительно - гидроксид натрия - NaOH и О-ксилол при следующем соотношении компонентов, мас.%: гексан 65,0-80,0, реагент ОП-10 2,0-3,0, изобутанол 5,0-15,0, NaOH 0,08-0,12, О-ксилол 10,0-20,0. Технический результат - повышение растворяющей способности состава для удаления АСПО в осложненных условиях, расширение сырьевой базы, в том числе и с привлечением отходов нефтехимического производства. 3 пр., 3 ил.

СПОСОБ ОБРАБОТКИ ПОДЗЕМНЫХ ПЛАСТОВ

Изобретение относится к добыче нефти, газа или воды из скважин, пробуренных в подземном пласте. Способ обработки повреждения пласта месторождения в подземном пласте месторождения, в котором повреждение пласта вызвано следующими причинами: фильтрационными корками буровых флюидов на масляной основе, фильтрационными корками буровых флюидов на водной основе, нефтепромысловыми отложениями, асфальтеном, парафином, воском, резьбовой смазкой, эмульсией или водяным блоком, включает: введение в подземный пласт месторождения флюида для обработки, содержащего воду и по меньшей мере одно из следующих соединений циклодекстрина или крахмала с ферментом, способным генерировать циклодекстрин из крахмала, а также создание условий флюиду для обработки для устранения повреждения пласта. Применение циклодекстрина в качестве компонента флюида для обработки для устранения повреждения пласта в подземном пласте месторождения, в котором нарушение эксплуатационных качеств пласта месторождения вызвано следующими причинами ...

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 ...

ДИСПЕРГИРУЮЩАЯ ПРИСАДКА ДЛЯ АСФАЛЬТЕНОВ И ЕЕ ПРИМЕНЕНИЯ

Настоящее изобретение относится к применению по меньшей мере одной модифицированной алкилфенол-альдегидной смолы в композиции сырой нефти или в продукте, полученном из композиции сырой нефти и содержащем асфальтены, для диспергирования асфальтенов и/или для предотвращения, и/или замедления, и/или остановки, и/или снижения осаждения асфальтенов. При этом модифицированную алкилфенол-альдегидую смолу получают в ходе реакции Манниха алкилфенол-альдегидной конденсационной смолы с по меньшей мере одним альдегидом и/или одним кетоном, имеющим от 1 до 8 атомов углерода и по меньшей мере одним углеводородным соединением, имеющим по меньшей мере одну алкиламинную группу, имеющую от 1 до 30 атомов углерода, а алкилфенол-альдегидную конденсационную смолу получают при конденсации по меньшей мере одного алкилфенола, замещенного по меньшей мере одной линейной или разветвленной алкильной группой, имеющей от 1 до 30 атомов углерода, с по меньшей мере одним альдегидом и/или одним кетоном, имеющим от 1 до ...

ТЕКУЧАЯ СРЕДА ДЛЯ ОБСЛУЖИВАНИЯ СКВАЖИН

Изобретение относится к текучей среде для обслуживания скважин газовых, геотермальных, угольнопластовых метановых или нефтяных месторождений. Способ обслуживания ствола скважины включает: смешивание агента для снижения трения, анионогенного поверхностно-активного вещества, катионогенного поверхностно-активного вещества и водной основы с образованием вязкоупругого геля на водной основе, введение в ствол скважины текучей среды для обслуживания скважин, содержащей вязкоупругий гель на водной основе, где агент для снижения трения содержит по меньшей мере одно высокомолекулярное полимерное звено, выбранное из акриламидных групп, акрилатных групп, сульфогрупп и групп малеиновой кислоты, а гель на водной основе содержит анионогенное поверхностно-активное вещество и катионогенное поверхностно-активное вещество и где концентрация агента для снижения трения составляет 0,06 кг/м(0,5 фунта/1000 галлонов) или менее в расчете на всю текучую среду для обслуживания скважин. Технический результат - повышение ...

ТЕРМОСТАБИЛЬНЫЕ КОМПОЗИЦИИ ИНГИБИТОРОВ ОСАЖДЕНИЯ ПАРАФИНА

Изобретение относится к термостабильным композициям ингибиторов осаждения парафинов. Композиция ингибитора осаждения парафина для сырой нефти, содержащая неполимерное сложноэфирное соединение и от около 1 мас.% до 20 мас.% полимера, ингибирующего осаждение парафина, причем композиция является безводной и является текучей при температуре в диапазоне около 0°С и -40°С. Способ применения указанной выше композиции, включающий образование безводной жидкой композиции, содержащей неполимерное сложноэфирное соединение и от около 1 мас.% до 20 мас.% полимера, ингибирующего осаждение парафина, хранение безводной жидкой композиции в закрытом контейнере при первой температуре в диапазоне от около -40°С до 60°С, удаление безводной жидкой композиции из контейнера при второй температуре в диапазоне от около -40°С до 60°С и введение безводной жидкой композиции в источник сырой нефти, в котором удаление и введение осуществляют путем вливания или с помощью механического насоса. Применение указанной выше ...

СОСТАВ И СПОСОБ ПРИГОТОВЛЕНИЯ ТВЕРДОГО ПЕНООБРАЗОВАТЕЛЯ ДЛЯ УДАЛЕНИЯ ЖИДКОСТИ С ЗАБОЯ ГАЗОВЫХ И ГАЗОКОНДЕНСАТНЫХ СКВАЖИН

Изобретение относится к газодобывающей промышленности и может быть использовано для удаления водогазоконденсатной смеси с забоя газовых и газоконденсатных скважин. Технический результат - повышение пенообразующей способности, обеспечение эффективного удаления жидкости с забоя газовых и газоконденсатных скважин при различной минерализации скважинной жидкости, в широком диапазоне содержания углеводородной фазы, сохранение физико-химических свойств пенообразователя при повышенных температурах. Состав для приготовления твердого пенообразователя для удаления жидкости с забоя газовых и газоконденсатных скважин, содержащий поверхностно-активное вещество - ПАВ, мочевину, карбоксиметилцеллюлозу - КМЦ, в качестве ПАВ содержит МОРПЕН, представляющий собой смесь водо- и маслорастворимых алкилсульфатов и сульфоэтоксилатов натрия, при следующем соотношении компонентов, масс. %: МОРПЕН 24,9-28,4, мочевина 71,1-74,6, КМЦ 0,5-1,0. Способ приготовления твердого пенообразователя для удаления жидкости с забоя ...

СПОСОБЫ И СОСТАВЫ ДЛЯ ТЕПЛОВОЙ ОБРАБОТКИ ТРУБОПРОВОДА, ИСПОЛЬЗУЕМОГО ДЛЯ ДОБЫЧИ ИЛИ ТРАНСПОРТИРОВКИ УГЛЕВОДОРОДА, ДЛЯ ОБЛЕГЧЕНИЯ УДАЛЕНИЯ ОТЛОЖЕНИЙ ТВЕРДЫХ ПАРАФИНОВ

Группа изобретений относится к нефтяной и газовой промышленности, в частности к методам удаления отложений в трубопроводах для добычи и транспортировки углеводородов. Представлены способы увеличения температуры секции трубопровода, способы регулирования высвобождения реагентов, катализатора экзотермической реакции и полученные продукты. Согласно одному аспекту способ включает в себя этапы, на которых: формируют обрабатывающую жидкость, содержащую: несущую жидкость; и первый реагент, и второй реагент; и подают обрабатывающую жидкость в секцию трубопровода, используемого для добычи или транспортировки углеводородов. Первый реагент и второй реагент выбираются такими, чтобы вступать друг с другом в экзотермическую химическую реакцию; и первый, и второй реагенты находятся в концентрации в несущей жидкости, по меньшей мере, достаточной для получения теоретической теплоты реакции в количестве, по меньшей мере, 1000 кДж/л обрабатывающей жидкости. По меньшей мере, некоторое количество, по меньшей ...

Композиционный ингибитор осаждения нефтяных асфальтенов для процессов закачки CO2 в пласты

Изобретение относится к нефтедобывающей промышленности, а именно к составам, обеспечивающим коллоидную стабильность нефти в пластовых условиях, в частности, при закачке CO2, и может быть использовано в процессах добычи, транспорта и хранения нефти. Технический результат - ингибирование осаждения асфальтенов с эффективностью более 80 % при добавлении ингибитора в количестве 5,0-10,0 мас.% относительно количества углекислого газа СО2, расширение арсенала средств. Композиционный ингибитор осаждения нефтяных асфальтенов для процессов закачки СО2в пласты включает, мас.%: тяжелую смолу пиролиза 50-60; ксилол 37-48; нонилфенол 2-5. 3 табл., 38 пр.

СПОСОБ ПОЛУЧЕНИЯ ВЗВЕШЕННОЙ ДИСПЕРСНОЙ СМЕСИ ПОЛИМЕРОВ НА ОСНОВЕ МАСЛА ДЛЯ СНИЖЕНИЯ ГИДРАВЛИЧЕСКИХ ПОТЕРЬ И СМЕСЬ ТАКИХ ПОЛИМЕРОВ

... 1. Способ получения дисперсной композиции в виде суспензии на основе масла, содержащей полимеры для снижения сопротивления течению жидкости, при котором осуществляют добавление (в расчете на общую массу дисперсной композиции) 0,001-0,1 мас.% поглотителя ультрафиолетовых лучей и 0,001-0,1 мас.% бактерицидного агента в 50-90 мас.% растительного масла с получением первой смеси, смесь перемешивают до однородного состояния для использования в качестве диспергирующего агента; осуществляют добавление (в расчете на общую массу дисперсной композиции) 2-25 мас.% лубриканта в 10-40 мас.% сверхвысокомолекулярного α-олефин-стирольного полимера, обеспечивающего снижение сопротивления течению жидкости, с получением второй смеси, измельчение второй смеси при температуре не менее -90°С; осуществляют добавление полученного порошка в диспергирующий агент и перемешивание смеси с получением суспензии. 2. Способ по п.1, отличающийся тем, что в качестве лубриканта используют стеарат магния, стеарат кальция, стеарат ...

СПОСОБ СОЛЮБИЛИЗАЦИИ АСФАЛЬТЕНОВ В УГЛЕВОДОРОДНОЙ СМЕСИ

... 1. Способ солюбилизации асфальтенов в углеводородной смеси, содержащей асфальтены, отличающийся тем, что в смесь добавляют эффективное количество дендримерного соединения. 2. Способ по п.1, отличающийся тем, что дендримерное соединение функционализировано. 3. Способ по п.1 или 2, отличающийся тем, что дендримерное соединение представляет собой сверхразветвленный полиэфирамид. 4. Способ по п.3, отличающийся тем, что применяют сверхразветвленный полиэфирамид, который получен путем взаимодействия циклического ангидрида с ди-или триалканоламином по реакции (само)конденсации. 5. Способ по п.4, отличающийся тем, что используют сверхразветвленный полиэфирамид, который имеет среднечисловую молекулярную массу между 500 и 50000. 6. Способ по п.4 или 5, отличающийся тем, что циклический ангидрид выбирают из группы, состоящей из янтарного ангидрида, глутарового ангидрида, тетрагидрофталевого ангидрида, гексагидрофталевого ангидрида, фталевого ангидрида, ангидрида норборнен-2,3-дикарбоновой кислоты ...

СМЕСЬ ПРИВИТЫХ СОПОЛИМЕРОВ

... 1. Смесь привитых сополимеров на основе отличающихся друг от друга основ для прививки, отличающаяся тем, что привитые сополимеры содержат в качестве мономерного компонента а) бурый уголь и/или производные полифенолов и/или б) полиамиды, а также в) отличающиеся друг от друга ненасыщенные по типу этилена мономеры. ! 2. Смесь привитых сополимеров по п.1, отличающаяся тем, что привитые сополимеры содержат мономерные компоненты а) и б), в качестве основ для прививки и/или компонента для прививки и мономерный компонент в) в качестве компонента для прививки. ! 3. Смесь привитых сополимеров по п.1, отличающаяся тем, что привитые сополимеры состоят I) из мономерного компонента а) в качестве основы для прививки и, по крайней мере, одного из мономерных компонентов б) и в) в качестве компонента для прививки, II) из мономерного компонента б) в качестве основы для прививки и, по крайней мере, одного из мономерных компонентов а) и в) в качестве компонента для прививки, III) из мономерного компонента а ...

СПОСОБ ТЕРМОХИМИЧЕСКОЙ ОБРАБОТКИ ПЛАСТА

Изобретение относится к нефтедобывающей промышленности. Технический результат - повышение эффективности теплового воздействия на пласт за счет увеличения времени достижения максимальной температуры разогрева реакционной смесью водных растворов нитрита натрия и сульфаминовой кислоты. Способ термохимической обработки пласта включает закачку в пласт водного раствора нитрита натрия при следующем соотношении компонентов, мас.%: нитрит натрия 17-46; вода пресная остальное, и водного раствора сульфаминовой кислоты с рН 4,0-5,0 при следующем соотношении компонентов, мас.%: сульфаминовая кислота 10-50; гидроксид натрия или водный аммиак 8-30; уксуснокислый аммоний 1-7; вода пресная остальное. Закачку в пласт указанных водных растворов осуществляют в объемах, обеспечивающих стехиометрическое взаимодействие нитрита натрия и сульфаминовой кислоты. 1 табл.

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СПОСОБ УДАЛЕНИЯ БИТУМА ДЛЯ УЛУЧШЕНИЯ ПРОНИЦАЕМОСТИ ПЛАСТА

ПРЕДУПРЕЖДЕНИЕ СКОПЛЕНИЯ БИОМАССЫ В НАГРЕВАТЕЛЬНЫХ СКВАЖИНАХ

... 1. Способ обработки подземного целевого участка, включающий этапы:a) приготовления суспензии биомассы, содержащей один или несколько видов микроорганизмов;b) введения суспензии (a) в ствол нагнетательной скважины подземного целевого участка;с) необязательного введения одной или нескольких жидкостей в ствол нагнетательной скважины;d) введения первого состава раствора питательных веществ в ствол нагнетательной скважины, где указанный первый раствор питательных веществ поддерживает рост одного или нескольких микроорганизмов из (a) в указанном подземном целевом участке, но не способствует скоплению биомассы и образованию биопленки; а такжеe) введения второго состава раствора питательных веществ в ствол нагнетательной скважины, где указанный второй состав раствора питательных веществ обеспечивает биозакупорку пор и каналов в подземном целевом участке.2. Способ по п.1, где одна или несколько жидкостей из (c) содействует перемещению суспензии одного или нескольких микроорганизмов из (a) в подземный ...

СПОСОБ ПОДАВЛЕНИЯ ОБРАСТАНИЯ МЕТАЛЛИЧЕСКИХ ПОВЕРХНОСТЕЙ С ИСПОЛЬЗОВАНИЕМ АГЕНТА ДЛЯ МОДИФИКАЦИИ ПОВЕРХНОСТИ

ТЕРМОСТАБИЛЬНЫЕ КОМПОЗИЦИИ ИНГИБИТОРОВ ОБРАЗОВАНИЯ ОТЛОЖЕНИЙ

УСТРАНЕНИЕ ВЫЗВАННОГО АСФАЛЬТЕНАМИ ЗАКУПОРИВАНИЯ СТВОЛОВ СКВАЖИН И ЭКСПЛУАТАЦИОННЫХ ТРУБОПРОВОДОВ

СПОСОБЫ ИЗВЛЕЧЕНИЯ УГЛЕВОДОРОДОВ ИЗ ПОДЗЕМНОГО ПЛАСТА И СПОСОБЫ ОБРАБОТКИ УГЛЕВОДОРОДНОГО МАТЕРИАЛА ВНУТРИ ПОДЗЕМНОГО ПЛАСТА

СПОСОБ ОБРАБОТКИ ПОДЗЕМНЫХ РЕЗЕРВУАРОВ

... 1. Способ обработки подземного пласта, где данный способ включает: ! (a) введение в подземный пласт мицеллярной дисперсии, содержащей воду, одного или нескольких предшественников органических кислот, одно или несколько поверхностно-активных веществ и необязательно одного или нескольких представителей, выбираемых из солей, вспомогательных поверхностно-активных веществ и/или органических жидкостей, которые не являются предшественниками органических кислот; и ! (b) обеспечение (i) солюбилизации мицеллярной дисперсией углеводородов, эмульсий или водяных барьеров, присутствующих в подземном пласте, и (ii) гидролиза «in situ», по меньшей мере, части предшественника органической кислоты для получения количества органической кислоты, достаточного, по существу, для растворения кислоторастворимого материала, присутствующего в фильтрационных корках, или другом повреждении в подземном пласте, или по соседству с ними. ! 2. Способ по п.1, где предшественником органической кислоты являются сложный эфир ...

Способ предотвращения отложения парафина в нефтепромысловом оборудовании

Реагент для удаления твердых парафиновых отложений в нефтяных скважинах

Применение госсиполовой смолыкубового остатка дистилляции жирных кислот, вццеляемых из хлопковых соапстокоВ|В качестве реагента для удаления твердых парафиновых отложений в нефтяных скважинах. в ...

Verfahren zur Verhinderung und Behebung von Stoerungen durch Wachsabscheidung bei der Gewinnung, Weiterleitung und Lagerung von Erdoel und Naturgas

Pfropfcopolymer als Gashydratinhibitor

Es werden Pfropfcopolymere auf Basis eines Polyamids vorgeschlagen, welches mit Maleinsäureanhydrid umgesetzt wurde und das mindestens eine vinylisch ungesättigte Seitenkette aufweist, wobei diese gepfropfte Seitenkette mindestens einen Vertreter, ausgewählt aus a) N-Vinylcaprolactam und/oder b) N-Vinylpyrrolidon, enthält. Als bevorzugte Polyamid-Komponenten sind unter anderem natürliche, aber auch synthetische Polyamide vorgesehen. Derartige Pfropfcopolymere, aber auch allgemein Pfropfcopolymere auf Polyamidbasis und aufgebaut aus mindestens einer ethylenisch ungesättigte Verbindungen enthaltenden Seitenkette, eignen sich allgemein in bauchemischen Anwendungen, aber auch bei der Erschließung, Ausbeutung und Komplettierung unterirdischer Erdöl- und Erdgaslagerstätten sowie bei Tiefbohrungen und außerdem bei der Förderung und dem Transport von Öl oder Gas und hier insbesondere als Gashydratinhibitor.

Process for disruption of filter cakes

METHOD FOR INHIBITING THE DEPOSITION OF WAX FROM WAX-CONTAINING CRUDE OIL

... 1403782 Inhibiting deposition of wax from crude oil UNION OIL CO OF CALIFORNIA 16 May 1972 22989/72 Heading C5E The deposition of wax from waxy crude oils onto metal surfaces in contact with the oil is inhibited by incorporating into the oil a copolymer of ethylene and vinyl acetate containing 35 to 70% of vinyl acetate and having a melt index of 1 to 600 g. per 10 minutes. The method can be applied to the oil in a well. A solution of the polymer in an organic solvent may be added to the oil when it is warm enough to maintain the wax in solution, and the oil when cooled below the soldification point of the wax. Accumulated wax deposits can be removed from metal surfaces in contact with a waxy crude oil by the periodic addition of the copolymer of the oil.

Method and composition for inhibiting asphaltene deposition in a hydrocarbon mixture

Preparation of phosphate esters having reduced phosphorus volatility from phosphorus pentoxide, for use in non-volatile phosphorus hydrocarbon gelling agent

Phosphate esters (being mono-, di- or tri-alkyl phosphate esters) having reduced, negligible or no volatile phosphorus at temperatures below about 250{C are prepared by contacting phosphorus pentoxide with an alkoxide donor under appropriate conditions of temperature, pressure and reaction time (e.g. 93-149{C, at or near atmospheric pressure and for 0.5-12 hours). The alkoxide donor is a mono-, di- or tri-alkyl phosphate, or an alcohol, or mixtures thereof, wherein the alkyl groups and the alcohol all have at least four carbon atoms, and one or more of such carbon atoms may be replaced by nitrogen or oxygen and the atom sequences may be acyclic or cyclic, saturated or unsaturated, or comprise combinations thereof. Preferably, phosphorus pentoxide is reacted first with a mono-, di- or tri-alkyl phosphate and the product thereof is further reacted with an alcohol. Such esters may be used as an improved chemical gelling additive for hydrocarbon based fracturing fluids having reduced, negligible ...

