СПОСОБ ПОЛУЧЕНИЯ УГЛЕВОДОРОДНОЙ ОСНОВЫ БУРОВЫХ РАСТВОРОВ С УЛУЧШЕННЫМИ ЭКСПЛУАТАЦИОННЫМИ СВОЙСТВАМИ

Изобретение относится к производству углеводородной основы для получения буровых растворов УОБР. Технический результат - расширение сырьевой базы и технологических решений для производства УОБР, улучшение эксплуатационных свойств УОРБ. Способ получения УОБР включает приготовление смеси утяжеленных среднедистиллятных фракций атмосферно-вакуумной перегонки нефти, каталитического крекинга и замедленного коксования, каталитическое гидрирование указанной смеси, защелачивание полученного гидрогенизата гидрирования для достижения содержания серы в конечном продукте до уровня не более 0,001 мас.%, ректификацию полученного гидрогенизата, каталитический гидрокрекинг вакуумного газойля, получаемого при перегонке мазута, ректификацию полученного гидрогенизата каталитического гидрокрекинга. Каталитическое гидрирование смеси утяжеленных среднедистиллятных фракций атмосферно-вакуумной перегонки нефти, каталитического крекинга и замедленного коксования осуществляют при давлении 20,0-32,0 МПа, температуре ...

ЭМУЛЬСИЯ ДЛЯ ГИДРОРАЗРЫВА ПЛАСТА

Группа изобретений относится к снижению трения жидкости для гидроразрыва в операции гидроразрыва пласта. Технический результат - снижение трения в условиях сильной солености с высоким содержанием двухвалентных солей. Обратная эмульсия «вода-в-масле» для снижения трения жидкости для гидроразрыва пласта содержит масло; воду; по меньшей мере один водорастворимый анионный полимер со средней молекулярной массой более 3 миллионов дальтон, содержащий от 4 до 14 мол.% сульфированных анионных мономеров, от 0 до 17 мол.% карбоксилированных анионных мономеров и от 69 до 96 мол.% неионных мономеров; по меньшей мере один инвертирующий агент и по меньшей мере один эмульгирующий агент, причем массовое отношение R между общим количеством инвертирующего агента и общим количеством эмульгирующего агента выше 1,8. Инвертирующий агент выбирают из этоксилированного нонилфенола; этоксилированного/пропоксилированного спирта; этоксилированного тридецилового спирта и этоксилированного/пропоксилированного жирного ...

ПЕНОГАСЯЩАЯ КОМПОЗИЦИЯ И СПОСОБ ЦЕМЕНТИРОВАНИЯ В ПОДЗЕМНОЙ ФОРМАЦИИ

Изобретение относится к цементным композициям и способам снижения захвата воздуха в цементных композициях. Способ снижения захвата воздуха в цементной композиции, включающий: (a) добавление пеногасящей композиции к цементной композиции, где пеногасящая композиция содержит эфир органической кислоты и полиоксиэтилен-полиоксипропиленового блоксополимера; (b) смешивание пеногасящей композиции и цементной композиции с образованием смеси; и (c) оставление смеси для схватывания с получением твердого цемента; где пеногасящая композиция способствует снижению захвата воздуха в цементной композиции по сравнению с цементной композицией, не содержащей пеногасящую композицию; где эфир органической кислоты и полиоксиэтилен-полиоксипропиленового блоксополимера представляет собой продукт реакции диэтерификации полиоксиэтилен-полиоксипропиленового блоксополимера и органической кислоты, выбранной из группы, состоящей из олеиновой кислоты, стеариновой кислоты, субериновой кислоты, азелаиновой кислоты, себациновой ...