Preparation of phosphate esters having reduced phosphorus volatility from phosphorus pentoxide, for use in non-volatile phosphorus hydrocarbon gelling agent

Method of treating an oil or gas well with biodegradable low toxicity fluid system

A method for preventing the formation of calcium carboxylate deposits in the dewatering process for crude oil/water streams

Compositions

WAXY CRUDE OIL COMPOSITIONS

... 1382045 Waxy crude oil composition SHELL INTERNATIONALE RESEARCH MAATSCHAPPIJ NV 3 March 1972 [5 March 1971] 6132/71 Heading C5G and C5E A waxy crude oil contains a polymer having a number average molecular weight of at least 4000 and being produced by the copolymerization of (1) at least one olefinically unsaturated compound containing an aliphatic hydrocarbon side chain with at least 10 C atoms, (ii) at least one olefinically unsaturated compound containing a heterocyclic ring and optionally (iii) up to 50 mole per cent of at least one olefinically unsaturated compound containing neither such a heterocyclic ring nor such a side chain. Examples of (i) are alkyl esters of unsaturated carboxylic acids, vinyl and allyl esters of saturated carboxylic acids, amides and imides of unsaturated carboxylic acids, and alkyl vinyl ethers. Examples of (ii) are sulpholene and vinyl compounds of pyridine, quinolene, or isoquinolene. The examples describe copolymers of alkyl acrylates with 4-vinyl pyridine ...

Composition and process for cleaning pipe dope and other solids from well systems

An improved chemical composition and process for cleaning pipe dope from wellbores has been established. The chemical composition is of an aliphatic hydrocarbon and/or esters with a biodegradable water insoluble monoterpene,preferably having a flash point (PMCC) greater than 140{F (approx. 60{C), the mixture then used neat, or in a dispersion of seawater, being used to remove pipe dope from tubing, casing and the like.

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

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

Composition for removing petroleum sludges from vessels

PCT No. PCT/FR81/00168 Sec. 371 Date Aug. 16, 1982 Sec. 102(e) Date Aug. 16, 1982 PCT Filed Dec. 23, 1981 PCT Pub. No. WO82/02177 PCT Pub. Date Jul. 8, 1982.A composition for recovering and upgrading sludge that accumulates in vessels for storing and transporting petroleum products comprises a solvent made up of at least one aliphatic hydrocarbon and at least one aromatic monohalogenated hydrocarbon of the benzene or naphthalene type, together with a demulsifying and dispersing agent that is an aliphatic straight-chain oxyethylated amineated derivative or a quaternary ammonium compound having at least one alkyl and at least one aryl residue in the form of thiocyano derivative. The composition is dissolved in a hydrocarbon in a proportion of from 2 to 10% by weight, the resulting solution is projected on to the residues at a pressure of from 2 to 15 bars, and the resulting suspension is recycled, recovered, and treated like crude oil. The invention is applied to the recovery and upgrading ...

Water removal from anti-agglomerate LDHIs

Squeeze process for reactivation of well treatment fluids containing a water insoluble adsorbant

Squeeze process for reactivation of well treatment fluids containing a water insoluble adsorbant A wellbore process involves the steps of injecting an initial charge of a mixture, the mixture being formed from at least a water-insoluble adsorbent and at least one well treatment agent, into a well bore formed in the subterraneous formation so as to form a downhole matrix within the formation; and then pressurizing the well bore for a time and under conditions sufficient to reactivate the downhole matrix in the formation, so that the treatment agent activity of the matrix is increased relative to the treatment agent activity of the matrix just prior to injecting the solution. The formation may be pressurised below its fracture pressure. The matrix may be used to filter formation particles and can be deposited around a screen.

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

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.

Asphaltene dispersants

The present disclosure relates to compositions and methods for prevent the formation of and disperse aggregates and other poorly soluble materials in hydrocarbon fluids. The compositions include an asphaltene dispersant prepared from the reaction of a polyethyleneimine (PEI) dendrimer and one or more derivatizing reagents wherein the polyethylene dendrimer has a weight average molecular weight of greater than or equal to 9 kDa. The methods include emplacing in a wellbore a composition comprising an asphaltene inhibitor, wherein the asphaltene inhibitor is a compound prepared from the reaction of a polyethyleneimine dendrimer and one or more derivatizing reagents wherein the polyethylene dendrimer has a weight average molecular weight of greater than or equal to 9 kDa.

Fatty amides and derivatives from natural oil metathesis

A method for improving the low properties of a crude oil or natural gas liquid

A method for improving the flow of properties of a crude oil or natural gas liquid.

A method to improve the flow properties of wax containing crude oils and natural gas liquids which contain a natural pour point depressant by adding a synthetic pour point depressant at a higher temperature than 20c below the inversion temperature of the crude oil or natural gas liquid.

A method for improving the low properties of a crude oil or natural gas liquid

FATTY AMIDES AND DERIVATIVES FROM NATURAL OIL METATHESIS

A method for improving the low properties of a crude oil or natural gas liquid

Fatty amides and derivatives from natural oil metathesis

Method of preparation of an injectable mixture and gélifiable in situ in a confined space

A method for the thermo-chemical dewaxing of largedimension lines

Stabilization of crude oil.

Improved method for the thermo-chemical dewaxing of large dimension lines

Fatty amides and derivatives from natural oil metathesis

THE PRODUCTION OF CRUDE OIL STIMULATING SUBSTANCES AND PROCEDURE FOR THEIR SUBSEQUENT TREATMENT

SOAP FIGHT MEANS

COMPOSITION AND PROCEDURE FOR RECOVERING AND FOR THE VALORISIEREN OF PETROLEUM PRODUCTS.

Procedure for the prevention of deposits in the probes and lines during the crude oil promotion

PROCEDURE FOR THE DEGRADATION OF THE WAX ELIMINATION TEMPERATURE OF WAX CONTAINING CRUDE OIL

Anti-agglomerate hydrate inhibitors

A hydrate inhibitor comprising a sulfolane derivative and associated methods and compositions.

LOW MOLECULAR WEIGHT POLYACRYLATES FOR EOR

The disclosure is directed to low molecular weight polyelectrolyte complex nanoparticles that can be used to deliver agents deep into hydrocarbon reservoirs. Methods of making and using said polyelectrolyte complex nanoparticles are also provided.

Precipitation prevention in produced water containing hydrate inhibitors injected downhole

The precipitation of polymeric kinetic hydrate inhibitors (KHIs) in stored produced water is prevented or inhibited by incorporating a water immiscible solvent therein having a polarity index greater than about 3. The polymeric KHIs whose precipitation is inhibited or prevented include, but are not limited to, hyperbranched molecules, polyvinylcaprolactam, polyvinylpyrrolidone, and the like. Suitable water immiscible solvents include, but are not necessarily limited to, xylene, toluene, kerosene, mineral spirits, trimethylbenzene, cumene, heavy aromatic naphtha, ethylbenzene, polyethylbenzene, naphthalene, and mixtures thereof.

Low dosage polymeric naphthenate inhibitors

Polymeric naphthenate inhibitors may be delivered into production fluids for contact with mixtures of oil and water, such as in a hydrocarbon producing formation, production equipment, or processing systems. These polymeric naphthenate inhibitors exhibit surface-active properties that cause the inhibitors to self-associate at oil- water interfaces. The relatively large surface area makes these polymers more persistent and more efficient in terms of required concentration. The presence of these polymers on the oil/water interface inhibits interactions between organic acids in the oil with cations or cation complexes in water. These compounds also inhibit aggregation of organic acid carboxylate salts that form when pH and pressure conditions are amenable to organic acid ionization. Preferred inhibitors do not form emulsions due to the formation of unstable mixed interface structures that result in coalescence of dispersed droplets. Naphthenate inhibitor compound dosages of less than 100 ppm ...

METHOD OF DEPOSITING POLYMERIC POUR POINT DEPRESSANT IN AN OIL PRODUCING FORMATION

METHODS AND COMPOSITIONS FOR USE IN OIL AND/OR GAS WELLS

Abstract Methods and compositions comprising an emulsion or a microemulsion for use in various aspects of the life cycle of an oil and/or gas well are provided. In some 5 embodiments, the emulsion or the microemulsion comprises water, a solvent, and a surfactant, and optionally, one or more additives. In some embodiments, methods for preventing, reducing, or eliminating a crude oil emulsion in an oil and/or gas well are provided.

Methods of mitigating bituminous material adhesion using nano-particles

Embodiments relate to solid nano-particles applied to the surface of well equipment to treat bituminous material adhesion. An embodiment provides a method of treating the surface of well equipment. The method may comprise applying a solid nanoparticle film to the surface of the well equipment with a treatment fluid comprising solid nanoparticles. The method may further comprise allowing the solid nanoparticles to interact with the surface of the well equipment and/or bituminous materials adhered to the surface of the well equipment to remove at least a portion of the bituminous materials from the surface of the well equipment.

Composites for use in stimulation and sand control operations

A composite having a solid particulate and a surface modifying treatment agent on the solid particulate wherein the surface modifying treatment agent has a hydrophobic tail and an anchor for adhering the hydrophobic tail onto the solid particulate. The anchor may be metal and the hydrophobic tail may be an organo-silicon material, a fluorinated hydrocarbon or both an organo-silicon material and a fluorinated hydrocarbon. The composite may be used as a proppant in a hydraulic fracturing operation as well as a sand control particulate in a gravel packing operation. The presence of the surface modifying treatment agent on the surface of the solid particulate reduces the generation of fines and dust as well as the migration of sand during a hydraulic fracturing operation or a sand control operation. The presence of the surface modifying treatment agent on the surface of the solid particulate further enhances the crush resistance of the solid particulate.

Chlorine dioxide precursor and methods of using same

According to one aspect of the invention, a method of converting an oxy halide salt into a halide dioxide in a reaction zone under certain conditions is provided. More specifically, the method includes generating chlorine dioxide from a stable composition comprising an oxy halide salt by introducing said composition to a reducing agent and minimum temperature within the reaction zone. According to another aspect of the invention, a composition for a stable chlorine dioxide precursor comprising an oxy halide salt is provided.

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.

Treatment fluids comprising magnetic surfactants and methods relating thereto

Treatment fluids that include magnetic surfactants may be useful in various subterranean operations, e.g., particulate placement operations and drilling operations. For example, some methods may include introducing a treatment fluid into a wellbore penetrating a subterranean formation, the treatment fluid including at least a base fluid and a magnetic surfactant, the magnetic surfactant being a cationic surfactant having a magnetically susceptible counterion.

Method for treatment of underground reservoirs

A process is disclosed for treating an underground formation, which process comprises: (a) introducing into the underground formation a micellar dispersion comprising water, one or more organic acid precursors, one or more surfactants and, optionally, one or more salts, co-surfactants and/or organic liquids that are not organic acid precursors; and (b) allowing (i) the micellar dispersion to solubilise hydrocarbons, emulsions or water blocks present in the underground formation, and (ii) at least a portion of the organic acid precursor to hydrolyse ...

Demulsifier composition and method of using same

Disclosed and claimed is a microemulsion-based demulsifier composition and a method of demulsifying an emulsion comprising hydrocarbon and water. The demulsifier composition includes (i) an oil-like phase comprising at least one nonionic surfactant having a hydrophilic-lipophilic balance (HLB) of less than about 9; (ii) a coupling agent capable of stabilizing the demulsifier composition; (iii) at least one water-soluble or dispersible nonionic surfactant that is different from the at least one nonionic surfactant in the oil-like phase; (iv) at least one additional surfactant selected from anionic, cationic, amphoteric, and combinations thereof; (v) at least one nonionic demulsifier; and (vi) water.

Hydraulic fracturing composition, method for making and use of same

A hydraulic fracturing composition includes: a superabsorbent polymer in an expanded state; a plurality of proppant particles disposed in the superabsorbent polymer; a well treatment agent, and a fluid to expand the superabsorbent polymer into the expanded state. A process for treating a well with well treatment agent includes disposing a hydraulic fracturing composition comprising the well treatment agent in a well. The well treatment agent can be a scale inhibitor, tracer, pH buffering agent, or a combination thereof.

Compositions and methods for hindering asphaltene deposition

Metal silicides in hydrocarbon production and transportation

USE OF METAL SILICIDES IN HYDROCARBON PRODUCTION AND TRANSPORTATION A method of hydraulic fracturing is provided which uses metal silicides to generate significant pressure inside a wellbore. The method comprises injecting a fracturing fluid and an aqueous or reacting fluid into the wellbore to react with the fracturing fluid. The fracturing fluid comprises metal silicide, which may be uncoated or coated, and hydrocarbon fluid. The reacting fluid comprises water or a solvent. A method of removing buildup in pipelines such as subsea pipelines which uses metal silicides to generate heat and pressure inside the pipeline is also provided. The method comprises injecting an organic slug and an aqueous slug. The organic slug comprises metal silicide and hydrocarbon fluid. The aqueous slug comprises water. Alternatively, there is also provided a method for purifying flowback water produced from a hydraulic fracturing process comprising adding metal silicide to the flowback water produced from a ...

COMPOSITIONS AND METHODS OF USING SAME IN PRODUCING HEAVY OIL AND BITUMEN

Compositions and methods of using same are described for negating asphaltene deposition in a formation, wellbore, near wellbore region, and production tubing. Compositions of the invention comprise an asphaltene solvent and a viscosity reducing agent, the asphaltene solvent and viscosity reducing agent present in a ratio so as to substantially reduce viscosity of an asphaltene-containing material while substantially negating deposition of asphaltenes either in a reservoir, in production tubing, or both when mixed or otherwise contacting the asphaltene-containing material. Methods of the invention comprise forcing a composition comprising an asphaltene solvent and a viscosity reducing agent to contact an asphaltene-containing hydrocarbon in an underground geologic formation, and producing from the formation a production composition comprising at least some of the treatment composition and at least some of the asphaltene- containing hydrocarbon under conditions sufficient to substantially ...

METHOD FOR SOLUBILISING ASPHALTENES IN A HYDROCARBON MIXTURE

Method for solubilising asphaltenes in an asphaltenes-containing hydrocarbon mixture by adding thereto an effective amount of a dendrimeric compound, and a hydrocarbon mixture comprising, in addition to hydrocarbons, asphaltenes and at least one dendrimeric compound. Preferably, the dendrimeric compound is a hyperbranched polyester amide, more preferably a polyester amide built up from succinic anhydride, diisopropanolamine, functionalised with poly (isobutenyl) succinic anhydride.

PROCESS OF SEALING A BREAKTHROUGH CREATED DURING THE PRODUCTION OF HYDROCARBONS IN A SUBTERRANEAN FORMATION

This invention relates to a method for sealing a breakthrough penetrating an injection well.

COMPOSITIONS AND METHODS FOR TREATMENT OF WELL BORE TAR

Of the many compositions and methods provided herein, one method includes a method comprising: contacting tar resident in a well bore with a treatment fluid comprising a styrene-acrylate polymer; and allowing the styrene-acrylate polymer to interact with the tar to at least partially reduce the tendency of the tar to adhere to a surface. Another method provided herein includes a method for treating tar sand comprising: contacting the tar sand with a treatment fluid comprising an aqueous fluid and a styrene-acrylate polymer, the tar sand comprising tar and sand; and allowing the styrene-acrylate polymers to interact with the tar to at least partially separate the tar from the sand.

PROCESS FOR REMEDIAL CEMENTING

An improved method is disclosed for remedial cementing operations. Prior to conducting the remedial cementing operation, the zone to be cemented is pretreated with a hydrocarbon solvent capable of dissolving hydrocarbons, such as oils and asphaltenes. Following solvent treatment, the zone may be treated with an acid solution capable of dissolving mineral constituents.

CRUDE OIL RECOVERY

ASPHALTENE DISPERSANTS FOR PETROLEUM PRODUCTS

An imidazoline-containing product useful for dispersing asphaltenes in heavy crude oil or residual fuel oil.

TREATMENT OF OIL AND GAS WELLS AND OIL HANDLING EQUIPMENT

A method of treating an oil well or a gas well to restore production capacity. In certain embodiments, the method comprises mixing a coagulant, a surfactant, and water or production brine to produce a well treatment mixture; injecting the treatment mixture into the oil well; operating the oil well to distribute the treatment mixture throughout the oil well; and withdrawing a the treatment mixture, oil, production brine, and oil waste constituents from the oil well. As a result of the treatment compositions and methods, the oil waste constituents may include dissolved and or delaminated paraffin removed from surfaces of the oil well. In certain embodiments, following treatment, the oil well is substantially free of paraffin deposits.

METHOD AND APPARATUS TO PRODUCE SALES OIL IN A SURFACE FACILITY FOR A SOLVENT BASED EOR PROCESS

A method of separating a heavy hydrocarbon fraction from a mixed fluid production stream produced from an underground reservoir is shown wherein the mixed fluid production stream is produced by means of a solvent based in situ gravity drainage process, the mixed fluid production stream including at least some water, some heavy hydrocarbons including oil, some light hydrocarbons including solvent and some solids. The method includes adjusting a solvent to oil ratio of the mixed fluid stream by doing one or both of reducing the solvent content and increasing an oil content in an amount to dissolve asphaltene particles found in the mixed fluid stream and to thereby destabilize any emulsions present in said mixed fluid production stream. This promotes passive separation of a water fraction from said mixed fluid stream.

POLYMER DISPERSIONS FOR WAX INHIBITION DURING STIMULATION TREATMENT

The present invention relates to a method of inhibiting or control wax formation during stimulation treatment of a well. More specifically, the present invention proposes the use of aqueous polymer dispersions suitable as wax inhibitor compositions which are compatible with aqueous fracturing fluids.

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.

TRIGGERING AN EXOTHERMIC REACTION FOR RESERVOIRS USING MICROWAVES

Compositions and methods for triggering an exothermic reaction of an exothermic reaction component are provided. A method includes the steps of mixing the exothermic reaction component in an aqueous solution to achieve a pre-selected solution pH, where the aqueous solution operably delays triggering of the exothermic reaction upon reaching a pre-determined temperature of a hydrocarbon-bearing formation; disposing the exothermic reaction component within the hydrocarbon-bearing formation; applying microwaves to the exothermic reaction component, where the microwaves are operable to trigger the exothermic reaction of the exothermic reaction component; and generating heat and gas in situ by the exothermic reaction to increase pressure and temperature of the hydrocarbon-bearing formation proximate the exothermic reaction component.

COMPOSITION FOR REMEDIATING IRON SULFIDE IN OILFIELD PRODUCTION SYSTEMS

A composition for inhibiting corrosion and/or removing hydrocarbonaceous deposits in oil and gas applications is provided. The composition comprises an iron sulfide dissolver, an organic solvent, and a corrosion inhibitor.

USE OF GASEOUS PHASE NATURAL GAS AS A CARRIER FLUID DURING A WELL INTERVENTION OPERATION

Methods for servicing a hydrocarbon well using natural gas are provided. The method can include preparing a working fluid comprising about 5 vol% to about 100 vol% of natural gas. A quantity of the natural gas in the working fluid can be sufficient to form a heterogeneous phase well servicing mixture of a gaseous phase natural gas and a solid or liquid phase recovery target material under specified well intervention conditions. During the well servicing operation and under the specified well intervention conditions, the working fluid can be injected into the well and mixing the working fluid with the recovery target material in the well to form the heterogeneous phase well servicing mixture. The natural gas can be in a gas phase and can serve as a carrier fluid for the recovery target material. At least a portion of the heterogeneous phase well servicing mixture can be recovered at surface.

MIXTURE OF COMPOUNDS, ORGANIC BASES, INORGANIC COMPOUNDS AND OXIDIZING COMPOUNDS USED IN THE PRODUCTION, IMPROVED RECOVERY AND TREATMENT OF LIG HT, MEDIUM, HEAVY, EXTRA HEAVY, HYDROCARBONS AND BITUMINOUS SANDS

TEMPERATURE-STABLE PARAFFIN INHIBITOR COMPOSITIONS

Disclosed are compositions including up to 20 wt% of a paraffin inhibiting polymer and one or more non-polymeric glycol ether compounds, wherein the compositions are stable and flow at a temperature between about 0 °C and -40 °C, in many cases between about -20 °C and -40 °C. The glycol ether compounds are non-polymeric, are liquids at 20 °C (1 atm) and have boiling points over 100 °C, in many cases over 200 °C. The compositions are useful paraffin inhibitor concentrates for use in the petroleum industry wherein the concentrates are stable, pumpable, and pourable at temperatures as low as -40 °C and as high as 60 °C.

FATTY ALCOHOLS AND ESTERS FOR CRUDE OIL TREATMENT

Compounds are provided that can be used in methods for reducing paraffin or wax deposition in crude oil during processing, storage, or transportation. More specifically, the method comprises contacting the crude oil with a composition in an amount effective to reduce paraffin or was deposition.

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.

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

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

Compositions And Methods For Inhibiting Naphthenate Solids Formation From Liquid Hydrocarbons

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

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

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

Compositions and Methods for Treatment of Well Bore Tar

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

Nanoparticle Kinetic Gas Hydrate Inhibitors

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

Asphaltene Inhibitors for Squeeze Applications

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

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

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

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).