СМАЗЫВАЮЩИЕ КОМПОЗИЦИИ ДЛЯ ПРИМЕНЕНИЯ В СКВАЖИННЫХ ФЛЮИДАХ

Группа изобретений относится к смазкам, применяемым в скважинных флюидах. Технический результат – улучшение смазывания металлических поверхностей с целью снижения трения, скручивающих и осевых нагрузок. Способ включает циркуляцию скважинного флюида в стволе скважины подземного пласта, причем скважинный флюид выбирают из группы, состоящей из флюида для внутрискважинных работ, бурового флюида, флюида для заканчивания скважины, флюида для гидроразрыва пласта, флюида для вскрытия пласта, ремонтной жидкости и их комбинации. Скважинный флюид необязательно содержит соль, выбранную из группы, состоящей из хлорида натрия, хлорида кальция, хлорида цинка, хлорида калия, бромида калия, бромида натрия, бромида кальция, бромида цинка, формиата натрия, формиата калия, формиата аммония, формиата цезия и их смеси. В скважинный флюид добавляют смазку смазывания поверхности. Смазка включает хлорид холина и сульфированное растительное масло, причем смазка увеличивает смазывающую способность флюида по сравнению ...

ПРОТИВОТУРБУЛЕНТНАЯ ПРИСАДКА ДЛЯ БУРОВЫХ РАСТВОРОВ

Изобретение относится к добавкам для снижения гидродинамического сопротивления жидкости в условиях развитой турбулентности потока, в частности, при прокачке буровых растворов в процессе бурения нефтяных и газовых скважин. Технический результат - высокая эффективность, обеспечение снижения гидродинамического сопротивления жидкости в турбулентном потоке не менее чем на 60% в сравнении с исходным модельным буровым раствором при повышенной температуре до 180°C, при кислотности среды до рН 1,65, при минерализации раствора до 7,0 мас.% по CaCl. Противотурбулентная присадка для снижения гидродинамического сопротивления бурового раствора на водной среде представляет собой трехкомпонентный акрилатный сополимер с молекулярной массой более 2,5⋅10Да, состоящий из мономеров нитрила акриловой кислоты, натриевой соли 2-акриламидо-2-метилпропансульфоновой кислоты и акриламида при следующем соотношении компонентов, мас.%: нитрил акриловой кислоты 8-12; Na-2-акриламидо-2-метилпропансульфоновой кислоты 43 ...

СМЕСИ, СОДЕРЖАЩИЕ ОЛИГОМЕРНЫЕ ИЛИ ПОЛИМЕРНЫЕ СОЕДИНЕНИЯ, ИХ ПОЛУЧЕНИЕ И ПРИМЕНЕНИЕ

Изобретение относится к области строительных материалов. Смесь, пригодная для использования в качестве добавки к строительным материалам, содержит:(A) по меньшей мере одно гидравлическое связующее средство или латентное гидравлическое связующее средство;(B) по меньшей мере один сополимер, получаемый путем превращения:(α1) по меньшей мере одного этиленненасыщенного сомономера по меньшей мере с одной функциональной группой, выбранной из СООН-групп, сульфокислотных групп, нитрильных групп, гидроксиалкильных групп и аминогрупп; с(β) по меньшей мере одним олигомерным или полимерным соединением, получаемым путем превращения:(a) по меньшей мере одной этиленненасыщенной дикарбоновой или поликарбоновой кислоты или ее ангидрида или сложного эфира; с(b) по меньшей мере одним по меньшей мере трифункциональным спиртом; и(c) по меньшей мере одним соединением общей формулы I:,в которой Rвыбран из алкила с 1-4 атомами углерода, А является одинаковым или разным и выбран из алкиленов с 2-6 атомами углерода ...

СПОСОБ ПОВЫШЕНИЯ ПОДВИЖНОСТИ ТЯЖЕЛОЙ СЫРОЙ НЕФТИ В ПОДЗЕМНЫХ ПЛАСТАХ

Группа изобретений относится к добыче сырой нефти. Технический результат - улучшение подвижности тяжелой сырой нефти в подземном пласте. Способ улучшения подвижности тяжелой сырой нефти в пористом подземном пласте включает введение в пласт жидкого состава, содержащего воду, поверхностно-активное вещество и совместный растворитель, и образование в пласте по меньшей мере одного из: эмульсии и дисперсии, причем эмульсия или дисперсия имеет воду в качестве внешней фазы и тяжелую сырую нефть в качестве внутренней фазы. Поверхностно-активное вещество представляет собой неионогенное соединение и содержит 20-30% метанола или 5-10% 2-бутоксиэтанола. Поверхностно-активное вещество в комбинации с совместным растворителем имеет гидрофильно-липофильный баланс более 10. Совместный растворитель содержит простой эфир гликоля. Жидкий состав дополнительно содержит эмульгатор, противотурбулентную присадку, содержащую этоксилированное поверхностно-активное вещество, и линкер. Линкер представляет собой гликоль ...