PETROLEUM ASHPHALTENE HANDLER ADDITIVE COMPOUND

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

Treatment fluids comprising magnetic surfactants and methods relating thereto

Treatment fluids that include magnetic surfactants may be useful in various subterranean operations, e.g., particulate placement operations and drilling operations. For example, some methods may include introducing a treatment fluid into a wellbore penetrating a subterranean formation, the treatment fluid including at least a base fluid and a magnetic surfactant, the magnetic surfactant being a cationic surfactant having a magnetically susceptible counterion.

Alkylphenol Copolymer

An alkylphenol copolymer, such as for use in a petroleum composition, is provided. The alkylphenol copolymer has at least the following repeating unit (I): 173-. (canceled)75. The alkylphenol copolymer of claim 74 , wherein A is a C-Calkylene.76. The alkylphenol copolymer of claim 74 , wherein X is —C(O)O—.77. The alkylphenol copolymer of claim 74 , wherein Rincludes a C-Calkyl.78. The alkylphenol copolymer of claim 74 , wherein Rincludes a C-Calkyl.79. The alkylphenol copolymer of claim 74 , wherein Rincludes a polyether.80. The alkylphenol copolymer of claim 79 , wherein the polyether includes a polyethylene glycol.81. The alkylphenol copolymer of claim 74 , wherein n is an integer from 1 to 100.82. The alkylphenol copolymer of claim 74 , wherein the repeating unit (I) comprises from 0.1% to 75% of the repeating units of the alkylphenol copolymer.83. The alkylphenol copolymer of claim 74 , wherein the repeating unit (II) comprises from 25% to 98% of the repeating units of the alkylphenol copolymer.85. The alkylphenol copolymer of claim 84 , wherein Ris a C-Calkyl.86. The alkylphenol copolymer of claim 84 , wherein Ris a C-Calkyl.87. The alkylphenol copolymer of claim 86 , wherein Rincludes from 24 to 34 carbon atoms.88. The alkylphenol copolymer of claim 84 , wherein the alkyl of Rcontains 3 or more carbon atoms than the alkyl of R.89. The alkylphenol copolymer of claim 84 , wherein o and p are independently from 5 to 25.90. The alkylphenol copolymer of claim 84 , wherein the ratio of the moles of the repeating unit (II) to the moles of the repeating unit (IV) is from about 0.2 to about 5.91. A paraffin inhibitor composition comprising the alkylphenol copolymer of .92. An asphaltene dispersant composition comprising the alkylphenol copolymer of .93. A petroleum composition comprising the alkylphenol copolymer of and a petroleum source.94. A method for modifying a petroleum source claim 74 , the method comprising adding the alkylphenol copolymer of to a petroleum ...

WAX DEPOSIT REMOVAL USING AQUEOUS SURFACTANT

A method and system for removing wax deposits from a wellbore and other oil production and processing equipment using a wax removal surfactant having at least 1% alkyl polyglycoside (APG), at least 0.5% ethoxylated alcohol (AE) or alcohol ethoxysulfates (AES), and at least 1% saturated alcohol, and optionally comprising D-Limonene, wherein the wax removal surfactant solution forms a Winsor Type III or Type IV microemulsion with water and wax. 1. A method of removing wax deposits from oil production or processing equipment (OPPE) , said method comprising:a. determining that efficiency is reduced in OPPE as a result of wax deposits;b. adding a wax removal surfactant having a temperature of at least 50° C. into said OPPE in an amount sufficient to dissolve said wax deposits, said wax removal surfactant comprising an aqueous solution having at least 1% alkyl polyglycoside (APG), at least 0.5% ethoxylated alcohol (AE) or alcohol ethoxysulfates (AES), and at least 1% saturated alcohol, wherein said wax removal surfactant solution forms a microemulsion with water and wax and/or oil; andc. recovering or removing said wax removal surfactant plus dissolved wax deposits, thus leaving said OPPE with reduced or no wax deposits.2. The method of claim 1 , wherein said wax removal surfactant is used at temperatures of ≥60°.3. The method of claim 1 , wherein said wax removal surfactant further comprises D-limonene.4. The method of claim 1 , wherein said wax removal surfactant further comprises 2-25% D-limonene.5. The method of claim 1 , wherein said APG are C8-C16 claim 1 , said EA or AES are C8-C15 with an average of about 2-14 ethylene oxide groups claim 1 , and said saturated alcohols are about C3-C15.6. The method of claim 1 , wherein said APG are C10-C14 alkyl polyglucosides claim 1 , said ethoxylated alcohols are C9-C15 with an average of about 12 ethylene oxide groups claim 1 , and said saturated alcohols are about C3-C8.7. The method of claim 5 , wherein said wax removal ...

TREATMENT OF OIL AND GAS WELLS AND OIL HANDLING EQUIPMENT

A method of treating an oil well or a gas well to restore production capacity. In certain embodiments, the method comprises mixing a coagulant, a surfactant, and water or production brine to produce a well treatment mixture; injecting the treatment mixture into the oil well; operating the oil well to distribute the treatment mixture throughout the oil well; and withdrawing a the treatment mixture, oil, production brine, and oil waste constituents from the oil well. As a result of the treatment compositions and methods, the oil waste constituents may include dissolved and or delaminated paraffin removed from surfaces of the oil well. In certain embodiments, following treatment, the oil well is substantially free of paraffin deposits. 1. A method of treating an oil well , the method comprising:a) mixing a coagulant, a surfactant, and water or production brine or other salt water to produce a well treatment mixture;b) injecting the treatment mixture into the oil well;c) operating the oil well to distribute the treatment mixture throughout the upper portion of the oil well; andd) withdrawing oil and production brine from the oil well containing a mixture of oil, the treatment mixture and other constituents including dissolved and/or delaminated paraffins.2. The method of claim 1 , wherein following treatment claim 1 , the oil well is substantially free of paraffin deposits.3. The method of claim 1 , further comprising preventing freezing of an aqueous portion of the treatment mixture by adding at least one of chloride salts or nitrate to lower the freezing temperature of the mixture.4. A method of treating natural gas well claim 1 , the method comprising:a) mixing a coagulant, a surfactant, and water or production brine to produce a well treatment mixture;b) injecting the treatment mixture into the gas well;c) operating the gas well to distribute the treatment mixture throughout the upper portion of the gas well; andd) withdrawing natural gas and production brine from ...

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 ...

DOUBLE-HEADED HYDRATE INHIBITORS AND METHODS OF USE

Compositions and methods of using of such compositions to, for example, inhibit of the formation of gas hydrate agglomerates are provided. In one embodiment, the methods comprise: introducing a hydrate inhibitor composition comprising a compound into a fluid, wherein the compound comprises two hydrophobic cation moieties, a lipophilic tail, and two linking moieties. 2. The hydrate inhibitor composition of claim 1 , wherein each of X and Y is independently 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 , and any combination thereof.3. The hydrate inhibitor composition of claim 1 , wherein Ris a Cto Chydrocarbon chain resulting from a reaction between an acrylate or a methacrylate and an amine claim 1 , the amine being selected from the group consisting of:a synthetic primary amine selected from the group consisting of: butylamine, hexylamine, octylamine, dodecylamine, and any combination thereof;a primary fatty amine derived from one or more fatty acids selected from the group consisting of: corn oil, canola oil, coconut oil, safflower oil, sesame oil, palm oil, cottonseed oil, soybean oil, olive oil, sunflower oil, hemp oil, wheat germ oil, palm kernel oil, vegetable oil, caprylic acid, capric acid, lauric acid, stearic acid, myristic acid, myristoleic acid, palmitic acid, palmitoleic acid, sapienic acid, elaidic acid, vaccenic acid, linoleic acid, arachidic acid, arachidonic acid, eicosapentaenoic acid, erucic acid, docosahexaenoic acid, behenic acid, lignoceric acid, cerotic acid, oleic acids (cis- and trans-), and any combination thereof; andany combination thereof.4. The hydrate inhibitor composition of further comprising a solvent selected from the group consisting of: an alcohol claim 1 , methanol claim 1 , isopropyl alcohol claim 1 , glycol claim 1 , ethylene glycol claim 1 , an organic solvent claim 1 , toluene claim 1 , xylene claim 1 , monobutyl ether ...

METHOD OF INCREASING SCALE INHIBITOR RETENTION

A method for increasing the retention of a scale inhibitor within a hydrocarbon producing system is provided. The method includes, the steps of: (i) pre-flushing the system with a liquid; (ii) treating the system with a scale inhibitor; and (iii) over-flushing the system with a composition comprising an ionic polymer and a liquid carrier. The concentration of the ionic polymer in the composition is 5 to 50% wt. 122.-. (canceled)23. A method for increasing the retention of a scale inhibitor within a hydrocarbon producing system , the method comprising:(i) pre-flushing the system with a liquid;(ii) treating the system with a scale inhibitor after step (i), the scale inhibitor comprising a scale inhibitor other than a polyamino acid; and(iii) over-flushing the system with a composition comprising an ionic polymer and an aqueous carrier after step (ii), wherein the pH of the composition is 4 to 6, and the ionic polymer present in the over-flush comprises a polyamino acid.24. The method as claimed in claim 23 , wherein the pre-flushing and/or the treating step further comprises contacting the system with the ionic polymer.25. The method as claimed in claim 23 , wherein the pre-flushing step comprises contacting system with the ionic polymer.26. The method as claimed in claim 23 , wherein the treating step further comprises treating the system with the ionic polymer.27. The method as claimed in claim 23 , wherein the method further comprises treating the system with the ionic polymer after the pre-flushing step and before the treating step.28. The method as claimed in claim 23 , wherein the treating step comprises simultaneously treating the system with the ionic polymer and the scale inhibitor.29. The method as claimed in claim 23 , wherein the over-flushing step further comprises over-flushing the system with an aqueous fluid after over-flushing the system with the composition.30. The method as claimed in claim 23 , wherein the over-flushing step is the final step prior ...

COPOLYMERS COMPRISING ETHYLENE, VINYL ESTERS AND ESTERS OF (METH)ACRYLIC ACID, THEIR FORMULATIONS AND USE AS POUR POINT DEPRESSANT, WAX INHIBITOR AND FLOW ENHANCER FOR CRUDE OILS

Copolymers comprising ethylene, vinyl esters, in particular vinyl acetate and esters of (meth)acrylic acid, selected from esters comprising branched alkyl, cyclic alkyl or optionally alkyl substituted aryl moieties and having a weight average molecular weight of 35,000 g/mol to 150,000 g/mol, formulations of such copolymers in organic solvents and their use as pour point depressant, wax inhibitor and flow enhancer for crude oils. 125-. (canceled)27. The copolymer (A) according to claim 26 , wherein Ris a methyl moiety.28. The copolymer (A) according to claim 26 , wherein Rhas 5 to 11 carbon atoms claim 26 ,29. The copolymer (A) according to claim 26 , wherein Rhas 8 to 10 carbon atoms.30. The copolymer (A) according to claim 26 , wherein Rhas 6 to 10 carbon atoms.31. The copolymer (A) according to claim 26 , wherein Ris selected from the group consisting of Rand R.32. The copolymer (A) according to claim 26 , wherein Ris R.33. The copolymer (A) according to claim 26 , wherein the weight average molecular weight Mof the copolymer (A) is 50 claim 26 ,000 g/mol to 120 claim 26 ,000 g/mol.35. The composition (X) according to claim 34 , wherein the organic solvent (B) comprises a hydrocarbon or a hydrocarbon mixture.36. The composition (X) according to claim 34 , wherein the solvent (B) comprises saturated aliphatic hydrocarbons having a flashpoint ≧60° C.37. The composition (X) according to claim 34 , wherein the concentration of the copolymer (A) is 10 to 20% by weight.38. A method comprising adding a pour point depressant for crude oil comprising the copolymer (A) according to to the crude oil.39. A method comprising adding a formulation comprising at least one copolymer (A) according to and an organic solvent to crude oil.41. The method according to claim 39 , wherein the formulation used additionally comprises at least one wax dispersant.42. The method according to claim 41 , wherein the wax dispersant is at least one selected from the group consisting of ...

Chlorine dioxide precursor and methods of using same

According to one aspect of the invention, a method of converting an oxy halide salt into a halide dioxide in a reaction zone under certain conditions is provided. More specifically, the method includes generating chlorine dioxide from a stable composition comprising an oxy halide salt by introducing said composition to a reducing agent and minimum temperature within the reaction zone. According to another aspect of the invention, a composition for a stable chlorine dioxide precursor comprising an oxy halide salt is provided

ADDITIVES FOR WINTERIZATION OF PARAFFIN INHIBITORS

A winterized paraffin inhibitor, which is capable of being used for preventing the deposition of paraffins in hydrocarbon streams and capable of withstanding freezing or crystallization at freezing or sub-freezing temperatures, may be formed by adding an oxyalkylated branched aliphatic compound having 12 or more carbons to a high molecular weight aliphatic polymer paraffin inhibitor, the oxyalkylated branched aliphatic compound having 12 or more carbons being produced by the oxyalkylation of the branched aliphatic compound having 12 or more carbon atoms in which the branched aliphatic compound having 12 or more carbon atoms is grafted with a polyether via a ring-opening reaction, wherein the polyether is a polymer of ethylene oxide, propylene oxide, butylene oxide, and combinations thereof. 1. A method for winterizing a paraffin inhibitor , the method comprising:introducing an oxyalkylated linear or branched aliphatic compound having 12 or more carbon atoms into a paraffin inhibitor composed of a high molecular weight aliphatic polymer in an amount effective to therebypreventing the freezing or crystallization of the paraffin inhibitor at temperatures ranging from about 0° C. to −40° C.2. The method of claim 1 , wherein the oxyalkylated linear or branched aliphatic compound is formed by the oxyalkylation of a linear or branched aliphatic compound having 12 or more carbon atoms.3. The method of claim 2 , wherein the linear or branched aliphatic compound having 12 or more carbon atoms is a branched aliphatic compound comprising branches containing functional groups having 2 to 28 carbon atoms.4. The method of claim 3 , wherein the branched aliphatic compound having 12 or more carbon atoms comprises branches containing functional groups selected from the group consisting of alkyl groups claim 3 , arylalkyl groups claim 3 , cycloalkyl groups claim 3 , and combinations thereof.5. The method of claim 2 , wherein the linear or branched aliphatic compound having 12 or more ...

HYDROCARBON BASED CARRIER FLUID

Y-grade NGL or L-grade is used as a carrier fluid to transport one or more chemical additives into a hydrocarbon bearing reservoir to treat the hydrocarbon bearing reservoir. The Y-grade NGL or L-grade and the chemical additives may be chilled and/or foamed. 1. A method of injecting a treatment fluid into a hydrocarbon bearing reservoir , comprising:mixing an unfractionated hydrocarbon liquid mixture and a chemical additive, wherein the unfractionated hydrocarbon liquid mixture is a by-product of a de-methanized hydrocarbon stream and comprises ethane, propane, butane, isobutane, pentane, and less than one percent methane by liquid volume, wherein the unfractionated hydrocarbon liquid mixture is sourced and transported from a separate processing facility that is located at a location remote from the hydrocarbon bearing reservoir, wherein the separate processing facility comprises at least one of a splitter facility, a gas plant, and a refinery, wherein the unfractionated hydrocarbon liquid mixture is transported via pressure storage vessels from the separate processing facility to the hydrocarbon bearing reservoir;pressurizing the unfractionated hydrocarbon liquid mixture and the chemical additive with a first pump;pressurizing a liquefied gas with a second pump;vaporizing the liquefied gas with a vaporizer;mixing the pressurized, vaporized gas with the pressurized, unfractionated hydrocarbon liquid mixture and chemical additive to form a treatment fluid; andpumping the treatment fluid into the hydrocarbon bearing reservoir at a pressure greater than a formation pressure of the hydrocarbon bearing reservoir.2. The method of claim 1 , further comprising mixing water with the unfractionated hydrocarbon liquid mixture and the chemical additive claim 1 , wherein the water comprises 5-10% inhibited water by volume.3. The method of claim 1 , wherein the chemical additive comprises a surfactant claim 1 , a non-ionic surfactant claim 1 , a polymer claim 1 , an acid claim 1 ...

MULTIPLE HYDROPHILIC HEAD HYDRATE INHIBITORS

Compounds comprising multiple hydrophilic heads and a lipophilic tail may be employed into fluids to inhibit agglomeration of hydrates, among other things. Suitable hydrophilic heads may include secondary, tertiary, and/or quaternary ammonium cation moieties, phosphonium cation moieties, and combinations thereof. Such LDHI compounds may provide enhanced interactivity with hydrate crystals and/or hydrate-forming molecules. These compounds may be employed in fluids in various environments, such as a conduit penetrating a subterranean formation, or a conduit carrying fluid in an industrial setting. 2. The composition of wherein each of R claim 1 , R claim 1 , and Ris linear CHand R is a Cto Chydrocarbon chain.3. The composition of claim 1 , further comprising a solvent selected from the group consisting of: toluene claim 1 , xylene claim 1 , methanol claim 1 , isopropyl alcohol claim 1 , glycol claim 1 , and combinations thereof.4. The composition of claim 1 , wherein each of R claim 1 , R claim 1 , and Ris linear CHand R is a Cto Chydrocarbon chain.5. The composition of claim 1 , wherein Ris hydrogen claim 1 , each of Rand Ris linear CH claim 1 , and R is a Cto Chydrocarbon chain.6. The composition of claim 1 , wherein R is unsubstituted.7. The composition of claim 1 , further comprising an acid selected from the group consisting of: acrylic acid claim 1 , acetic acid claim 1 , hydrochloric acid claim 1 , citric acid claim 1 , and combinations thereof.9. The fluid of claim 8 , wherein each of R claim 8 , R claim 8 , and Ris linear CHand R is a Cto Chydrocarbon chain.10. The fluid of claim 8 , wherein R is unsubstituted.11. The fluid of claim 8 , wherein each of R claim 8 , R claim 8 , and Ris linear CHand R is a Cto Chydrocarbon chain.12. The fluid of claim 8 , wherein Ris hydrogen claim 8 , each of Rand Ris linear CH claim 8 , and R is a Cto Chydrocarbon chain.13. The fluid of claim 8 , wherein the fluid has a water cut of 50% or more.14. The fluid of claim 8 , ...

Enzyme-Encapsulated Hydrogel Nanoparticles for Hydraulic Fracturing Fluid Cleanup

Provided herein is a hydraulic fracturing fluid containing enzyme encapsulated hydrogel nanoparticles and a breaker composition of a viscosifier-degrading enzyme encapsulated in the hydrogel nanoparticle. Also provided are methods for hydraulic fracturing utilizing hydrogel nanoparticles encapsulating an enzyme as a breaker to prevent the premature degradation of the fracturing fluid, to improve transport and placement of the proppant and to facilitate subsequent cleaning of the fracturing fluid.

COMPOSITIONS TO STABILIZE ASPHALTENES IN PETROLEUM FLUIDS

Compositions may include those of the formula: (I) wherein R1 is an alkyl chain having a carbon number in the range of greater than 40 to 200, R2 is a multiester, R3 is hydrogen, an ion, or an alkyl chain having a carbon number in the range of 1 to 200, m is an integer selected from 0 to 4, and n is an integer selected from the range of 0 to 4, wherein the sum of m and n is 1 or greater. Compositions may include a reaction product of a polyisobutylene-substituted succinic anhydride and a hydroxy-functional dendrimer, wherein the molar ratio of polyisobutylene-substituted succinic anhydride to hydroxy-functional dendrimer is within the range of 10:1 to 30:1. 1. A composition comprising a reaction product of a polyisobutylene-substituted succinic anhydride and a hydroxy-functional dendrimer , wherein the molar ratio of polyisobutylene-substituted succinic anhydride to hydroxy-functional dendrimer is within the range of 10:1 to 30:1.3. The composition of claim 2 , wherein R1 is an alkyl chain having a carbon number in the range of 50 to 100 claim 2 , X is —OM claim 2 , and m+n=1.4. The composition of claim 3 , wherein R1 is an alkyl chain having a carbon number in the range of 60 to 75.5. The composition of claim 2 , wherein the multiester group is a dendrimeric multiester comprising 8 to 50 ester groups.6. The composition of claim 2 , wherein the compound has a weight average molecular weight in the range of 900 to 100 claim 2 ,000 Da.7. The composition of wherein the compound has a weight average molecular weight in the range of 10 claim 2 ,000 to 50 claim 2 ,000 Da.8. The composition of claim 2 , wherein R1 is an alkyl chain generated from the reaction of one or more monomers selected from a group consisting of ethylene claim 2 , propene claim 2 , butylene claim 2 , and isobutylene.9. The composition of claim 2 , wherein the multiester group is a dendrimeric multiester comprising a polyalcohol core and one or more generations of 2 claim 2 ,2-dimethylolpropionic acid ...

Contraction and confinement of oil slicks on water, including water where ice is present, using non-ionic surfactants

Methods for reducing the size of an oil slick on a water surface or on a water surface when ice is present are described. Spreading of oil can be reversed by reducing the surface tension of the seawater, for example, by using a low concentration of at least one water-soluble surfactant, such as a non-ionic surfactant. A controlled amount of the surfactant or surfactant mixture may be discharged over time at the inner-wall of a spill control boom surrounding the oil spill, or within the vicinity of the oil spill in the absence of control booms using a soaker hose or a floating polyethylene or polypropylene hose impregnated with surfactant, whereby the confinement and contraction of the oil slick is maintained by compensating for dissolved surfactant and surfactant moving away from the oil slick. Water-soluble surfactants are typically solids or gels at low temperatures when no organic co-solvent is added to the surfactant. The solid or gel form is advantageous for generating slow, but continuous release of surfactant, and thus there is no need for an organic co-solvent. This is not the situation for oil-soluble surfactants, which require an organic co-solvent to be successfully applied at low temperatures. Mixing oil-soluble surfactants with water-soluble surfactants may overcome the problem of dispersing oil-soluble surfactant without an organic co-solvent at low temperatures.

Fluids For Fracking Of Paraffinic Oil Bearing Formations

This invention provides a fracturing fluid comprising 1. A fracturing fluid comprisingi) 85 wt.-% or more of an aqueous carrier fluid as continuous phase, [{'sub': 3', '30, 'a) copolymers of ethylene and ethylenically unsaturated esters, ethers and/or Cto C-alkenes, which contain 4 to 18 mol-% of at least one vinyl ester, acrylic ester, methacrylic ester, alkyl vinyl ether and/or alkene,'}, {'sub': 12', '50, 'b) homo- or copolymers of ethylenically unsaturated carboxylic acids, bearing C-C-alkyl radicals bound via ester, amide and/or imide groups,'}, 'c) ethylene copolymers grafted with ethylenically unsaturated esters and/or ethers,', {'sub': 3', '30, 'd) homo- and copolymers of Cto C-olefins, and'}, 'e) condensation products of alkyl phenols with aldehydes and/or ketones, 'ii) 0.001 to 1.5 wt.-% of a first wax inhibitor being dispersed in the carrier fluid, the wax inhibitor being selected from the group consisting of'}iv) optionally a water soluble polymer for viscosity adjustment, wherein the amount of water-immiscible hydrocarbons is less than 2.5 wt.-%.2. The fracturing fluid as claimed in claim 1 , further comprising iii) a water insoluble solid proppant.3. The fracturing fluid as claimed in claim 2 , wherein the water insoluble proppant comprises an immobilized second wax inhibitor.4. The fracturing fluid as claimed in claim 1 , in which the first and/or second wax inhibitor comprises a copolymer of ethylene and at least one ethylenically unsaturated ester claim 1 , ethylenically unsaturated ether or an alkene.5. The fracturing fluid as claimed in claim 4 , in which the ethylenically unsaturated ester is a vinyl ester.6. The fracturing fluid as claimed in claim 1 , in which the first and/or second wax inhibitor comprises a homo- or copolymer of at least one ester of at least one ethylenically unsaturated carboxylic acid claim 1 , said ester bearing C-C-alkyl radicals.7. The fracturing fluid as claimed in claim 6 , in which the ethylenically unsaturated ...

ALKYL LACTONE-DERIVED HYDROXYAMIDES AND ALKYL LACTONE-DERIVED HYDROXYESTERS FOR THE CONTROL OF NATURAL GAS HYDRATES

Disclosed are alkyl lactone-derived hydroxyamides and alkyl lactone-derived hydroxyesters used in compositions and methods for inhibiting natural gas hydrate agglomerates. The alkyl lactone-derived hydroxyamides and alkyl lactone-derived hydroxyesters 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 formation of natural gas hydrate agglomerates , 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 1-30 carbon atom-containing alkyl substituent.3. The composition of claim 1 , wherein the alkyl lactone is a decalactone claim 1 , or tetradecalactone.5. The composition of claim 1 , wherein the composition further comprises one or more thermodynamic gas hydrate inhibitors claim 1 , kinetic gas hydrate inhibitors claim 1 , anti-agglomerants claim 1 , 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.6. 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.7Daphnia magna. The composition of claim 1 , wherein the alkyl lactone-derived hydroxyamide or alkyl lactone-derived hydroxyester comprises a 48-hour ECvalue with greater than or equal to 10 mg/ml.8. The composition of claim 1 , wherein the alkyl lactone-derived hydroxyamide or alkyl lactone-derived hydroxyester has an increased biodegradation compared ...

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 ...

Polymer dispersions for wax inhibition during stimulation treatment

The present invention relates to a method of inhibiting or control wax formation during stimulation treatment of a well. More specifically, the present invention proposes the use of aqueous polymer dispersions suitable as wax inhibitor compositions which are compatible with aqueous fracturing fluids.

MALEIC ANHYDRIDE COPOLYMER WITH BROADLY DISPERSED ESTER SIDE CHAIN AS WAX INHIBITOR AND WAX CRYSTALLIZATION ENHANCER

A wax inhibitor composition, the composition having at least one alpha-olefin maleic anhydride copolymer of the formula: 2. The wax inhibitor composition as recited in claim 1 , wherein the at least one alpha olefin maleic anhydride copolymer is prepared by reacting an alpha-olefin containing greater than 10 carbon atoms with maleic anhydride in the presence of a free radical initiator to obtain a high molecular weight copolymer claim 1 , followed by reacting the high molecular weight copolymer with an alcohol mixture having a dispersed chain length ranging from 10 to 80 carbon atoms.3. The wax inhibitor composition as recited in claim 2 , wherein the alpha-olefin comprises a range of about 10-30 carbon atoms.4. (canceled)5. The wax inhibitor composition as recited in claim 2 , wherein the alpha-olefin is 1-octadecene claim 2 , 1-eicosene claim 2 , 1-docosene claim 2 , 1-tetracosene claim 2 , 1-hexacosene claim 2 , 1-octacosene claim 2 , 1-hexadecene claim 2 , 1-tetradecane claim 2 , or 1-dodecene.6. The wax inhibitor composition as recited in claim 2 , wherein the alcohol mixture contains more than 25% by weight of alcohols in the alcohol mixture contain greater than 35 carbon atoms.7. The wax inhibitor composition as recited in claim 2 , wherein the alcohol mixture has a dispersed chain length ranging from (i) C10-C60 claim 2 , (ii) C20-C70 claim 2 , or (iii) C30-C80.89-. (canceled)10. The wax inhibitor composition as recited in claim 2 , wherein the alcohol mixture comprises a linear aliphatic alcohol containing more than 25% by weight of alcohols in the alcohol mixture contain greater than 35 carbon atoms.12. The comb polymer composition as recited in claim 11 , wherein the at least one alpha olefin maleic anhydride copolymer is prepared by reacting an alpha-olefin or alpha-olefin mixture with a chain length of greater than 24 carbon atoms with a dicarboxylic acid to obtain a copolymer claim 11 , followed by reacting the copolymer with an alcohol mixture in the ...

MITIGATION OF CONDENSATE BANKING USING SURFACE MODIFICATION

The present application relates to methods and systems for mitigating condensate banking. In some embodiments, the methods and systems involve altering the wettability of a rock formation in the vicinity of a wellbore for a gas condensate reservoir. 125-. (canceled)26. A system for mitigating condensate banking in the vicinity of a wellbore for a gas condensate reservoir , the system comprising:a first container or source of a polymer solution that comprises a charged polymer with a first net charge;a second container or source of a particle suspension that comprises charged particles with a second net charge, wherein the first and second net charges are opposed; andconduits for introducing the polymer solution and the particle suspension into a rock formation in the vicinity of a wellbore for a gas condensate reservoir.27. The system of claim 26 , wherein the charged polymer is positively charged in the polymer solution and the charged particles are negatively charged in the particle suspension.28. The system of claim 26 , wherein the charged polymer comprises a plurality of amine groups.29. The system of claim 26 , wherein the charged polymer comprises a plurality of quaternary ammonium groups.30. The system of claim 26 , wherein the charged polymer is a quaternizable polymer prepared by polymerization of vinylimidazole with a vinyl or acrylic claim 26 , or both monomer.31. The system of claim 26 , wherein the charged polymer is a polyquaternium.32. The system of claim 26 , wherein the charged polymer is a polyethylenimine.33. The system of claim 32 , wherein the charged polymer is a functionalized derivative of polyethylenimine.34. The system of claim 26 , wherein the polymer solution has a pH in the range of about 5 to about 10.35. The system of claim 26 , wherein the charged polymer has a number average molecular weight in the range of about 120 to about 800 claim 26 ,000 grams per mole.36. The system of claim 26 , wherein the charged polymer is present in the ...

OXIDIZING GASSES FOR CARBON DIOXIDE-BASED FRACTURING FLUIDS

Unconventional hydrocarbon source rock reservoirs can contain the organic material kerogen, intertwined with the rock matrix. The kerogen can alter the tensile strength of the rock and contribute to higher fracture energy needs. To degrade kerogen and other organic materials, oxidizing gasses are dissolved in carbon dioxide (CO) which is then used as part of a fracturing fluid. The oxidizing gasses can be dissolved directly in the COor generated in situ using precursors. 1. A method for treating kerogen in a subterranean zone , the method comprising: carbon dioxide, and', 'an oxidizing gas, and, 'placing a composition in the subterranean zone, the composition comprising'}treating the kerogen in the subterranean zone with the composition.2. The method of claim 1 , wherein placing the composition comprises flowing the composition to a location in the subterranean zone.3. The method of claim 1 , wherein the oxidizing gas comprises at least one of chlorine dioxide (ClO) claim 1 , chlorine gas (Cl) claim 1 , bromine gas (Br) claim 1 , fluorine gas (F) claim 1 , chlorine monoflouride (ClF) claim 1 , oxygen gas (O) claim 1 , ozone (O) claim 1 , nitrous oxide (NO) claim 1 , nitric oxide (NO) claim 1 , nitrogen dioxide (NO) claim 1 , or mixtures thereof.4. The method of claim 1 , further comprising supplying the oxidizing gas by an oxidizing gas stream.5. The method of claim 1 , further comprising generating the oxidizing gas in situ.6. The method of claim 5 , wherein generating the oxidizing gas in situ comprises:providing precursors comprising a first precursor compound and a second precursor compound;injecting the first precursor compound into the composition;pumping a spacer amount of carbon dioxide into the composition; andinjecting the second precursor compound into the composition,wherein the first and second precursor compounds react to generate the oxidizing gas.7. The method of claim 6 , wherein the precursors comprise a chlorite and an oxidizing agent.8. The ...

In situ microemulsions used as spacer fluids

Nanoemulsions, miniemulsions, microemulsion systems with excess oil or water or both (Winsor III) or single phase microemulsions (Winsor IV) may be formed in situ during hydrocarbon recovery operations after drilling with OBM or SBM using one or more fluid pills. The nanoemulsions, miniemulsions, microemulsion systems with excess oil or water or both or single phase microemulsions remove oil and solids from the well and wellbore surfaces. In one non-limiting embodiment, a single phase microemulsion (SPME) or other in situ-formed fluid may be created from a polar phase, a nonpolar phase, at least one viscosifier, and at least one surfactant.

CLEANING AND REMOVAL OF WAX DEPOSITS IN OIL AND GAS WELLS USING CATIONIC POLYMERS

The present invention generally relates to methods for removing deposits in an oil or gas well by contacting the annular fluid in a batch-wise method with an effective amount of a composition comprising a water-soluble copolymer. These methods are advantageous because they can be used as needed to improve well operation. The methods use a water-soluble copolymer comprised of an acrylamide monomer and one or more cationic monomer. 1. A method for removing a deposit in an oil or gas well , the method comprising contacting the annular fluid batch-wise with an effective amount of a composition comprising a water-soluble copolymer , wherein the produced fluid comprises at least about 10 vol % water.2. The method of wherein the water-soluble copolymer is comprised of an acrylamide monomer and a cationic monomer.3. The method of wherein the cationic monomer is a dimethylaminoethyl acrylate benzyl chloride quaternary salt claim 2 , a dimethylaminoethyl acrylate methyl chloride quaternary salt claim 2 , a dialkyldimethyl ammonium salt claim 2 , a methacrylamido propyltrimethyl ammonium salt claim 2 , a 3-(acryloylamino)propyl trimethyl ammonium salt claim 2 , a 2-acryloyloxyethyltrimethyl ammonium salt claim 2 , a 2-methacryloyloxyethyltrimethyl ammonium salt claim 2 , a acryloyloxyethyldimethylbenzyl ammonium salt claim 2 , a methacryloyloxyethyldimethylbenzyl ammonium salt claim 2 , or a combination thereof.4. The method of wherein the acrylamide monomer is acrylamide.5. The method of wherein the cationic monomer comprises dimethylaminoethyl acrylate benzyl chloride quaternary chloride and dimethylaminoethyl acrylate methyl chloride quaternary chloride.6. The method of wherein the water-soluble copolymer has a molar ratio is from about 1:2:1.3 to about 1:3:2 of acrylamide to dimethylaminoethyl acrylate benzyl chloride quaternary salt to dimethylaminoethyl acrylate methyl chloride quaternary salt.7. The method of wherein the water-soluble copolymer has a molar ratio of ...

Methods and systems for infusing porous ceramic proppant with a chemical treatment agent

Methods and systems for infusing ceramic proppant and infused ceramic proppant obtained therefrom are provided. The method can include introducing ceramic proppant and a chemical treatment agent to a mixing vessel, mixing the ceramic proppant and the chemical treatment agent in the mixing vessel to provide a mixture, introducing microwave energy to the mixing vessel to heat the mixture to a temperature sufficient to produce infused ceramic proppant containing at least a portion of the chemical treatment agent, and withdrawing the infused ceramic proppant from the mixing vessel.

Olefinic Ester Compositions and Their Use in Stimulating Hydrocarbon Production from a Subterranean Formation

Compositions for stimulating hydrocarbon production from a subterranean formation are generally disclosed. In some embodiments, such compositions include olefinic ester compounds, such as alkyl esters of C10-18 unsaturated fatty acids. In some embodiments, the olefinic ester compounds are derived from a natural oil or a natural oil derivative, for example, by catalytic olefin metathesis. Uses of such compounds, such as in oil- and gas-production methods are also generally disclosed. 145-. (canceled)46. A method of stimulating an oil or gas well , comprising:{'sub': 1-6', '3-10', '10-16, 'providing a composition, wherein the composition comprises olefinic ester compounds, which are Calkanol esters or Ccycloalkanol esters of Ccarboxylic acids having one or more carbon-carbon double bonds; and'}introducing the composition into an oil or gas well.47. The method of claim 46 , wherein the oil or gas well is a gas well for shale gas or tight gas.48. the method of claim 46 , wherein the introducing comprises injecting the composition into the oil or gas well under pressure.49. The method of claim 46 , wherein the composition further comprises water.50. The method of claim 49 , wherein the composition is an emulsion claim 49 , which comprises a dispersed phase and a continuous phase.51. The method of claim 50 , wherein the emulsion is an oil-in-water emulsion claim 50 , and wherein the dispersed phase comprises the olefinic ester compounds and the continuous phase comprises water.52. The method of claim 50 , further comprising a surfactant.53. The method of claim 50 , wherein the emulsion is a water-in-oil emulsion claim 50 , and wherein the dispersed phase comprises water and the continuous phase comprises the olefinic ester compounds.54. The method of claim 46 , wherein the composition further comprises a terpene.55. The method of claim 54 , wherein the terpene is selected from the group consisting of linacool claim 54 , geraniol claim 54 , nopol claim 54 , α-terpineol ...

METHOD, PROCESS, APPARATUS AND CHEMICALS TO PRODUCE AND INJECT PARAFFIN TREATING COMPOUNDS

The present invention is a device and a method that combines a carbon disulfide-releasing chemical with a low pH organic or inorganic acid to produce a carbon disulfide-containing fluid at or near the point of injection that minimizes or eliminates the possible exposure of carbon disulfide to workers and the environment. In one particular embodiment a positive displacement injection pump injects the carbon disulfide-containing fluid into a crude oil system for treating crude oil transmission lines and in downhole tubulars to remove paraffin deposits. The device uses a unique in-line motion mixer to mix two fluids. The device is electronically controlled locally and remotely with the system operating data displayed locally and transmitted remotely. The paraffin treating carbon disulfide-containing fluid and supplemental chemicals dissolve, disperse and remove paraffin deposits. 1. A system for in-line mixing and injection of paraffin treatment solutions comprising:a first feed tank containing a precursor salt and selectively in communication with a first conduit;a first positive displacement pump in line with the first conduit;a second feed tank containing an acid and selectively in communication with a second conduit;a second positive displacement pump in line with the second conduit;an in-line motion mixer selectively in communication with the first conduit and second conduit, wherein the in-line motion mixer combines the precursor salt and the acid to form a carbon disulfide solution and release it into an exit conduit; andan injection manifold which receives the carbon disulfide solution from the exit conduit and releases it into a flowline.2. The system of claim 1 , wherein the precursor salt comprises a thiocarbonate claim 1 , thiocarbamate claim 1 , dithiocarbonate claim 1 , dithiocarbamate claim 1 , trithiocarbonate claim 1 , trithiocarbamate claim 1 , or combinations thereof.3. The system of claim 1 , wherein the acid has a pH below 3.5 and comprises a ...

OIL SOLUBLE MOLYBDENUM COMPLEXES AS HIGH TEMPERATURE FOULING INHIBITORS

Disclosed are molybdenum-containing complexes used in compositions and methods for inhibiting or reducing the deposition of foulant on equipment. 2. The method of claim 1 , wherein the foulant comprises coke claim 1 , sludge claim 1 , corrosion products claim 1 , polymers claim 1 , and catalyst fines.3. The method of claim 1 , wherein the fluid comprises at least a liquid hydrocarbon material.4. The method of claim 1 , wherein the molybdenum-containing complex is added to the fluid from 1 ppm to 3000 ppm of the fluid volume.5. The method of claim 1 , wherein the at least one molybdenum-containing complex comprises a molybdenum dithiocarbamate claim 1 , dithiophosphate claim 1 , polymers thereof and combinations thereof.6. The method of claim 5 , wherein the molybdenum dithiocarbamate comprises an alkyldithiocarbamate.7. The method of claim 6 , wherein the alkyldithiocarbamate comprises an ethyl hexyl dithiocarbamate claim 6 , straight chain C6-C10 alcohols or mixtures thereof.8. The method of claim 5 , wherein the molybdenum dithiophosphate comprises an alkyldithiophosphate.9. The method of claim 8 , wherein the alkyldithiophosphate comprises an ethyl hexyl claim 8 , straight chain C6-C10 alcohols or mixtures thereof.10. The method of claim 1 ,wherein the molybdenum-containing complex provides at least 70% inhibition of foulant deposition.1224. The composition of claim claim 1 , wherein the composition further comprises one or more claim 1 , 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.13. The composition of claim 11 , wherein the R claim 11 , R claim 11 , R claim 11 , and Rof formulae I and II comprise thiophosphates claim 11 , phosphates and polymers thereof.14. The composition of claim 11 , wherein the Yand Yof formulae III and IV comprise thiocarbamates and polymers thereof.15. The composition ...

A Chemical Treatment Solution for Formation Damage at Near Wellbore

An emulsion composition of treating near-wellbore obstruction comprising an aqueous phase in 0.5 to 40% by weight of total composition; an non-aqueous phase in 15 to 90% by weight of total composition; a surfactant un 2 to 60% by weight of total composition; and a compound having a Chemical structure I in 1 to 30% by weight of total composition 110.-. (canceled)11. A microemulsion composition for treating formation damage at near-wellbore , comprising:an aqueous phase present in a range of 0.5 to 40% by weight of total composition;a non-aqueous phase present in a range of 15 to 90% by weight of total composition;a surfactant present in a range of 2 to 60% by weight of total composition;a pour point depressant present in a range of 5 to 40% by weight of total composition; and {'br': None, 'sub': 1', '2', '3', 'n', '4, 'R—CONH—[R—NH—R]—HNOC—R\u2003\u2003(Chemical structure I)'}, 'a compound having a chemical structure I and present in a range of 1 to 30% by weight of total composition'}{'sub': 1', '2', '3', '4, 'in which R, R, Rand Rare linear, branched or aromatic carbon-containing substituents having 2 to 26 carbon atoms and n is an integer in a range of 1 to 100, wherein each of the substituents comprises an alkyl group, a carbonyl group, a carboxylic group, an amine group, or an amide group.'}12. The composition according to claim 11 , further comprising a co-surfactant claim 11 , present in a range of 1 to 30% by weight of the total composition claim 11 , and selected from the group consisting of C3 to C18 alcohols claim 11 , C3 to C18 alkyl lactates claim 11 , lecithin claim 11 , C3 to C18 fatty acids claim 11 , alkane diols claim 11 , amino acids claim 11 , and combinations thereof.13. The composition according to claim 11 , wherein the non-aqueous phase is selected from the group consisting of terpenes claim 11 , aromatic hydrocarbons claim 11 , glycols claim 11 , esters claim 11 , fatty acid ester claim 11 , fatty ester claim 11 , glycol ethers claim 11 , ...