ЗАГУСТИТЕЛЬ ВОДНОГО РАСТВОРА КИСЛОТЫ, СПОСОБ ЗАГУЩЕНИЯ ВОДНОГО РАСТВОРА КИСЛОТЫ И СПОСОБ ДОБЫЧИ НЕФТИ С ПРИМЕНЕНИЕМ УКАЗАННОГО ЗАГУСТИТЕЛЯ, НАБОР КОМПОНЕНТОВ ДЛЯ ЗАГУЩЕНИЯ ВОДНОГО РАСТВОРА КИСЛОТЫ И КОМПОЗИЦИЯ ДЛЯ ОСУЩЕСТВЛЕНИЯ КИСЛОТНОГО ГИДРАВЛИЧЕСКОГО РАЗРЫВА ПЛАСТА, ВКЛЮЧАЮЩИЕ УКАЗАННЫЙ ЗАГУСТИТЕЛЬ

Группа изобретений относится к загущению растворов кислот и применению загушенных растворов кислот для гидравлического разрыва пласта. Технический результат – повышение эффективности переноса пропанта, повышение эффективности извлечения углеводородов из пласта, использование для обработки одной рабочей жидкости – кислотного геля, в случае необходимости содержащей пропант. Для загущения водного раствора кислоты применяют комбинацию а) полиэтоксилированного таллового амина формулы,где m и n = 2 и R представляет собой остаток жирной кислоты, выбранной из группы, состоящей из олеиновой, пальмитиновой, стеариновой, миристиновой или линолевой кислоты; б) соединения, выбранного из группы, состоящей из: четвертичной аммониевой соли формулы,где R представляет собой насыщенный, моно-, ди- или три-ненасыщенный углеводородный радикал С; Rпредставляет собой водород, метил, этил, пропил, изопропил, аллил, винил, фенил и бензил; R, R, R, Rнезависимо представляют собой водород, метил, этил, пропил, изопропил ...

ОРГАНИЧЕСКИЙ ИНГИБИТОР ГЛИН ДЛЯ БУРОВЫХ РАСТВОРОВ

Изобретение относится к бурению нефтяных, газовых и геологоразведочных скважин, а именно к органическим ингибиторам глин для буровых растворов. Технический результат - повышенине устойчивости глинистых минералов к гидратации и диспергируемости при бурении буровыми растворами на водной основе, предотвращение сальникообразования, снижение коллоидной фазы и повышение смазочных и противоприхватных свойств. Органический ингибитор глин для буровых растворов содержит смазочную добавку ФК-2000 Плюс, состоящую из жирных кислот триглицеридов подсолнечного, кукурузного, соевого, рапсового масла с числом углеродных атомов от 14 до 24 в количестве 50-80 мас.%, нейтрализующего агента в количестве 3-6 мас.%, полиэтиленгликолевого эфира моноизононилфенола с 6-12 мономерными звеньями в радикале в количестве 5-30 мас.% и воды остальное, Дипроксамин 157 и смесь растительных и минеральных масел в соотношении от 1:1 до 1:9 при следующем соотношении ингредиентов, мас.%: смазочная добавка ФК-2000 Плюс 4-8; Дипроксамин ...