IONIC LIQUIDS AND METHODS OF USING SAME

Ionic liquid containing compositions may be used in the production, recovery and refining of oil and gas. In addition, they may be used to treat wastewater and/or to inhibit and/or prevent fouling of contaminants onto surfaces. 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)21. (canceled)22. (canceled)23. (canceled)24. (canceled)25. (canceled)26. (canceled)27. (canceled)28. (canceled)29. (canceled)30. (canceled)33. The method of claim 32 , wherein R claim 32 , R claim 32 , R claim 32 , R claim 32 , R claim 32 , Rand Rare independently —H or a Calkyl and/or the anion is a halide selected from the group consisting of —Cl claim 32 , —Br claim 32 , —F or —I.35. A method of treating a hydrocarbon containing fluid to:(a) inhibit or prevent the formation or precipitation of asphaltenes in the fluid; or [{'br': None, 'sup': 1', '2', '3', '4', '+', '−, 'RRRRNX\u2003\u2003(IV); or'}, {'br': None, 'sup': 1', '2', '3', '+', '8', '+', '5', '6', '7', '−, 'RRRNRNRRRX\u2003\u2003(V)'}], '(b) remove or reduce sulfur containing compounds in the fluid, the method comprising contacting the fluid with an ionic liquid of the formula{'sup': 1', '2', '3', '4', '5', '6', '7', '8, 'X is an anion selected from the group consisting of halides; hydroxyl; carbonates; alkyl carbonates; bicarbonates; carboxylates; hydroxycarboxylates; sulfonates; sulfates; bisulfites; thiocyanates; dithiocarbonates; dithiocarbonates; trithiocarbonates; carbamates; dithiocarbamates; trithiocarbamates; xanthates; sulfides; polysulfides; alkoxides; anionic ureas; anionic alkyl substituted phosphines; anionic amino fatty acids; anionic alkoxylated fatty acids; anionic acrylamido-methyl propane sulfonate/acrylic acid copolymers; anionic phosphated maleic copolymers; anionic metal complexes; sulfur ...

Asphaltene Inhibition

The technology disclosed herein provides compositions and methods for asphaltene control in a hydrocarbon fluid, such as crude oil, by employing a quaternary ammonium salt. 1. A method of asphaltene control in a hydrocarbon fluid , comprising employing a quaternary ammonium salt comprising the reaction product of:a. the reaction product of a hydrocarbyl substituted acylating agent and a compound having an oxygen or nitrogen atom capable of condensing with said hydrocarbyl substituted acylating agent and further having a tertiary amino group; andb. a quaternizing agent suitable for converting the tertiary amino group to a quaternary nitrogen.2. The method of claim 1 , wherein the quaternizing agent is selected from the group consisting of dialkyl sulfates; alkyl halides; benzyl halides; haloacetic acids/salts; hydrocarbyl substituted carbonates; hydrocarbyl substituted oxalate esters; hydrocarbyl epoxides optionally in combination with an acid; and mixtures thereof.3. The method of any previous claim claim 1 , wherein the hydrocarbyl substituted acylating agent is a polyisobutylene succinic acid or anhydride.4. The method of claim 3 , wherein the polyisobutylene of the polyisobutylene succinic acid or anhydride has a number average molecular weight of from between about 150 to about 5000.5. The method of any of or claim 3 , wherein the hydrocarbyl substituted acylating agent is a polyhydroxy carboxylic acid.6. The method of claim 5 , wherein the polyhydroxy carboxylic acid is polyhydroxy stearic acid.7. The method of any previous claim wherein the compound having an oxygen or nitrogen atom capable of condensing with said hydrocarbyl substituted acylating agent and further having a tertiary amino group is N claim 5 ,N-dimethyl-1 claim 5 ,3-diaminopropane.8. The method of any previous claim claim 5 , wherein the hydrocarbon fluid has an asphaltene content of at least 0.01 wt %.9. The method of any previous claim claim 5 , wherein the hydrocarbon fluid has an asphaltene ...

METHODS OF EXTRACTING HYDROCARBONS FROM SUBTERRANEAN FORMATIONS

A method of extracting hydrocarbons from a subterranean formation comprises introducing a solution comprising a silicon-containing compound into the subterranean formation. The silicon-containing compound may comprise a terminal group comprising one of an alkanoate group, a fluoroalkanoate group, and a perfluoroalkanoate group, and one or more of an alkoxy group and a chlorine atom bonded to a silicon atom. The method comprises attaching the silicon-containing compound to one or more of formation surfaces of the subterranean formation to form an oleophilic surface on the one or more of the formation surfaces and the surfaces of proppant particles. 2. The method of claim 1 , further comprising selecting the fluorinated alkyl group to comprise a branched fluorinated alkyl group.3. The method of claim 1 , wherein at least one of the R′ groups comprises a chlorine atom.4. The method of claim 1 , further comprising selecting the fluorinated alkyl group to comprise a perfluoroalkyl group.5. The method of claim 1 , wherein introducing into a subterranean formation a solution comprises introducing a solution comprising a silicon-containing compound wherein at least one of the R′ groups comprises an alkyl group.7. The method of claim 1 , further comprising reacting the silicon-containing compound with exposed hydroxyl groups on formation surfaces of the subterranean formation to form an oleophilic surface comprising exposed R′″ groups on the formation surfaces.9. A method of extracting a hydrocarbon from a subterranean formation claim 1 , the method comprising:forming an oleophilic surface on one or more of formation surfaces of a subterranean formation and surfaces of proppant particles within the subterranean formation;removing hydrocarbons from the subterranean formation while the oleophilic surface is on one or more of the formation surfaces and the surfaces of the proppant particles;hydrolyzing the oleophilic surface and forming a hydrophilic surface on one or more of ...

TREATMENT OF PRODUCED HYDROCARBONS

A method for managing metal naphthenates in produced hydrocarbons includes injecting acid and/or sour gas into produced hydrocarbons in a production well, flowline or riser, to thereby control the pH of fluids contained in the produced hydrocarbons.

Method of Removing Non-Aqueous Drilling Mud with Banana Containing Fluid

Non-aqueous drilling fluids may be removed from a wellbore or tubing nor casing within the wellbore by introducing into the well a biodegradable aqueous fluid comprising banana. 1. A method of cleaning a wellbore or tubing or casing in a wellbore containing residues and/or deposits of an oil or synthetic based drilling mud , the method comprising introducing into the wellbore , tubing or casing an aqueous cleaning fluid containing banana and removing from the wellbore , tubing or casing the cleaning fluid having at least a portion of the residues or deposits of the oil or synthetic based drilling mud entrained therein.2. The method of claim 1 , further comprising introducing into the wellbore claim 1 , tubing or casing a cementitious slurry and displacing at least a portion of the drilling mud claim 1 , drilling mud deposits or drilling mud residues with the aqueous fluid.3. The method of wherein at least a portion of the drilling mud claim 1 , drilling mud deposits or drilling mud residues are displaced out of the well with the aqueous fluid.4. The method of claim 3 , wherein all of the drilling mud claim 3 , drilling mud deposits or drilling mud residues are displaced out of the well with the aqueous fluid.5. The method of claim 1 , wherein the aqueous fluid further comprises a weighting agent.6. The method of claim 1 , wherein the density of the aqueous fluid is from about 8 to about 24 lb/gal.7. The method of claim 1 , further comprising diluting a concentrate of a fluid containing banana to render the aqueous cleaning fluid and then introducing the aqueous cleaning fluid into the wellbore claim 1 , tubing or casing.8. The method of claim 7 , wherein the concentrate is diluted on the fly.9. The method of claim 1 , wherein the weight ratio of banana:water in the aqueous cleaning fluid is from about 1:10 to about 10:1.10. The method of claim 9 , wherein the weight ratio of banana:water in the aqueous cleaning fluid is from about 1:5 to about 5:1.11. The method of ...

Methods to assess monitor and control bacterial biofilms

The present disclosure describes methods for detecting, monitoring, and modulating (e.g., promoting, enhancing, sustaining, maintaining, reducing, mitigating or eliminating of) biofilm formation, as well as mitigating or eliminating Microbial Influenced Corrosion (MIC) of a metal surface. The method of monitoring includes: providing a test sample; detecting at least one of a prophage gene, a prophage gene expression, a prophage gene transcript, a prophage protein, a prophage metabolite, a prophage intermediate, or a combination thereof, wherein the existence, amount or level of prophage gene expression, a prophage gene transcript, a prophage protein, a prophage metabolite, a prophage intermediate, or a combination thereof relative to a control is indicative of biofilm presence, formation or the state of the biofilm in a sample. The present disclosure also describes a composition for modulating biofilm formation, maintenance, mitigation, reduction, and elimination.

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 ...

INFUSED AND COATED PROPPANT CONTAINING CHEMICAL TREATMENT AGENTS AND METHODS OF USING SAME

Proppant compositions and methods for using same are disclosed herein. In particular, a proppant composition for use in hydraulic fracturing is disclosed herein. The proppant composition can contain a plurality of particulates and at least one particulate of the plurality of particulates containing a chemical treatment agent. The at least one particulate having a long term permeability measured in accordance with ISO 13503-5 at 7,500 psi of at least about 10 D. The at least one chemical treatment agent can separate from the at least one particulate when located inside a fracture of a subterranean formation after a period of time. 1. A proppant composition , the composition comprising:a proppant particulate;a non-degradable coating disposed onto the proppant particulate;a degradable shell encapsulating at least a portion of the non-degradable coating; anda chemical treatment agent, wherein a first portion of the chemical treatment agent is blended with the non-degradable coating; andwherein the chemical treatment agent is configured to separate from the proppant particulate upon degradation of the degradable shell.2. The composition of claim 1 , wherein the proppant particulate has an internal interconnected porosity of about 5% to about 75%.3. The composition of claim 1 , wherein the chemical treatment agent comprises a scale inhibitor claim 1 , a salt inhibitor claim 1 , a hydrogen sulfide scavenger claim 1 , an iron sulfide scavenger claim 1 , or any combination thereof.4. The composition of claim 3 , wherein the scale inhibitor comprises diethylenetriamine penta(methylene phosphonic acid) or one or more potassium salts of maleic acid copolymers.5. The composition of claim 3 , wherein the salt inhibitor comprises potassium ferricyanide.6. The composition of claim 1 , wherein the non-degradable coating is a phenolic novolac resin.7. The composition of claim 1 , wherein a second portion of the chemical treatment agent is blended with the degradable shell.8. The ...

COMPOSITIONS COMPRISING NON-HALOGENATED SOLVENTS FOR USE IN OIL AND/OR GAS WELLS AND RELATED METHODS

Compositions comprising non-halogenated solvents for use in various aspects of a life cycle of an oil and/or gas well, and related methods, are provided. In some embodiments, the composition comprises a solvent blend and one or more surfactants. In some embodiments, the solvent blend comprises a first type of solvent (e.g., a terpene) and a second type of solvent (e.g., a non-halogenated solvent). The composition may comprise about 90 wt % to 99.9 wt % of the solvent blend, and about 0.1 wt % to 10 wt % of one or more surfactants, versus the total weight of the composition. In some embodiments, compositions can be used in methods for treating an oil and/or gas well, having a wellbore that comprises one or more fluids. A composition may be delivered into the wellbore, passing through the one or more fluids to reduce residues comprising asphaltenes, paraffins or combinations thereof on or near the wellbore. 1. A composition for treating an oil and/or gas well having a wellbore , comprising: a terpene and', 'a non-halogenated solvent; and, 'from about 90 wt % to about 99.9 wt % of a solvent blend versus the total weight of the composition, wherein the solvent blend comprisesfrom about 0.1 wt % to about 10 wt % of one or more surfactants versus the total weight of the composition.2. The composition of claim 1 , wherein the terpene is selected from the group consisting of d-limonene claim 1 , dipentene claim 1 , alpha terpineol claim 1 , alpha pinene claim 1 , beta pinene claim 1 , and eucalyptol claim 1 , or combinations thereof.3. The composition of claim 1 , wherein the non-halogenated solvent comprises a non-halogenated aromatic ester solvent.4. The composition of claim 3 , wherein the non-halogenated aromatic ester solvent is selected from the group consisting of esters of salicylates claim 3 , benzoates claim 3 , cinnamates claim 3 , and phthalates claim 3 , or combinations thereof.5. The composition of claim 1 , wherein the solvent blend further comprises an alkyl ...

COMPOSITIONS COMPRISING AROMATIC ESTER SOLVENTS FOR USE IN OIL AND/OR GAS WELLS AND RELATED METHODS

Compositions comprising aromatic ester solvents for use in various aspects of a life cycle of an oil and/or gas well, and related methods, are provided. In some embodiments, the composition includes an emulsion or microemulsion wherein the emulsion or microemulsion comprises an aqueous phase, a surfactant, and a non-aqueous phase. In some embodiments, the non-aqueous phase comprises a solvent blend including a first type of solvent and a second type of solvent, e.g., having a respective weight ratio of about 3:2 to 1:4. In some embodiments, the first type of solvent is a terpene and/or the second type of solvent is an aromatic ester solvent. In some embodiments, compositions are used in methods for treating an oil and/or gas well having a wellbore. In some embodiments, the composition is delivered into the wellbore, reducing residues comprising kerogens, asphaltenes, paraffins, organic scale, or combinations thereof on or near the wellbore. 1. A composition for treating an oil and/or gas well having a wellbore , comprising: an aqueous phase;', 'a surfactant; and', 'a solvent blend, comprising a first type of solvent and a second type of solvent, having a weight ratio from about 3:2 to about 1:4,', 'wherein the first type of solvent is a terpene and the second type of solvent is an aromatic ester solvent., 'a microemulsion, wherein the microemulsion comprises'}2. The composition of claim 1 , wherein the terpene is selected from the group consisting of d-limonene claim 1 , dipentene claim 1 , alpha terpineol claim 1 , alpha pinene claim 1 , beta pinene claim 1 , and eucalyptol claim 1 , or combinations thereof.3. The composition of claim 1 , wherein the aromatic ester solvent is selected from the group consisting of esters of salicylates claim 1 , benzoates claim 1 , cinnamates claim 1 , and phthalates claim 1 , or combinations thereof.4. The composition of claim 1 , wherein the solvent blend further comprises butyl 3-hydroxybutanoate.5. The composition of claim 1 , ...

Compositions comprising aromatic compounds for use in oil and/or gas wells and related methods

Compositions comprising aromatic compounds for use in various aspects of a life cycle of an oil and/or gas well, and related methods, are generally provided. In some embodiments, the composition is an emulsion or a microemulsion comprising a cashew nut shell liquid, a derivatized cashew nut shell liquid, an aromatic compound having a melting point above room temperature, and/or a non-aromatic compound having a melting point above room temperature. In some embodiments, the emulsion or the microemulsion comprises an aqueous phase, a non-aqueous phase, and at least one surfactant, and an additive which is an aromatic compound or mixture of aromatic compounds having a melting point above room temperature. 1. A microemulsion for treating an oil and/or gas well having a wellbore , comprising:an aqueous phase;a surfactant; anda non-aqueous phase comprising cashew nut shell liquid.2. The microemulsion of claim 1 , wherein the non-aqueous phase further comprises a terpene.3. The microemulsion of claim 1 , wherein the surfactant comprises a derivatized cashew nut shell liquid claim 1 , a linear alcohol ethoxylate claim 1 , or a combination thereof.4. The microemulsion of claim 3 , wherein the derivatized cashew nut shell liquid is an ethoxylated cashew nut shell liquid.5. The microemulsion of claim 1 , wherein the non-aqueous phase further comprises a co-solvent.6. The microemulsion of claim 1 , wherein the microemulsion further comprises a derivatized cashew nut shell liquid.7. A microemulsion for treating an oil and/or gas well having a wellbore claim 1 , comprising:an aqueous phase;a surfactant; anda non-aqueous phase comprising derivatized cashew nut shell liquid.8. The microemulsion composition of claim 7 , wherein the derivatized cashew nut shell liquid is an ethoxylated cashew nut shell liquid.97. The microemulsion composition of claim 7 , therein the surfactant is a derivatized cashew nut shell liquid.109. The microemulsion composition of claim 7 , wherein the ...

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 ...

INHIBITION OF ASPHALTENE

Methods, systems and compositions reduce or prevent the formation of asphaltene deposits by controlling the precipitation of asphaltene. An asphaltene inhibitor is utilized comprising an aromatic core. The asphaltene inhibitor is introduced into a well or pipeline. The method of utilizing the inhibitor may include the use of a downhole continuous injection process or squeeze treatment. A method of reducing asphaltene scale deposition including adding an asphaltene scale deposition squeeze treatment inhibitor to a hydrocarbon reservoir is provided. The asphaltene scale deposition squeeze treatment inhibitor may be added to the hydrocarbon reservoir by a squeeze treatment process. 1. An asphaltene precipitation and/or flocculation inhibitor with a molecular weight of less than about 1000 , wherein the asphaltene precipitation inhibitor comprises an aromatic core and the inhibitor exhibits charge transfer.2. The inhibitor of claim 1 , wherein the molecular weight is at least about 78.3. The inhibitor of wherein the inhibitor has π-π interaction with asphaltene.4. A method of reducing asphaltene precipitation comprising:adding an asphaltene precipitation inhibitor to a hydrocarbon reservoir, well or oil production pipeline;non-covalently interacting the inhibitor with asphaltene through π-π interaction;forming a nanoaggregate of inhibitor and asphaltene in solution.5. The method of claim 4 , wherein adding the asphaltene precipitation inhibitor comprises a squeeze treatment process or a downhole continuous injection process.6. The method of claim 4 , wherein the inhibitor has a molecular weight of less than about 1000.7. The method of claim 4 , wherein the nanoaggregate comprises asphaltene micelles and the inhibitor is disposed within the asphaltene micelle.8. A method of reducing asphaltene scale deposition comprising:adding an asphaltene scale deposition squeeze treatment inhibitor to a hydrocarbon reservoir.9. The method of claim 8 , wherein adding the asphaltene ...

OIL RECOVERY COMPOSITIONS AND METHODS THEREOF

Asphaltene formation in a hydrocarbon-bearing zone is mitigated with the injection of nanoparticles. In one embodiment, a method of mitigating asphaltene formation comprises: providing an injection fluid comprising water, foam, carbon dioxide, natural gas, methane, ethane, nitrogen, propane, butane, flue gas, exhaust gas, steam, alkali, polymer, surfactant, or any combination thereof; providing nanoparticles, wherein the nanoparticles comprise nickel oxide, alumina, silica, silicate based, iron oxide (Fe3O4), impregnated nickel on alumina, synthetic clay, iron zinc sulfide, magnetite, iron octanoate, or any combination thereof; injecting a combination of the injection fluid and the nanoparticles into a hydrocarbon-bearing zone, wherein the nanoparticles are injected such that asphaltene formation is reduced compared to injection without the nanoparticles; and recovering fluids produced from the hydrocarbon-bearing zone, the fluids having a reduced concentration of asphaltenes compared to injection without the nanoparticles. 1. A method of mitigating asphaltene formation , the method comprises:providing an injection fluid comprising water, foam, carbon dioxide, natural gas, methane, ethane, nitrogen, propane, butane, flue gas, exhaust gas, steam, alkali, polymer, surfactant, or any combination thereof;{'sub': 3', '4, 'providing nanoparticles, wherein the nanoparticles comprise nickel oxide, alumina, silica, silicate based, iron oxide (FeO), impregnated nickel on alumina, synthetic clay, iron zinc sulfide, magnetite, iron octanoate, or any combination thereof;'}injecting a combination of the injection fluid and the nanoparticles into a hydrocarbon-bearing zone, wherein the nanoparticles are injected such that asphaltene formation is reduced compared to injection without the nanoparticles; andrecovering fluids produced from the hydrocarbon-bearing zone, the fluids having a reduced concentration of asphaltenes compared to injection without the nanoparticles.2. The ...