АГЛОМЕРИРУЮЩИЕ ПОЛИМЕРНЫЕ КОМПОЗИЦИИ, МОДИФИЦИРОВАННЫЕ ТВЕРДЫЕ МАТЕРИАЛЫ И СПОСОБЫ ИХ ПОЛУЧЕНИЯ И ПРИМЕНЕНИЯ

Изобретение относится к агрегирующим композициям для обработки подземного пласта и скважинных флюидов. Способ изменения характеристик самоагрегации и/или способности к агрегации у частиц, поверхностей и/или материалов для внутрискважинного применения включает приведение частиц, поверхностей и/или материалов в контакт с агрегирующей композицией, содержащей хитозаны, полипептиды, содержащие по меньшей мере одну аминокислоту, выбранную из группы, состоящей из лизина, триптофана, гистидина, аргинина, аспарагина, глутамина и их смесей и комбинаций, протеинсодержащие желатины и их смеси или комбинации, где указанная композиция образует частичное, по существу сплошное и/или сплошное покрытие на указанных частицах, поверхностях и/или материалах, изменяя их характеристики самоагрегации и/или способность к агрегации. Способ контролирования пескопроявления или попадания мелких частиц в скважину включает закачивание в пласт жидкости с определенной скоростью и определенным давлением для контролирования ...

РЕЦЕПТУРЫ РЕГУЛИРОВАНИЯ ВСПЕНИВАНИЯ

Настоящее изобретение относится к рецептурам регулирования вспенивания для предотвращения или снижения вспенивания и к применению таких рецептур для предотвращения или снижения вспенивания в текучих средах, таких как водные текучие среды и особенно в применениях в нефтяном промысле. Рецептура регулирования вспенивания в форме микроэмульсии содержит: (а) от 5 до 70% мас./мас. главного поверхностно-активного вещества, где указанное поверхностно-активное вещество имеет ГЛБ от 1 до 12 и/или температуру помутнения от 20 до 70°C; (b) от 2 до 40% мас./мас. водонерастворимого органического жидкого носителя, содержащего масло и модификатор вязкости, выбранный из эфиров двухосновной кислоты, эфиров жирной кислоты и их смесей; и (с) воду. Технический результат: стабильность и простота использования рецептуры, которые являются очень эффективными пеногасителями и хорошими противовспенивателями. 5 н. и 16 з.п. ф-лы, 12 табл.

Способ получения реагента для глинистых буровых растворов

Изобретение относится к области бурения нефтяных и газовых скважин, в частности к реагентам для химической обработки глинистых буровых растворов. Технический результат - эффективное снижение показателей условной вязкости в условиях температурной агрессии. Способ получения реагента для глинистых буровых растворов включает модифицирование 50%-ного водного раствора лигносульфоната натрия с последующим высушиванием. Причем модифицирование проводят в две стадии: на первой стадии сульфированным компонентом при температуре 60°С в течение 1 ч, на второй - 50%-ным водным раствором полифосфата аммония при температуре 50°С в течение 1 ч, а исходные компоненты используют при следующем соотношении, мас.%: 50%-ный водный раствор лигносульфоната натрия 95; сульфированный компонент 3; 50%-ный водный раствор полифосфата аммония 2. Используемый сульфированный компонент получают путем сульфирования при температуре 80°С в течение 1,5 ч смеси тяжелых нефтяных остатков нефтепереработки с суммарным содержанием ...

СМАЗОЧНАЯ ДОБАВКА ДЛЯ БУРОВОГО РАСТВОРА

Настоящее изобретение относится к смазочным композициям для буровых растворов, применяемым в операциях бурения. Технический результат – высокие смазочные и противосальные свойства смазочной добавки, образование устойчивой пленки на поверхности металла. Смазочная добавка для бурового раствора содержит, мас.%: жидкий углеводородный компонент - отработанное моторное масло 85–87,27; жирные кислоты растительных масел до 3; олеиновую кислоту 0,2–0,8; депрессорную присадку 0,03–0,05; стеариновую кислоту 2,5; смесь триэтаноламина с моноэтаноламином и/или диэтаноламином 8,0–8,6; оксиэтилированный алкилфенол 2. В смазочной добавке используют жирные кислоты растительных масел с кислотным числом не ниже 180 ед. 6 табл.