Modified Phenol Polymer and Use Thereof

A polymer, such as for use in a petroleum composition, is provided. The polymer has at least the following repeating unit (I): wherein, R 1 includes an alkyl, an alkenyl, an alkynyl, an aryl, an amine, or -A-Y—R 10 wherein A is a direct bond or an alkylene; Y is —C(O)O—, —OC(O)—, —C(O)N(R 11 )—, —N(R 11 )C(O)—, —C(O)—, —N(R 11 )—, —O—, or —S—; R 10 includes an alkyl, an alkenyl, an alkynyl, an aryl, or a polyether; and R 11 is H or an alkyl; R 2 is an alkylene; X is —O—, —N—, —O—C(O)—, or —N—C(O)—; R 3 includes an alkyl, an alkenyl, an alkynyl, or an aryl; R 4 includes H, an alkyl, an alkenyl, an alkynyl, or an aryl; and p is 0 when X is —O—, —O—C(O)—, or —N—C(O)— and p is 1 when X is —N—. The present invention also provides a method for forming the aforementioned polymer containing the aforementioned repeating unit (I) as well as a method for using the aforementioned polymer containing the aforementioned repeating unit (I).

NON-INTRUSIVE AUTOMATED DEPOSITION MANAGEMENT

A method may include: generating a signal in a conduit; measuring the signal; generating data representing a deposit in the conduit, the data being generated by a deposition identification model, wherein the deposition identification model utilizes the signal as an input; generating a treatment plan based at least in part on the data representing the deposit; and applying a chemical additive to the conduit based at least in part on the treatment plan. 1. A method comprising:generating a signal in a conduit;measuring the signal;generating data representing a deposit in the conduit, the data being generated by a deposition identification model, wherein the deposition identification model utilizes the signal as an input;generating a treatment plan based at least in part on the data representing the deposit; andapplying a chemical additive to the conduit based at least in part on the treatment plan.2. The method of wherein the signal is a pressure signal claim 1 , an acoustic signal claim 1 , or a combination thereof and wherein the conduit is a wellbore or a pipeline.3. The method of wherein the step of measuring the signal comprises measuring the signal with a pressure transducer claim 1 , microphone claim 1 , hydrophone claim 1 , or any combination thereof.4. The method of wherein the step of generating data representing the deposit further comprises performing a calibration calculation and using an output of the calibration calculation in the deposition identification model.5. The method of wherein the calibration calculation confirms at least one of acoustic velocity claim 4 , viscosity claim 4 , or density.6. The method of wherein the treatment plan comprises an identity and a flow rate of the chemical additive claim 1 , the chemical additive being operable to treat the deposit.7. The method of wherein the deposit is at least one of asphaltene claim 6 , paraffin claim 6 , hydrate claim 6 , or scale.8. The method of further comprising:performing an integrated ...

AQUEOUS CLEANING COMPOSITION AND METHOD

An aqueous cleaning composition for removing paraffin, asphaltene, and scale deposits or plugs from a hydrocarbon system. The aqueous cleaning composition is formed of a cleaning composition and an aqueous liquid. The cleaning composition contains about 21-33% of a silicate, about 20-35% of a peroxygen, about 3-15% of a phosphate, about 15-40% of a carbonate or bicarbonate, about 1-10% of a chelating agent, about 1-5.5% of a surfactant combination. In one embodiment, the surfactant combination includes a surfactant polymer mixture containing a block polymer and a reverse polymer, and a wetting agent containing a sulfonated material or an ethoxylated alcohol. 1. A cleaning composition comprising:about 21% to about 33% of a silicate;about 20% to about 35% of a peroxygen;about 3% to about 15% of a phosphate;about 15% to about 40% of a carbonate or a bicarbonate;about 1% to about 10% of a chelating agent;about 0.6% to about 2% of a surfactant polymer mixture containing an equal amount of a block polymer and a reverse polymer; andabout 0.5% to about 2% of a wetting agent containing a sulfonated material or an ethoxylated alcohol, wherein a ratio of the surfactant polymer mixture to the wetting agent is about 1:1 to about 1:2.2. The cleaning composition of claim 1 , wherein the silicate comprises a sodium metasilicate claim 1 , a sodium sesqui-silicate claim 1 , a sodium silicate claim 1 , a potassium silicate claim 1 , or an orthosilicate.3. The cleaning composition of claim 1 , wherein the peroxygen comprises a percarbonate claim 1 , a perborate claim 1 , a hydrogen peroxide claim 1 , a persulfate claim 1 , a thiourea dioxide claim 1 , a diethylhydroxylamine claim 1 , a peracetic acid claim 1 , or a urea peroxide.4. The cleaning composition of claim 1 , wherein the phosphate comprises sodium tripolyphosphate claim 1 , tetrapotassium pyrophosphate claim 1 , sodium hexametaphosphate claim 1 , sodium acid pyrophosphate claim 1 , tetrasodium pyrophosphate claim 1 , ...

NON-REDUCING STABILIZATION COMPLEXANT FOR ACIDIZING COMPOSITIONS AND ASSOCIATED METHODS

Methods for reducing viscosifying tendencies of crude oil in subterranean formations using solid acid chelating agents are described. The methods include combining a solid acid chelating agent and an aqueous acid solution to form a treatment fluid, and introducing the treatment fluid into the subterranean formation. The solid acid chelating agent includes at least one aminopolycarboxylic acid functional group and at least one phosphonic acid functional group. 1. A method of reducing viscosifying tendencies of crude oil in a subterranean formation comprising:combining a solid acid chelating agent and an aqueous acid solution to form a treatment fluid, wherein the solid acid chelating agent consists of at least one aminopolycarboxylic acid functional group and at least one phosphonic acid functional group andintroducing the treatment fluid into the subterranean formation, wherein the subterranean formation has a bottomhole temperature in excess of 350° F.2. The method of claim 1 , wherein the treatment fluid does not comprise an emulsion.3. The method of claim 1 , wherein the treatment fluid has a viscosity substantially similar to water.4. The method of claim 1 , wherein the aqueous acid solution comprises hydrochloric acid.5. The method of claim 1 , wherein the solid acid chelating agent is present in an amount of about 5% to 35% (w/v) of the treatment fluid.6. The method of claim 1 , wherein the solid acid chelating agent is present in an amount of about 0.5 to about 40 pounds per thousand gallons (PPT) of the treatment fluid.7. The method of claim 1 , wherein reducing the formation of sludge is part of an acidizing or scale control operation.8. The method of claim 1 , wherein the solid acid chelating agent claim 1 , when ionized claim 1 , forms a complex with iron cations.9. The method of claim 8 , wherein the iron cations comprise ferric cations.10. A method of reducing viscosifying tendencies of crude oil in a subterranean formation comprising:combining a solid ...

THERMALLY STABLE SCALE INHIBITOR COMPOSITIONS

The present invention relates to a thermally stable polymeric scale inhibitor compositions and use thereof. Preferably, the polymeric scale inhibitor is a polycarboxylic acid copolymer comprising a styrene sulfonic acid group. The polymeric scale inhibitor compositions of the present invention are particularly suitable for high pressure/high temperature scale inhibition treatment of oil and gas production wells and/or subterranean formations. 1. A method for scale inhibition treatment of an operation comprising a water system comprising the step of introducing an aqueous scale inhibiting composition into the water system wherein the aqueous scale inhibiting composition comprises a polycarboxylic acid copolymer comprising the following monomers:i) one or more monoethylenically unsaturated acid and/or anhydride and/or one of its saltsandii) styrene sulfonic acid and/or one of its salts.2. The method of whereini) the one or more monoethylenically unsaturated acid and/or anhydride and/or one of its salts is acrylic acid, methacrylic acid, or mixtures thereofandii) the styrene sulfonic acid and/or one of its salts is 4-styrene sulphonic acid.3. The method of whereini) the one or more monoethylenically unsaturated acid and/or anhydride and/or one of its salts is present in an amount of 50 to 98 weight percentandii) styrene sulfonic acid and/or one of its salts is present in an amount of 2 to 50 weight percent,wherein weight percent is based on the total weight of the polymerized monomers.4. The method of wherein the polycarboxylic acid copolymer is a copolymer consisting of acrylic acid and 4-styrene sulphonic acid having a weight average weightcular weight of from 1 claim 1 ,000 to 50 claim 1 ,000 Daltons.5. The method of wherein the aqueous scale inhibiting composition is introduced by a squeeze treatment.6. The method of wherein the aqueous scale inhibiting composition is introduced by a capillary injection treatment.7. The method of wherein the operation comprising a ...

Method of using shaped compressed pellets in well treatment operations

A shaped compressed pellet formed from a composite of a well treatment agent adsorbed onto a calcined porous metal oxide or into the interstitial spaces of the calcined porous metal oxide may be introduced into an oil or gas producing well. The well treatment agent of the shaped compressed pellet may be used to prevent and/or control the formation of deposits in the well.

Hydrate kinetics inhibitor

A hydrate kinetic inhibitor, which is prepared by a polymerization of mercaptoethanol and N-vinylcaprolactam, is hydroxyl terminated poly(N-vinylcaprolactam) having a structure of formula (I) below, wherein n=10 to 1000. The inhibitor is a novel hydrate kinetic inhibitor, which has low effective concentration and high cloud point, and is effective when the degree of supercooling is relatively high.

METHODS AND SYSTEMS FOR CONTROLLABLY GENERATING HEAT AND/OR NITROGEN GAS IN SUBTERRANEAN AND PIPELINE OPERATIONS

Methods and systems for generating heat and/or nitrogen gas in subterranean operations, pipelines, and other related operations are provided. In one embodiment, the methods comprise: providing a treatment composition comprising a carrier fluid, a delayed acid generating component, a first reactant, and a second reactant, wherein the first and second reactants are selected for being capable of reacting in an exothermic chemical reaction or a chemical reaction that produces nitrogen gas; and introducing the treatment composition into at least a portion of a conduit, container, or subterranean formation. 1. A method comprising:providing a treatment composition comprising a carrier fluid, a delayed acid generating component, a first reactant, and a second reactant, wherein the first and second reactants are selected for being capable of reacting in an exothermic chemical reaction; andintroducing the treatment composition into at least a portion of a subterranean formation.2. The method of wherein one or more of the first reactant claim 1 , the second reactant claim 1 , and the delayed acid generating component are introduced into the portion of the subterranean formation separately from another component of the treatment composition.3. The method of wherein the first reactant comprises sodium nitrite and the second reactant comprises ammonium chloride.4. The method of wherein the delayed acid generating component comprises at least one compound selected from the group consisting of: a lactate claim 1 , a lactic acid derivative claim 1 , a glycerol ester claim 1 , a glycerol polyester claim 1 , an aliphatic polyester claim 1 , a poly(lactide) claim 1 , a poly(glycolide) claim 1 , a poly(c-caprolactone) claim 1 , a poly(hydroxy ester ether) claim 1 , a poly(hydroxybutyrate) claim 1 , an aliphatic polycarbonate claim 1 , a poly(orthoester) claim 1 , a poly(amino acid) claim 1 , a poly(ethylene oxide) claim 1 , a polyphosphazene claim 1 , and any combination thereof.5. The ...

Composition and Methods for Microbial Enhanced Digestion of Polymers in Fracking Wells

The present invention provides environmentally-friendly compositions and methods for degrading polymers used in fracking operations to enhance the recovery of oil and gas. Specifically, the compositions and methods utilized microorganisms and/or heir growth by products to degrade polymers, such as PGA, PLA and PAM, used in fracking wells.

Refinery Antifoulant Process

Fouling in a refinery vessel, such as heat transfer equipment, used in a petroleum refinery operation and in which a refineable petroleum feedstock is at an elevated temperature and in fluid communication with the refinery vessel during a petroleum refinery operation, is reduced by providing in the refineable petroleum feedstock an additive comprising (i) a poly(butylenyl)benzene sulphonic acid; or, (ii) a poly(propylenyl)benzene sulphonic acid; or, (iii) a combination of a poly(butylenyl)benzene sulphonic acid and a poly(propylenyl)benzene sulphonic acid.

Determination Of Asphaltene Inhibitor Properties And Treatment Of Crude Oil With Asphaltene Inhibitors

This disclosure relates methods and systems for determining asphaltene inhibitor properties. For example, one embodiment provides a method for determining a content of disaggregated asphaltene in an inhibited crude oil. The method includes measuring the dielectric constant of a sample of the crude oil, the sample having a first concentration of an asphaltene inhibitor; providing a first dielectric correction factor for the first concentration of the asphaltene inhibitor; calculating, e.g., by a computing device, a first corrected dielectric constant of the sample having the first concentration, using the first dielectric correction factor; and determining the content of disaggregated asphaltene in the first crude oil sample, based on the first corrected dielectric constant. Methods for inhibiting asphaltene aggregation in crude oil are also provided. 1. A method for determining a content of disaggregated asphaltene in an inhibited crude oil , comprisingmeasuring the dielectric constant of a sample of the crude oil, the sample having a first concentration of an asphaltene inhibitor;providing a first dielectric correction factor for the first concentration of the asphaltene inhibitor;calculating, by a computing device, a first corrected dielectric constant of the sample having the first concentration, using the first dielectric correction factor; anddetermining the content of disaggregated asphaltene in the first crude oil sample, based on the first corrected dielectric constant.2. A method according to claim 1 , wherein the crude oil comprises water.3. A method according to claim 1 , wherein the first concentration is within the range of about 50 ppm to about 500 ppm.4. A method according to claim 1 , wherein the dielectric correction factor for the first concentration of the asphaltene inhibitor is a weighted average of the dielectric constant of an aliphatic hydrocarbon sample having the first concentration of the asphaltene inhibitor dissolved in an aliphatic ...

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.

COMPOSITES FOR USE IN STIMULATION AND SAND CONTROL OPERATIONS

A composite having a solid particulate and a surface modifying treatment agent on the solid particulate wherein the surface modifying treatment agent has a hydrophobic tail and an anchor for adhering the hydrophobic tail onto the solid particulate. The anchor may be metal and the hydrophobic tail may be an organo-silicon material, a fluorinated hydrocarbon or both an organo-silicon material and a fluorinated hydrocarbon. The composite may be used as a proppant in a hydraulic fracturing operation as well as a sand control particulate in a gravel packing operation. The presence of the surface modifying treatment agent on the surface of the solid particulate reduces the generation of fines and dust as well as the migration of sand during a hydraulic fracturing operation or a sand control operation. The presence of the surface modifying treatment agent on the surface of the solid particulate further enhances the crush resistance of the solid particulate. 1. A composite for treating a well wherein the composite comprises a surface modifying treatment agent at least partially coated onto a solid particulate and wherein the surface modifying treatment agent comprises a metallic anchor and a hydrophobic tail wherein the hydrophobic tail is an organo-silicon material , a fluorinated hydrocarbon or both a hydrophobic organo-silicon material and a fluorinated hydrocarbon and further wherein the metallic anchor of the surface modifying treatment agent is attached to the solid particulate.2. The composite of claim 1 , wherein the hydrophobic tail is a derivative of a silane claim 1 , polysiloxane or a polysilazane.31. The composite of claim 1 , wherein the metal of the metallic anchor is a Group 3 claim 1 , 4 claim 1 , 5 claim 1 , or 6 metal.4. The composite of claim 3 , wherein the metal of the metallic anchor is selected from the group consisting of Ti claim 3 , Zr claim 3 , La claim 3 , Hf claim 3 , Ta claim 3 , W and Nb.9. The composite of claim 1 , wherein the hydrophobic ...

METHOD FOR REMOVING ORGANIC AND INORGANIC DEPOSITS IN ONE STEP

Both organic deposits and inorganic deposits in a wellbore are simultaneously removed from a wellbore by contacting the deposits with a single phase fluid for an amount of time effective to simultaneously disperse the organic deposits and dissolve the inorganic deposits, where the single phase fluid includes least one solvent, at least one surfactant, at least one co-solvent, and at least one scale dissolver. The method further involves at least partially removing the organic deposits and inorganic deposits from the wellbore. In an embodiment where it is not necessary to remove inorganic deposits, the scale dissolver may be omitted. 1. A method for removing organic deposits from a wellbore comprising: at least one solvent;', 'at least one surfactant; and', 'at least one co-solvent; and, 'contacting the organic deposits in the wellbore with a single phase fluid for an amount of time effective to disperse the organic deposits, where the single phase fluid comprisesat least partially removing the organic deposits from the wellbore.2. The method of where the organic deposits comprise asphaltenes claim 1 , paraffins claim 1 , and combinations thereof.3. The method of where:the at least one solvent is selected from the group consisting of organic solvents, aromatic solvents, aliphatic solvents, naphthenic solvents, and combinations thereof; nonionic surfactants having an HLB between about 9 and about 14,', 'anionic surfactants selected from the group consisting of oxyalkylated ether sulfates, alkyl aryl sulfates, disulfonates, sulfosuccinates, sulfonates and carboxylates,', 'cationic surfactants,', 'gemini surfactants, betaines, amino-acids, and', 'combinations thereof; and, 'the at least one surfactant is selected from the group consisting ofthe at least one co-solvent is selected from the group consisting of glycol ethers, methyl 2-pyrrolidone, methanol, isopropyl alcohol, butanol, pentanol, hexanol, isooctyl alcohol and their isomers, blends of C1-C8 alcohols and ...

DISPERSING ADDITIVE FOR ASPHALTENES AND ITS USES

Use of an alkylphenol-aldehyde resin modified by at least one alkylamine in a composition of crude oils or in a product derived from a composition of crude oils as dispersing additive for asphaltenes. Process for the treatment of a composition of crude oils or a derived product which makes it possible to prevent the precipitation of asphaltenes, in particular in crude oils and the products which result therefrom by refining and/or extraction processes. Bituminous compositions including an alkylphenol-aldehyde resin modified by at least one alkylamine. 123-. (canceled)24. Method for dispersing asphaltenes and/or for preventing and/or delaying and/or stopping and/or reducing the precipitation of asphaltenes comprised in a composition of crude oils or in a product derived from a composition of crude oils comprising adding to said composition or product at least one modified alkylphenol-aldehyde resin , the said modified alkylphenol-aldehyde resin being capable of being obtained by a Mannich reaction of an alkylphenol-aldehyde condensation resin withat least one aldehyde and/or one ketone having from 1 to 8 carbon atoms;and at least one hydrocarbon compound having at least one alkylamine group having between 1 and 30 carbon atoms,the said alkylphenol-aldehyde condensation resin being itself capable of being obtained by condensationof at least one alkylphenol substituted by at least one linear or branched alkyl group having from 1 to 30 carbon atoms,with at least one aldehyde and/or one ketone having from 1 to 8 carbon atoms.25. Method according to claim 24 , for its employment in a composition of crude oils or in a product derived from a composition of crude oils and comprising asphaltenes subjected to one or more of the following conditions:a rise in pressure,a rise in temperature,a mixing with at least one other fluid.26. Method according to claim 24 , wherein the modified alkylphenol-aldehyde resin is capable of being obtained from p-nonylphenol claim 24 , ...

FLUID FORMULATIONS FOR CLEANING OIL-BASED OR SYNTHETIC OIL-BASED MUD FILTER CAKES

A treatment composition may contact an oil-based mud (OBM) filter cake formed over at least part of a wellbore for incorporating more oil and/or filter cake particles into the treatment composition as compared to an otherwise identical filter cake absent the treatment composition. The treatment composition may include, but is not limited to, a surfactant, an aqueous-based fluid, an agent, an optional second acid, and combinations thereof. The agent may be or include long chain alcohols, phenol derivatives, fatty esters, a first acid, and combinations thereof. The first acid may be or include citric acid, oleic acid, tartaric acid, stearic acid, linoleic acid, linolenic acid, aromatic dicarboxylic acids, oxalic acid, malonic acid, succinic acid, glutaric acid, boric acid, adipic acid, a diacid, a triacid, a tetraacid, and combinations thereof. 1. A treatment composition comprising:a surfactant selected from the group consisting of nonionic surfactants, anionic surfactants, cationic surfactants, amphoteric surfactants, zwitterionic surfactants, gemini surfactants, extended chain surfactants, dendritic surfactants, dendritic extended surfactants, and combinations thereof;an aqueous-based fluid; andan agent selected from the group consisting of long chain alcohols, phenol derivatives, fatty esters, a first acid, and combinations thereof; wherein the first acid is selected from the group consisting of citric acid, oleic acid, tartaric acid, stearic acid, linoleic acid, linolenic acid, aromatic dicarboxylic acids, oxalic acid, malonic acid, succinic acid, glutaric acid, glutamic acid, boric acid and adipic acid, a diacid, a triacid, a tetraacid, and combinations thereof.2. The treatment composition of claim 1 , wherein the diacid is a polycarboxylic acid selected from the group consisting of [N-(1 claim 1 ,2-dicarboxyethylene)-D claim 1 ,L-asparagine acid] (IDS) claim 1 , polyaspartic acid (DS) claim 1 , ethylenediamine-disuccinic acid (EDDS) claim 1 , [N claim 1 ,N-bis( ...