СПОСОБ ПОЛУЧЕНИЯ МНОГОФУНКЦИОНАЛЬНОЙ ДОБАВКИ ДЛЯ ВОДНЫХ БУРОВЫХ РАСТВОРОВ

Изобретение относится к области бурения нефтяных, газовых и геологоразведочных скважин, а именно к получению добавок для буровых растворов. Технический результат - придание буровым растворам высоких смазочных, антиприхватных, ингибирующих и антикоррозионных свойств при снижении эффективной рабочей концентрации добавки. В способе получения многофункциональной добавки для водных буровых растворов вначале получают продукт, содержащий метиловые эфиры жирных кислот растительных масел, - масложировую фракцию путем двухэтапной реакции этерификации. На первом этапе смешивают соапсток растительных масел - дистиллированные жирные кислоты растительных масел, у которых кислотное число составляет 185-205 мг KOH/г, с метанолом при их мольном соотношении 1:2 соответственно, проводят реакцию в течение 6 ч при температуре 130°С и давлении 8-9 атм с последующей отгонкой воды и метанола и отделением продукта реакции. Осуществляют отбор для второго этапа реакции этерификации продукта реакции с кислотным числом ...

АНТИФРИКЦИОННЫЕ ПРИСАДКИ

Группа изобретений относится к снижению гидравлического сопротивления углеводородных флюидов, протекающих по трубопроводу. Технический результат – уменьшение энергии, необходимой для транспортировки углеводородных флюидов, и увеличение пропускной способности трубопроводов за счет высокой концентрации полиальфаолефинов в антифрикционных присадках, легкость получения и транспортировки антифрикционных присадок, длительные сроки хранения антифрикционных присадкок при широком диапазоне температур хранения. Антифрикционная композиция для снижения гидравлического сопротивления углеводородных флюидов, протекающих по каналу, содержит по крайней мере один герметизированный временный контейнер; по крайней мере одну антифрикционную присадку и до 20 мас.% диспергирующего флюида, расположенные в герметизированном временном контейнере, причем массовый процент представлен в расчете на общую массу антифрикционной композиции, включающую и массу герметизированного временного контейнера. Антифрикционная присадка ...

БУРОВОЙ РАСТВОР НА ПОЛИМЕРНОЙ ОСНОВЕ ДЛЯ СТРОИТЕЛЬСТВА СКВАЖИН

Изобретение относится к бурению нефтяных и газовых скважин, а именно к безглинистым биополимерным буровым растворам, применяемым для вскрытия продуктивных пластов горизонтальных скважин и скважин с большим углом отклонения, представленных карбонатными и терригенными (песчаниками) коллекторами, а также для восстановления скважин бурением вторых стволов в различных гидрогеологических условиях. Технический результат - сохранение фильтрационно-емкостных свойств продуктивных коллекторов, снижение затрат пластовой энергии на движение флюидов с использованием биоразлагаемых полимеров и легко удалимых кольматантов. Буровой раствор на полимерной основе для строительства скважин содержит, мас.%: биополимер ксантанового типа марки xanthan gum FCC IV 0,15-0,22; модифицированный крахмал марки МК-Ф1 или МК-Б 1,8-2,5; кальцинированную и/или каустическую соду 0,1-0,2; карбонат кальция 3-10; хлорид калия или углекислый калий, или формиат натрия, или хлорид натрия 3-23; поверхностно-активное вещество ОП- ...

Смазочная добавка для буровых растворов

Изобретение относится к нефтедобывающей промышленности, а именно к смазочным добавкам для обработки буровых растворов, в том числе утяжеленных. Технический результат - повышение смазочной способности смазочной добавки для буровых растворов. Смазочная добавка для буровых растворов содержит исходные компоненты в следующем соотношении, мас.%: битуминозная нефть 30-40; стабилизирующая добавка 15-20; керосин 40-55. Причем стабилизирующая добавка состоит из смеси пальмоядрового масла, водного экстракта плодов мыльного ореха и карданола, взятых в соотношении 0,5:1,0:1,0. 1 табл., 3 пр.