USE OF ESTERAMINE TO INHIBIT THE AGGLOMERATION OF GAS HYDRATES

A process is described for inhibiting and/or delaying and/or preventing the agglomeration of gas hydrates, comprising adding one or more compounds of formula (1) or salts thereof: 5. The process according to claim 1 , wherein the compound of formula (1) is present in an amount ranging from 0.1% to 10% by weight claim 1 , relative to the total weight of the aqueous phase in a production fluid.6. The process according to a claim 1 , employing at least one compound of formula (1) in a carrier liquid.7. The process according to a claim 1 , employing at least one compound of formula (1) in a carrier liquid with low water miscibility.8. The process according to claim 1 , employing at least one compound of formula (1) in a carrier liquid claim 1 , said carrier liquid comprising at least one alcohol comprising one (1) or more hydroxyl groups on a linear claim 1 , branched or cyclic claim 1 , saturated or unsaturated hydrocarbon chain claim 1 , said hydrocarbon chain generally comprising from 1 to 30 carbon atoms.9. The process according to a claim 1 , employing at least one compound of formula (1) in a carrier liquid added to the production fluid in a proportion to make it possible to obtain a water fraction of 90% or less claim 1 , expressed by volume of aqueous phase relative to the total volume of liquid.10. (canceled)11. The process according to claim 1 , comprising a step of adding one or more compounds of formula (1) claim 1 , as defined in claim 1 , in combination with one or more other additives claim 1 , fillers claim 1 , solvents.12. The process according to claim 1 , comprising a step of adding one or more compounds of formula (1) in combination with one or more other additives chosen from corrosion inhibitors claim 1 , kinetic hydrate inhibitors claim 1 , mineral deposit inhibitors claim 1 , demulsifiers claim 1 , deoilers claim 1 , defoaming additives claim 1 , paraffin inhibitors and dispersants claim 1 , asphaltene inhibitors and dispersants claim 1 , ...

Nanoparticle carrier platform and methods for controlled release of subterranean well treatment additives

Nano-sized mixed metal oxide carriers capable of delivering a well treatment additive for a sustained or extended period of time in the environment of use, methods of making the nanoparticles, and uses thereof are described herein. The nanoparticles can have a formula of:A/[Mx1My2Mz3]OnHmwhere x is 0.03 to 3, y is 0.01 to 0.4, z is 0.01 to 0.4 and n and m are determined by the oxidation states of the other elements, and M1 can be aluminum (Al), gallium (Ga), indium (In), or thallium (Tl). M2 and M3 are not the same and can be a Column 2 metal, Column 14 metal, or a transition metal. A is can be a treatment additive.

Methods of using ionic liquids as corrosion inhibitors

Ionic liquid containing compositions may be used in the production, recovery and refining of oil and gas. In addition, they may be used to treat cooling water and/or to inhibit and/or prevent corrosion of metals.

Nitrile solvents

A method of removing from a surface a solid sulfur-containing impurity composition comprising a sulfur-containing compound, the method comprising the step of dissolving sulfur-containing compound in the sulfur-containing impurity composition with a nitrile compound to form a treated sulfur-containing impurity composition comprising less than 99.5 wt % sulfur-containing compound, based on the total weight of the treated sulfur-containing impurity composition.

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 ...

POLYMERIC COMPOSITIONS COMPOSED OF ETHYLENE-VINYL ESTER COPOLYMERS ALKYL (METH)ACRYLATES, PROCESSES FOR PRODUCTION THEREOF AND USE THEREOF AS POUR POINT DEPRESSANTS FOR CRUDE OILS, MINERAL OILS OR MINERAL OIL PRODUCTS

Polymeric compositions obtainable by free-radical polymerization of at least two different alkyl (meth)acrylates in the presence of at least one ethylene-vinyl ester copolymer, the alkyl (meth)acrylates used being a mixture comprising alkyl (meth)acrylates having linear C- to C-alkyl radicals and different alkyl (meth)acrylates having linear C- to C-alkyl radicals and/or branched C- to C-alkyl radicals and/or cyclic C- to C-alkyl radicals. The use of such polymeric compositions as pour point depressants for crude oils, mineral oils or mineral oil products. 1. A polymeric composition obtainable by free-radical polymerization of monoethylenically unsaturated monomers (A) in the presence of at least one ethylene-vinyl ester copolymer (B) ,the monomers (A) comprising at least 70% by weight of alkyl (meth)acrylates (A1) based on the amount of all monomers (A),{'sub': 2', '1', '4, 'sup': 1', '1, 'the ethylene-vinyl ester copolymers (B) comprising 55 to 85% by weight of ethylene and 15 to 45% by weight of vinyl esters of the general formula HC═CH—O—(O)C—R(III) where Ris H or a C- to Chydrocarbyl radical, and'}the amount of the monomers (A) being 70 to 90% by weight and that of the ethylene-vinyl ester copolymers (B) 10 to 30% by weight based on the sum of the monomers (A) and the ethylene-vinyl ester copolymers (B) together,wherein the alkyl (meth)acrylates (A1) are a mixture of{'sub': '2', 'sup': 2', '3', '2', '3, '(A1a) 50 to 99 mol % of at least one alkyl (meth)acrylate (A1a) of the general formula HC═C(R)—COORwhere Ris H or a methyl group and Ris a linear alkyl radical having 12 to 60 carbon atoms, and'}{'sub': '2', 'sup': 2', '4', '2', '4', '4a', '4b', '4c, 'claim-text': [{'sup': '4a', 'R: linear alkyl radicals having 1 to 11 carbon atoms,'}, {'sup': '4b', 'R: branched alkyl radicals having 4 to 60 carbon atoms, and'}, {'sup': '4c', 'R: cyclic alkyl radicals having 5 to 20 carbon atoms,'}, 'with the proviso that the sum of the amounts of (A1a) and (A1b) adds up to 100 ...

COMPOSITION FOR REMOVING ORGANIC DEPOSITS FROM OIL AND GAS WELLS AND OTHER SUBSURFACE SYSTEMS AND METHOD FOR REMOVING ORGANIC DEPOSITS USING THE REMOVER COMPOSITION

The present invention relates to a method for removing organic deposits from oil and gas wells and other subsystem systems comprising cumene and biodiesel. The invention also relates to a method for removing organic deposits, including the steps for pumping said remover composition through a riser and/or through peripheral pipes of the umbilical and/or production pipe, leaving the composition in contact with the deposit for a sufficient time for removal of at least 50% of such. 1. A remover composition of organic deposits and fouling in oil and gas wells and other subsurface systems , comprising (A) 75% to 97.5% by weight of cumene and (B) 2.5 to 25% by weight of biodiesel.2. The remover composition according to claim 1 , wherein the composition comprises 95% by weight of cumene and 5% by weight of biodiesel.3. The remover composition according to claim 1 , wherein the cumene consists of pure cumene (isopropylbenzene with purity above 99.9%) or contaminated cumene with up to 10% by weight of diisopropylbenzene (DIPB) and up to 3% by weight of 1 claim 1 ,3 claim 1 ,5-triisopropylbenzene (TIPB) claim 1 , based on cumene weight.4. The remover composition according to claim 1 , wherein the biodiesel comprises methyl esters derived from polyunsaturated-rich vegetable oils selected from the group consisting of soybean claim 1 , cotton and sunflower oil.5. The remover composition according to claim 4 , wherein the biodiesel comprises antioxidant additives selected from the group consisting of 2 claim 4 ,6-di-tert-butyl-4-methyl-phenol (BHT) claim 4 , 2 claim 4 , 5-di-tert-butyl hydroquinone (TBHQ) and 3-tert-butyl-4-hydroxyanisole (BHA).6. The remover composition of claim 5 , wherein the concentration of the oxidizing additive ranges from 100 to 1000 ppm.7. The remover composition of claim 4 , wherein the methyl ester is methyl isoate.8. The remover composition according to claim 1 , which has a flash point above 46° C.9. A method for removing organic deposits claim 1 , ...

PARAFFIN SUPPRESSANT COMPOSITIONS AND METHODS

Disclosed herein are paraffin suppressant compositions, and methods of making and using them. The compositions comprise a paraffin inhibitor, a hydrocarbon-soluble hydrotrope equivalent, and optionally one or more additional paraffin dispersants. When added to hydrocarbon media such as crude oils to form crude oil compositions, the suppressant compositions inhibit the precipitation of paraffin waxes in the crude oil compositions. The suppressant compositions, added to hydrocarbon media such as hydrocarbon solvents or crude oils, exhibit reduced precipitation, gelling, and/or crystallization of paraffin inhibitor from the hydrocarbon media, when the media are subjected to sustained temperatures between 4° C. and −60° C. 2. The paraffin suppressant composition of wherein the hydrotrope equivalent comprises an organic-ammonium salt of an alkylbenzene sulfonic acid wherein the alkyl of the alkylbenzene is a C10 to C20 alkyl.4. The paraffin suppressant composition of claim 1 , wherein the organic-ammonium is ethanolammonium.5. The paraffin suppressant composition of claim 1 , wherein Ris a C18 alkyl.8. The paraffin suppressant composition of claim 1 , further comprising a solvent selected from C1-C12 alcohols claim 1 , C5 to C18 linear alkanes claim 1 , C5 to C18 branched alkanes claim 1 , C5 to C8 cycloalkanes claim 1 , benzene claim 1 , toluene claim 1 , o-xylene claim 1 , m-xylene claim 1 , p-xylene claim 1 , refined petroleum solvent claim 1 , or any combination thereof.9. The paraffin suppressant composition of claim 1 , wherein the composition further comprises a C4-C50 alkyl phenol-formaldehyde resin.10. The paraffin suppressant composition of claim 1 , wherein the composition comprises less than 10% of water.11. A crude oil comprising about 0.1 ppm to 10 claim 1 ,000 ppm of the paraffin suppressant composition of .12. A method comprising applying about 0.1 ppm to 10 claim 1 ,000 ppm of the paraffin suppressant composition of to a first oil composition to make a ...

Asphaltene inhibition

The technology disclosed herein provides compositions and methods for asphaltene control in a hydrocarbon fluid, such as crude oil, by employing a thiophosphonate ester compound.

AQUEOUS CLEANING COMPOSITION AND METHOD

An aqueous cleaning composition for removing paraffin, asphaltene, and scale deposits or plugs from a hydrocarbon system. The aqueous cleaning composition is formed of a cleaning composition and an aqueous liquid. The cleaning composition contains about 21-33% of a silicate, about 20-35% of a peroxygen, about 3-15% of a phosphate, about 15-40% of a carbonate or bicarbonate, about 1-10% of a chelating agent, about 1-5.5% of a surfactant combination. In one embodiment, the surfactant combination includes a surfactant polymer mixture containing a block polymer and a reverse polymer, and a wetting agent containing a sulfonated material or an ethoxylated alcohol. 1. A method of removing a deposit from a hydrocarbon system , comprising the steps of:a) providing a cleaning composition comprising: about 21% to about 33% of a silicate, about 20% to about 35% of a peroxygen, about 3% to about 15% of a phosphate, about 15% to about 40% of a carbonate or a bicarbonate, about 1% to about 10% of a chelating agent, about 0.6% to about 2% of a surfactant polymer mixture containing an equal amount of a block polymer and a reverse polymer, and about 0.5% to about 2% of a wetting agent containing a sulfonated material or an ethoxylated alcohol, wherein a ratio of the surfactant polymer mixture to the wetting agent is about 1:1 to about 1:2;b) treating the hydrocarbon system containing the deposit with an aqueous cleaning fluid containing a concentration of the cleaning composition; andc) removing the deposit with the aqueous cleaning fluid from the hydrocarbon system.2. The method of claim 1 , wherein the concentration of the cleaning composition in the aqueous cleaning fluid is about 1% to about 10% by weight.3. The method of claim 1 , wherein the cleaning composition further comprises about 0.4% to about 1.5% of an ethoxy phosphate.4. The method of claim 1 , wherein the hydrocarbon system is an oil or gas wellbore or pipeline.5. The method of claim 4 , wherein the deposit contains ...

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.

METHOD OF INHIBITING OR REDUCING BIOFILM IN A PETROLEUM PRODUCTION PROCESS

The present disclosure generally relates to relates to methods of controlling biofilm, e.g., biofilm comprising microorganisms such as bacteria, which methods inhibit the formation of and/or reduce the amount of biofilm on a petroleum production surface, by contacting the surface and/or the biofilm with a petroleum field fluid comprising at least one compound which controls or inhibits the formation of and/or reduces the amount of biofilm. 2. The method according to claim 1 , wherein the petroleum field fluid comprises an aqueous fluid and/or the petroleum field fluid comprises water.3. The method according to or claim 1 , wherein Formula (I):R1 represents methyl group; ethyl propyl group; butyl group; methoxy group; ethoxy group; propoxy group; isopropoxy group; n-butoxy group; or tertiary butoxy group; andR2 and R3 represent independently hydrogen atom; methyl group; ethyl propyl group; butyl group; methoxy group; ethoxy group; propoxy group; isopropoxy group; n-butoxy group; tertiary butoxy group; andA represents 2-propenenitrile4. The method according to any one of the foregoing claims claim 1 , wherein Formula (I):R1 represents methyl group; ethyl propyl group; butyl group; methoxy group; ethoxy group; propoxy group; isopropoxy group; n-butoxy group; tertiary butoxy group; or amino group; andR2 and R3 represent independently hydrogen atom; methyl group; ethyl propyl group; butyl group; methoxy group; ethoxy group; propoxy group; isopropoxy group; n-butoxy group; tertiary butoxy group; andA represents a —CHCHCONR5R6 group, where R5 and R6 represent independently a hydrogen atom; an alkyl or hydroxyalkyl having 1 to 4 carbon atoms; optionally wherein R5 and R6 represent hydrogen atoms.5. The method according to any one of the foregoing claims claim 1 , wherein the compound according to Formula (I) is 3-[(4-methylphenyl)sulphonyl]-2-propenenitrile or 4-amino-N-2-thiazolyl-benzenesulphonamide.6. The method according to any one of the foregoing claims claim 1 , ...

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 ...

Process for the Cleaning of Oil and Gas Wellbores

Cleaning composition for use in cleaning wellbore walls, tubing or casing comprising: (i) from about 5% to 100% by weight of a mixture M consisting of from 10% to 50% by weight of acetophenone, from 5% to 30% by weight of butyl glycol and from 40% to 80% by weight of a surfactant, and (ii) from 0% to 95% by weight of water, in which (i)+(ii) sum up for at least 85% by weight of the cleaning composition; and process for cleaning a wellbore wall. 1. A cleaning composition for use in cleaning wellbore walls , tubing or casings comprising (i) from about 5% to 100% by weight of a mixture M consisting of from 10% to 50% by weight of acetophenone , from 5% to 30% by weight of butyl glycol and from 40% to 80% by weight of a surfactant and (ii) from 0% to 95% by weight of water , in which (i)+(ii) sum up for at least 85% by weight of the cleaning composition.2. The cleaning composition of claim 1 , comprising (i) from about 20% to about 50% by weight of a mixture M consisting of from 20% to 40% by weight of acetophenone claim 1 , from 10% to 20% by weight of butyl glycol and from 50% to 70% by weight of a surfactant and (ii) from 50% to 80% by weight of water claim 1 , in which (i)+(ii) sum up for at least 90% by weight.3. The cleaning composition of claim 2 , comprising (i) from about 30% to about 40% by weight of a mixture M consisting of from 25% to 35% by weight of acetophenone claim 2 , from 10% to 20% by weight of butyl glycol and from 50% to 70% by weight of a surfactant and (ii) from 50% to 80% by weight of water claim 2 , in which (i)+(ii) sum up for at least 95% by weight.4. The cleaning composition of claim 1 , comprising one or more organic solvent different from acetophenone and butyl glicol in an amount not exceeding 10% by weight of the mixture M.5. The cleaning composition of claim 4 , comprising one or more organic solvent different from acetophenone and butyl glicol in an amount not exceeding 5% by weight of the mixture M.6. The cleaning composition of ...

PARAFFIN INHIBITION BY SOLUBILIZED CALIXARENES

This invention relates to compositions and a process for stabilizing or improving the solubility of a phenolic resin containing a mixture of linear phenolic resins and calixarenes in a hydrocarbon solvent. This invention also relates to a paraffin-containing fluid composition comprising this stabilized (solubilized) calixarene resin. The invention also relates to methods for dispersing paraffin crystals, inhibiting paraffin crystal deposition, or treating a well or vessel to reduce the deposition of paraffin crystals, with a resin composition containing this stabilized (solubilized) calixarene resin. 2. The method of claim 1 , wherein each m is 1.5. The method of claim 1 , wherein each Ris independently a Cto Calkyl or Cto Calkyl.6. The method of claim 1 , wherein the total number of units in the modified calixarene compounds is from 4-8.7. The method of claim 1 , wherein q is 1 in one or more units in the modified calixarene compounds.8. The method of claim 1 , wherein the paraffin-containing fluid is a hydrocarbon fluid selected from the group consisting of a crude oil claim 1 , home heating oil claim 1 , lubricating oil claim 1 , and natural gas.10. The method of claim 9 , wherein each m is 1.13. The method of claim 9 , wherein each Ris independently a Cto Calkyl or Cto Calkyl.14. The method of claim 9 , wherein the total number of units in the modified calixarene compounds is from 4-8.15. The method of claim 9 , wherein q is 1 in one or more units in the modified calixarene compounds.16. The method of claim 9 , wherein the resin composition further comprises a hydrocarbon fluid that the resin is at least partially soluble in claim 9 , selected from the group consisting of a crude oil claim 9 , home heating oil claim 9 , lubricating oil claim 9 , and natural gas.17. The method of claim 16 , wherein the hydrocarbon fluid comprises one or more hydrocarbon solvents selected from the group consisting of kerosene claim 16 , diesel claim 16 , heptane claim 16 , benzene ...

Paraffin inhibition by calixarenes

This invention relates to a paraffin-containing fluid composition comprising a phenolic resin containing one or more calixarene compounds (i.e., a calixarene resin). The invention also relates to methods for dispersing paraffin crystals, inhibiting paraffin crystal deposition, or treating a well or vessel to reduce the deposition of paraffin crystals, with a calixarene resin.

Methods of Using Ionic Liquids as Demulsifiers

A method of demulsifying an emulsion with an ionic liquid having a nitrogen or phosphorus cation. 2. The method of claim 1 , wherein the ionic liquid is of formula (I) and X is an anionic homopolymer or copolymer of ethylene oxide/propylene oxide.4. The method of claim 2 , wherein X is —(CHCHO)CHCH(CH)O)where x and y are independently selected from 1 to 1500.5. The method of claim 1 , wherein X is selected from the group consisting of anionic alkyl substituted phenols claim 1 , anionic phenol oxyalkylates and anionic alkyl substituted phenol oxyalkylates.6. The method of claim 5 , wherein the alkyl and oxyalkylate groups contain from 1 to 28 carbon atoms.7. The method of claim 1 , wherein each R claim 1 , R claim 1 , R claim 1 , R claim 1 , R claim 1 , Rand Rare independently selected from the group consisting of hydrogen; benzyl; oxyalkyl; a straight or branched Calkyl group; a Calkylbenzyl group; a Carylalkyl group; a straight or branched Calkenyl group; a Chydroxyalkyl group; a Chydroxyalkylbenzyl group; and a polyoxyalkylene group and further wherein R groups may be joined to form a heterocyclic nitrogen containing ring; and Ris a straight or branched Calkylene claim 1 , an alkylene oxyalkylene claim 1 , or an alkylene polyoxyalkylene.8. The method of claim 7 , wherein R claim 7 , R claim 7 , R claim 7 , R claim 7 , R claim 7 , Rand Rof (II) and (III) are independently selected from —H claim 7 , a Calkyl claim 7 , —CHCHOH claim 7 , —CHCH(CH)OH claim 7 , and an oxirane or methyloxirane homo or copolymer containing (CHCHO)CHCH(CH)O)where x and y are independently selected from 1 to 1500 and mixtures thereof.9. The method of claim 1 , wherein the emulsion is a water-in-oil emulsion.10. The method of claim 1 , wherein the water-in-oil emulsion is a crude oil emulsion.11. The method of claim 12 , wherein the crude oil emulsion is a refinery desalting emulsion or a crude oil production emulsion.12. The method of claim 3 , wherein the melting point of the ionic liquid ...

FUNCTIONALIZED SILICATE NANOPARTICLE COMPOSITION, REMOVING AND EXFOLIATING ASPHALTENES WITH SAME

Removing an asphaltene particle from a substrate includes contacting a silicate nanoparticle with a chemical group to form a functionalized silicate nanoparticle, the chemical group includes a first portion; and a second portion comprising an aromatic moiety, the first portion being bonded to the silicate nanoparticle; contacting the asphaltene particle with the functionalized silicate nanoparticle, the asphaltene particle being disposed on the substrate; interposing the functionalized silicate nanoparticle between the asphaltene particle and the substrate; and separating the asphaltene particle from the substrate with the functionalized silicate nanoparticle to remove the asphaltene particle. A composition includes a functionalized silicate nanoparticle comprising a reaction product of a silicate nanoparticle and an aromatic compound; and a fluid. The aromatic compound includes a chemical group that includes a first portion, the first portion being directly bonded to the silicate nanoparticle in the functionalized silicate nanoparticle; and a second portion including an aromatic moiety. 1. A process for removing an asphaltene particle from a substrate , the process comprising: a first portion; and', 'a second portion comprising an aromatic moiety, the first portion being directly bonded to the silicate nanoparticle in the functionalized silicate nanoparticle;, 'contacting a silicate nanoparticle with a chemical group to form a functionalized silicate nanoparticle, the chemical group comprisingcontacting the asphaltene particle with the functionalized silicate nanoparticle, the asphaltene particle being disposed on the substrate;interposing the functionalized silicate nanoparticle between the asphaltene particle and the substrate; andseparating the asphaltene particle from the substrate with the functionalized silicate nanoparticle to remove the asphaltene particle from the substrate.2. The process of claim 1 , further comprising exfoliating the asphaltene particle ...

PRODUCTION-TREATING CHEMICALS ADDED TO POLYMER SLURRIES USED IN TREATMENT OF OIL AND GAS WELLS

Production-treating chemicals, such as paraffin inhibitors, corrosion inhibitors and scale inhibitors are provided along with water-soluble polymers in a base oil phase to be used in a well treatment. The mixture may be provided as a separate product or mixed at a well site when performing a well treatment, such as hydraulic fracturing, acidizing or gravel packing. 1. A method for treating a well with a production-treating chemical , comprising:adding the treating chemical to an oil phase along with a water-soluble polymer and forming a slurry of the water-soluble polymer in the oil phase;mixing the oil phase with a water phase to allow the water-soluble polymer to transfer to the water phase and form a gel in the water phase; andpumping the water phase and the oil phase into the well.2. The method of wherein the production-treating chemical is selected from the group consisting of those capable of addressing the effects caused by scale formation claim 1 , solid salt formation claim 1 , paraffin deposition claim 1 , emulsification claim 1 , gas hydrate formation claim 1 , corrosion claim 1 , asphaltene precipitation claim 1 , foam claim 1 , oxygen claim 1 , hydrogen sulfide and bacteria.3. The method of wherein the production-treating chemical is selected from the group consisting of an oil-soluble dispersion of amino tris(methylene phosphonic acid) claim 1 , organic phosphonates claim 1 , aminophosphonates claim 1 , phosphonates derived from alkyloxylated amines claim 1 , polymers and multi-polymers of acrylic acid claim 1 , methacrylic acid claim 1 , acrylamidomethylpropanesulfonic acid (AMPS) claim 1 , n-tert-butylacrylamide (NBA) claim 1 , hydroxypropylacrylate claim 1 , phosphinoacrylate claim 1 , sulfonate styrene claim 1 , ethylacrylate claim 1 , maleic anhydride claim 1 , phosphate esters claim 1 , carboxymethylinulin claim 1 , polyepoxysuccinic acid claim 1 , polyaspartic acid and mixtures of the same claim 1 , polymers and copolymers of olefin/maleic ...

Polymer dispersions for wax inhibition

The present invention relates to a process of a process for preparation of a polymer dispersion comprising a step (E) of free radical polymerization in an aqueous medium (M) in the presence of: at least a pre-polymer (pO) soluble in the medium (M), at least one free-radical polymerization initiator, and at least one ethylenically unsaturated hydrophobic monomer (m) which is chosen from an alkyl (meth)acrylate of at least C6, wherein the aqueous medium (M) includes water and at least one water miscible solvent.

ENZYMATIC COMPOSITIONS FOR THE DEGRADATION OF POLYMERS

Provided herein are compositions and methods for degrading polymer systems. These compositions and methods can be used to effectively degrade a range of polymers commonly used in oil and gas operations, including polymers with carbon-carbon backbones such as polyacrylamides. Further, these compositions and methods can simultaneously degrade other organic molecules and pollutants associated with oil and gas operations. The compositions and methods described herein employ reactants that are more environmentally-friendly than conventional methods and components used in, for example, polymer breaking processes. 1. A method for degrading a polymer within a subterranean formation , the method comprising:(a) providing a subterranean formation containing a polymer there within and a wellbore in fluid communication with the subterranean formation;(b) injecting a first composition comprising a peroxidase enzyme dissolved or dispersed in an aqueous carrier through the wellbore into the subterranean formation; and(c) injecting a peroxide through the wellbore into the subterranean formation.2. The method of claim 1 , wherein the polymer is deposited on a surface within the subterranean formation.3. The method of claim 2 , wherein the polymer deposited on the surface comprises a filter cake formed from a drilling fluid claim 2 , a drill-in fluid claim 2 , or a fracturing fluid.4. The method of claim 1 , wherein the polymer comprises a carbon-carbon backbone.5. The method of claim 1 , wherein the polymer comprises a biopolymer.6. The method of claim 5 , wherein the biopolymer comprises a polysaccharide.7. (canceled)8. (canceled)9. (canceled)10. The method of claim 1 , wherein the polymer comprises a polyacrylamide.11. The method of claim 10 , wherein the polyacrylamide comprises a polyacrylamide homopolymer or copolymer derived from acrylamide claim 10 , N-substituted hydrosoluble derivatives of acrylamide claim 10 , hydrosoluble N-vinylamides claim 10 , and combinations thereof. ...

CHEMICAL DEPLOYMENT MODULAR SYSTEM AND METHOD OF USE

A method of treating a wellbore comprises supporting a first tubular member in a housing; coupling a second tubular member to the first tubular member via a connector; the first tubular member, the second tubular member, or both comprising a chemical deployment modular device charged with a plurality of particulates preloaded with a well treatment additive; and deploying the first and second tubular members into the wellbore. 1. A method of treating a wellbore , the method comprising:supporting a first tubular member in a housing;coupling a second tubular member to the first tubular member via a connector;the first tubular member, the second tubular member, or both comprising a chemical deployment modular device charged with a plurality of particulates preloaded with a well treatment additive; anddeploying the first and second tubular members into the wellbore.2. The method of claim 1 , wherein the chemical deployment modular device comprises a tubular having a wall defining an interior space claim 1 , the wall having a perforated or slotted portion claim 1 , and the particulates are disposed in the interior space of the tubular between a first barrier and a second barrier.3. The method of claim 2 , wherein the chemical deployment modular device further comprises a screen radially outwardly disposed of the perforated or slotted portion of the pipe wall.4. The method of claim 1 , further comprising flowing a wellbore fluid about the plurality of the particulates to release the well treatment additive to the wellbore fluid.5. The method of claim 1 , further comprising recharging the plurality of the particulates with an additional well treatment additive.6. The method of claim 5 , wherein recharging the plurality of the particulates comprises circulating a treatment fluid comprising the additional well treatment additive in the wellbore.7. The method of claim 1 , wherein the chemical deployment modular device is deployed into a live well or a dead well.8. The method ...

Method and Composition for Drag Reduction and Treatment of Paraffin Deposits in Oil and Gas Infrastructure

A drag reducing composition and method of use wherein the drag reducing composition comprises a drag reducing surfactant and a solvent mixture that improves flow of fluid by reducing friction losses in a transport conduit while simultaneously cleaning the undesirable wax deposits from the conduit. The drag reducing additives of the invention are not subject to sheer degradation and are substantially useful in reducing drag in hydrocarbon fluids without compromised efficacy downstream from the injection site due to the molecules' ability to self-repair. 1. An aqueous drag reducing composition comprising:a drag reducing agent formed from an aqueous surfactant mixture containing a high molecular weight;a suspending aqueous medium, said suspending aqueous medium comprising a solvent mixture formed from an aromatic hydrocarbon solvent and a linear alkane hydrocarbon.2. The composition of claim 1 , wherein said drag reducing surfactant mixture is present in an amount of from about 10-20% by weight.3. The composition of claim 1 , wherein said surfactant mixture comprises Ethyl Alcohol in an amount from about 1-5% of the surfactant composition.4. The composition of claim 1 , wherein said surfactant mixture comprises Alcohol Ethoxysulfate in an amount from about 10-30% of surfactant composition.5. The composition of claim 1 , wherein said surfactant mixture comprises Alcohol Sulfate in an amount from about 10-30% of surfactant composition.6. The composition of claim 1 , wherein said surfactant mixture comprises Amines claim 1 , C10-16 alkyldimethyl claim 1 , N-oxides in an amount from about 1-5% of surfactant composition.7. The composition of claim 1 , wherein said solvent mixture comprises Heptane in an amount from about 50-70% of solvent composition.8. The composition of claim 1 , wherein said solvent mixture comprises Toluene in an amount from about 20-40% of solvent composition.9. A method of reducing drag in a flowing hydrocarbon stream comprising introducing into said ...

Composition and method for dispersing paraffins in crude oils

A composition of co-polymers, surfactants and solvents is provided for use in methods of reducing paraffin and wax deposition from crude oils in storage and transportation vessels.

Low molecular weight polyacrylates for eor

The disclosure is directed to low molecular weight polyelectrolyte complex nanoparticles that can be used to deliver agents deep into hydrocarbon reservoirs. Methods of making and using said polyelectrolyte complex nanoparticles are also provided.

Compositions and Methods for Treatment of Well Bore Tar

Of the many compositions and methods provided herein, one method includes contacting tar resident in a well bore with a tar stabilizer comprising an acrylonitrile-butadiene copolymer; and allowing the tar stabilizer to interact with the tar to at least partially reduce the tendency of the tar to adhere to a surface. 1. A well bore treatment fluid comprising:an aqueous fluid; andan acrylonitrile-butadiene copolymer.2. The fluid of claim 1 , wherein the acrylonitrile-butadiene copolymer is carboxylated.3. The fluid of claim 1 , wherein the acrylonitrile-butadiene copolymer further comprises a styrene.4. The fluid of claim 3 , wherein the acrylonitrile-butadiene copolymer comprises an additional monomer in an amount of less than about 1% by weight.5. The fluid of claim 1 , wherein the acrylonitrile-butadiene copolymer comprises acrylonitrile in an amount of about 50% to about 95% by weight of the copolymer claim 1 , butadiene in an amount of about 5% to about 50% by weight of the copolymer claim 1 , and styrene in an amount up to about 25% by weight of the copolymer.6. The fluid of claim 1 , wherein the acrylonitrile-butadiene copolymer is an emulsion-polymerized acrylonitrile-butadiene copolymer.7. The fluid of claim 1 , wherein the acrylonitrile-butadiene copolymer comprises a copolymer of acrylonitrile and butadiene claim 1 , wherein the acrylonitrile is substituted with at least one group selected from the group consisting of a chloro group claim 1 , a bromo group claim 1 , a fluoro group claim 1 , an akyl group claim 1 , an alkoxy group claim 1 , an alkenyl group claim 1 , an alkynyl group claim 1 , and an aryl group.8. The fluid of claim 1 , wherein the acrylonitrile-butadiene copolymer comprises a copolymer of acrylonitrile and butadiene claim 1 , wherein the butadiene is substituted with at least one group selected from the group consisting of a chloro group claim 1 , a bromo group claim 1 , a fluoro group claim 1 , an akyl group claim 1 , an alkoxy group claim ...

METHOD OF CONTROLLING GAS HYDRATES IN FLUID SYSTEMS

A method of inhibiting hydrates in a fluid comprising water and gas comprising adding to the fluid an effective hydrate-inhibiting amount of a composition comprising one or more co-polymers of N-alkyl (alkyl)acrylamide monomers and one or more cationic monomers selected from acid and alkyl chloride quaternary salts of N,N-dialkylaminoalkyl (meth)acrylates and N,N-dialkylaminoalkyl (meth)acrylamides. 113-. (canceled)14. A method of inhibiting hydrate formation in a fluid comprising water , gas and optionally liquid hydrocarbon comprising treating the fluid with an effective hydrate-inhibiting amount of an inhibitor composition comprising a cationic copolymer derived by polymerization of about 75 to about 99.9 mole percent of N-alkyl alkylacrylamide or N-alkyl acrylamide monomer units and about 0.1 to about 25 mole percent of alkylacrylamidoalkyltrialkylammonium chloride or acrylamidoalkyltrialkylammonium chloride monomer units.15. The method of claim 14 , wherein polymerization of said cationic copolymer is initiated by redox decomposition of a peroxide with a redox co-catalyst claim 14 ,16. The method of claim 14 , wherein said cationic copolymer has a molecular weight distribution of about 60-100 percent in the range of 1 claim 14 ,000 to 20 claim 14 ,000 Daltons and 0-25 percent in the range from 20 claim 14 ,000 to 6 claim 14 ,000 claim 14 ,000 Daltons.17. The method of claim 14 , wherein said inhibitor composition further comprises a hydroxyl-containing compound selected from the group consisting of a low molecular weight alcohol claim 14 , a low molecular weight glycol claim 14 , a low molecular weight glycol ether claim 14 , and combinations thereof.18. The method of claim 17 , wherein said hydroxyl-containing compound is selected from the group consisting of isopropanol; 1 claim 17 ,1 claim 17 ,1-tris(hydroxymethyl) propane; triethylene glycol dimethyl ether; diethylene glycol dimethyl ether; 2-ethoxyethanol; diethylene glycol monomethyl ether; ethylene ...

BIODEGRADABLE NON-ACIDIC OIL-IN-WATER NANOEMULSION

Formulation for a natural product as a replacement for the use of traditional acidic chemical stimulation methods for the emulsification, removal and release of paraffin and asphaltenes from low producing or pumped off wells and reservoirs with the use of traditional methodologies. Also a method of use of formulation for stimulating an oil well consisting of introducing into the wellbore a biodegradable, non-reactive fluid system containing a water-miscible fatty acid solvent, a solution of fatty acids, an amino alcohol, and at least one non-ionic surfactant. The fluid system may be further in the form of a nanoemulsion that is formed by combining a colloidal solution with one or more emulsifiers, an alcohol, and water. The fluid system may be used in well remediation and stimulation as well as additional, alternative applications such as the cleaning of surface and/or downhole equipment. 1. A biodegradable , non-acidic , oil-in-water nanoemulsion comprising(a) A micellar solution of fatty acids;(b) a water-soluble organic solvent, wherein the water soluble organic solvent is an alcohol;(c) an emulsifier;(d) at least one non-ionic surfactant and(e) water;(f) wherein the nanoemulsion has an average droplet size from about 5 nm to about 50 nm in diameter, and(g) wherein the nanoemulsion disperses and removes paraffin, asphaltenes deposits, sulfur, pipe dope and hydrocarbons.2. The nanoemulsion according to wherein the at least one fatty acid is a C8-C20 fatty acid.3. The nanoemulsion according to wherein the C8-C20 fatty acid is derived from coconut oil.4. The nanoemulsion according to wherein the emulsifier is an octyl phenol ethoxylate having an HLB value greater than 13.5.5. The nanoemulsion according to wherein the at least one nonionic surfactant is an alkylaryl polyether alcohol.6. The nanoemulsion according to wherein the at least one additional nonionic surfactant is a C9-C11 alkyl polyglucoside.7. The nanoemulsion according to wherein the fluid composition is ...

BIO-DERIVED COMPLEX FOR OIL AND GAS WELL REMEDIATION

The present invention relates to a method for oil and gas well remediation by the creation and use of a bio-derived nano scale complex mixtures, comprising bio-derived solvents and/or surfactants that allows the breaking, dissolving, dispersing and caging of obstructions in oil and gas wells. The charge present on the bio derived nanoscale complex is based on the pH of the well. The invention further reduces the well obstructions to a free-flowing fluid and then encapsulates them in an electrochemical, spherical, globe of protection. The method efficiently removes obstructions from the well to be treated. 1. A method of treating a well comprising:(a) Measuring pH of the well to be treated;(b) Dissolving and breaking down an obstruction(s) to their lowest energy form, a sphere, using a bio-derived nano scale complex;wherein the bio-derived nanoscale complex is cationic charged when the pH of the well is less than 7; andwherein the bio-derived nanoscale complex is anionic charged when the pH of the well is greater than 7.(c) Dispersing said spheres obtained in step (b) to obtain a flowing sphere(s) of dissolved obstructions;wherein said dispersing is a two-step process comprising(i) flowing of a collection of spheres due to an electrostatic action of a bio-surfactant(s); and(ii) keeping undesirable spheres from agglomerating by negative attractions of the bio-surfactant(s), while the spheres are swept away from well perforations; and(d) Caging the flowing spheres of dissolved obstructions to obtain a segregated cage(s) and sweeping the segregated cage(s) of obstructions to the surface of the well for disposal.2. The method of claim 1 , wherein the obstructions are selected from light hydrocarbon condensates claim 1 , paraffin and asphaltene.3. The method of claim 1 , wherein the obstructions are mineral scales.4. The method of claim 1 , wherein the bio-derived nano-scale complex comprises a first solvent claim 1 , a second solvent claim 1 , a bio-surfactant(s) and an ...

WATER-BASED DRILLING FLUID FOR REDUCING BITUMEN ACCRETION

A drilling fluid for reducing bitumen accretion to wellbore drilling components is provided. The drilling fluid includes an anti-accretion additive including a soluble polyamino acid. In various embodiments, the soluble polyamino acid is an alkali metal salt of a polyamino acid, an example being sodium salt of polyaspartic acid. Further, the drilling fluid may be an aqueous-based drilling fluid. The soluble polyamino acid may alternatively or additionally include one or more of a homo-polymer of amino acids, a sequential co-polymer of amino acids, or a random co-polymer of amino acids. The drilling fluids may be used in a method for reducing bitumen accretion to wellbore drilling components. 1. A drilling fluid for reducing bitumen accretion to wellbore drilling components , comprising an anti-accretion additive , the anti-accretion additive comprising a soluble polyamino acid.2. The drilling fluid of claim 1 , wherein the soluble polyamino acid is an alkali metal salt of a polyamino acid.3. The drilling fluid of claim 1 , wherein the drilling fluid is an aqueous-based drilling fluid.4. The drilling fluid of claim 1 , wherein the soluble polyamino acid comprises one or more of a homo-polymer of amino acids claim 1 , a sequential co-polymer of amino acids claim 1 , or a random co-polymer of amino acids.5. The drilling fluid of claim 1 , wherein the soluble polyamino acid is sodium salt of polyaspartic acid.6. The drilling fluid of claim 1 , wherein the molecular weight of the soluble polyamino acid is from about 500 to about 50 claim 1 ,000 Dalton.7. The drilling fluid of claim 6 , wherein the molecular weight of the soluble polyamino acid is from about 500 to about 25 claim 6 ,000 Dalton.8. The drilling fluid of claim 6 , wherein the molecular weight of the soluble polyamino acid is from about 1 claim 6 ,000 to about 5 claim 6 ,000 Dalton.9. The drilling fluid of claim 1 , wherein the soluble polyamino is present in an amount of from about 0.05 to about 25% by ...

COMPOSITE PROPPANT, METHOD FOR PRODUCING A COMPOSITE PROPPANT AND METHODS FOR THE USE THEREOF

The disclosure relates to the oil and gas industry, in particular, to a composite proppant modified by a polymeric carrier for the purpose of improving transport properties and delayed release of inhibitors from proppant. A composite proppant is provided which comprises at least one solid particle attached to at least one polymeric carrier facilitating a decrease in the composite proppant settling rate, where the polymeric carrier comprises inclusions of at least one inhibitor for inorganic or organic scales. The disclosure also relates to a method for manufacturing of such composite proppant and methods for using the same during hydraulic fracturing of a subterranean formation, and for treatment of organic fossils during downhole production after hydraulic fracturing of subterranean formation. 1. The composite proppant comprising at least one solid particle attached to at least one polymeric carrier facilitating a decrease in the composite proppant settling rate , wherein the polymeric carrier comprises inclusions of at least one inhibitor for inorganic or organic scales.2. The proppant of claim 1 , wherein the hydrodynamic radius of composite proppant in fluid is greater as compared to the hydrodynamic radius of a separate solid particle.3. The proppant of claim 1 , wherein sand claim 1 , ceramic proppant or polymer-coated proppant is used as a solid particle.4. The proppant of claim 1 , wherein at least one solid particle is attached to one polymeric carrier.5. (canceled)6. The proppant of claim 1 , wherein at least one solid particle is attached to two polymeric carriers.7. (canceled)8. The proppant of claim 1 , wherein the polymeric carrier has a shape selected from the group: disks claim 1 , plates claim 1 , stripes claim 1 , spirals claim 1 , bundles of fibers claim 1 , fragments of network and fragments of film claim 1 , or another shape differing from the spherical shape.9. The proppant of claim 1 , wherein the polymeric carrier comprises a soluble and/or ...