ЖИДКОСТЬ ГИДРОРАЗРЫВА И СПОСОБ ОБРАБОТКИ УГЛЕВОДОРОДНОГО ПЛАСТА

Изобретение относится к обработке углеводородных пластов. Способ гидравлического разрыва подземного пласта (ГРПП) с проходящим через него стволом скважины, включающий получение композиции гидроразрыва, содержащей флюид-носитель и компонент сверхвпитывающего полимера (СВП), содержащего один или более из: первый композит проппанта и первый СВП в негидратированной форме, где первый СВП по меньшей мере частично внедрен в свободное пространство проппанта, или покрытый СВП, и закачивание этой композиции в подземный пласт для создания или увеличения трещины. Способ указанного ГРПП, включающий получение композиции гидроразрыва, содержащей флюид-носитель, проппант, от около 10 фунтов (4,536 кг) до около 100 фунтов (45,359 кг) СВП на тысячу гал (3785 л) композиции и от около 1 фунта (0,454 кг) до около 30 фунтов (13,608 кг) модификатора вязкости на тысячу гал (3785 л) композиции, где модификатор вязкости содержит сульфированный полистирол (СПС), и закачивание этой композиции в подземный пласт для ...

СПОСОБ ПОЛУЧЕНИЯ ЛИГНОСУЛЬФОНАТНОГО РЕАГЕНТА ДЛЯ ОБРАБОТКИ БУРОВОГО РАСТВОРА

Изобретение относится к нефтяной и газовой промышленности, а именно к производству химических реагентов для обработки буровых растворов. Технический результат - усиление влияния лигносульфонатного реагента на фильтрацию и структурно-механические свойства глинистых растворов. Способ получения лигносульфонатного реагента для обработки бурового раствора, включающий нагревание при перемешивании лигносульфоната, формалина, конденсацию лигносульфоната с формалином с последующей нейтрализацией смеси едким натром, отличающийся тем, что предварительно лигносульфонат смешивают с этидроновой кислотой в количестве 10% от веса лигносульфоната в пересчете на моногидрат, смесь перемешивают, нагревают до 60-70°С, добавляют 3%-ный формалин в количестве 2,4% от веса лигносульфоната в пересчете на безводный формальдегид. 3 табл.

ТЕРМОСТОЙКИЙ КАТИОННЫЙ БУРОВОЙ РАСТВОР

Изобретение относится к буровым растворам на водной основе и может найти применение при бурении нефтяных и газовых скважин, преимущественно при бурении неустойчивых глинистых пород в терригенных и солевых отложениях в условиях воздействия высоких температур до 200°С. Технический результат изобретения - повышение крепящих свойств раствора и сохранение устойчивости (целостности) стенок ствола скважины при одновременном увеличении ингибирующих свойств раствора. Катионный буровой раствор включает мас.%: глинопорошок 3-5; полидадмах 1,75-3,50; катионный полимер Росфлок КФ 0,5-2; поливинилпирролидон 0,3-3,0; воду остальное. 1 ил., 3 табл.

СКВАЖИННЫЕ ФЛЮИДЫ И СПОСОБ ИХ ПРИМЕНЕНИЯ

... 1. Базовая текучая среда для получения скважинных флюидов, содержащая:смесь синтетических алифатических углеводородов, полученную из потока продуктов синтеза Фишера-Тропша и содержащую более 96% алифатических углеводородов с числом атомов углерода от C6 до C30, при этом доля гомологов с числом атомов углерода C10 и ниже составляет меньше чем примерно 3 масс.%, где указанная текучая среда обладает коэффициентом смазывающей способности равным 0,17 и менее и где коэффициент смазывающей способности определяется как коэффициент трения металлического кольца, вращающегося в базовой текучей среде при 60 об/мин о поверхность из твердого металла при 150 psi.2. Базовая текучая среда по п. 1, в которой доля гомологов с числом атомов углерода C9 и ниже составляет меньше чем примерно 0,35 масс.%.3. Базовая текучая среда по п. 1, в которой доля гомологов с числом атомов углерода C9 и ниже составляет меньше чем примерно 0,2 масс.%.4. Базовая текучая среда по п. 1, в которой доля гомологов с числом атомов ...

ОРГАНИЧЕСКИЙ ИНГИБИТОР ГЛИН ДЛЯ БУРОВЫХ РАСТВОРОВ

... 1. Органический ингибитор глин для буровых растворов, характеризующийся тем, что содержит смазочную добавку ФК-2000 Плюс, состоящую из жирных кислот триглицеридов подсолнечного, кукурузного, соевого, рапсового масла с числом углеродных атомов от 14 до 24 в количестве 50-80 мас.%, нейтрализующего агента в количестве 3-6 мас.%, полиэтиленгликолевого эфира моноизононилфенола с 6-12 мономерными звеньями в радикале в количестве 5-30 мас.% и воды - остальное, Дипроксамин 157 и смесь растительных и минеральных масел в соотношении от 1:1 до 1:9 при следующем соотношении ингредиентов, мас.%:2. Органический ингибитор по п. 1, отличающийся тем, что в качестве нейтрализующего агента смазочной добавки ФК-2000 Плюс используют гидрат окиси калия или натрия.

Реагент комплексного действия для буровых растворов на водной основе

Изобретение относится к бурению нефтяных и газовых скважин, а именно к реагентам для регулирования свойств буровых растворов на водной основе. Технический результат - улучшение смазочных, противоприхватных и поверхностно-активных свойств глинистых и безглинистых буровых растворов на водной основе. Реагент комплексного действия для буровых растворов на водной основе содержит, мас.%: талловое масло 20-25; соевое масло 20-25; щелочь 3-6; флотореагент-оксаль 15-20; диэтаноламид соевого масла 2-2,5; оксиэтилированные жирные спирты с десятью молями окиси этилена 2-5; моноэтаноламин 0,5-1; диэтиленгликоль 12-14; этиловый спирт 9-11. Реагент комплексного действия для буровых растворов на водной основе получен перемешиванием таллового масла, соевого масла, флотореагента-оксаля, оксиэтилированных жирных спиртов с десятью молями окиси этилена, щелочи, этилового спирта при температуре 55-60°С в течение 4 ч с последующим введением в смесь диэтаноламида соевого масла и моноэтаноламина и нагревом до 60 ...

КОМПЛЕКСНЫЙ РЕАГЕНТ ДЛЯ ОБЕЗЗАРАЖИВАНИЯ ВОД, ЗАКАЧИВАЕМЫХ В НЕФТЕНОСНЫЕ ПЛАСТЫ

Изобретение относится к реагентам, предназначенным для обеззараживания, в том числе и от сульфатвосстанавливающих бактерий, закачиваемым в нефтеносные пласты поверхностных вод, и может найти применение в нефтедобывающей отрасли. Изобретение содержит комплексный реагент для обеззараживания вод, закачиваемых в нефтеносные пласты. Комплексный реагент содержит смесь биоцидных ингредиентов и ингредиента, препятствующего застыванию реагента при низких температурах. В качестве биоцидных ингредиентов применяют полигексаметиленгуанидина гидрохлорид (ПГМГ-ГХ) и алкилдиметилбензиламмония хлорид (АДБАХ). В качестве ингредиента, препятствующего застыванию, используют полиэтиленгликоль (ПЭГ) или метанол. Массовое соотношение ингредиентов в реагенте составляет, %: ПГМГ-ГХ – 5-20; АДБАХ – 5-20; ПЭГ или метанол – 25-60; вода – до 100. Технический результат – обеспечение высокой селективности вводимых в реагент биоцидных ингредиентов в отношении подавления роста и развития сульфатвосстанавливающих бактерий ...

СПОСОБ ПОЛУЧЕНИЯ КОМПОНЕНТА ДЛЯ БУРОВЫХ РАСТВОРОВ

Изобретение относится к способам получения компонентов для буровых растворов. Технический результат – высокая пожаробезопасность и улучшенные низкотемпературные свойства компонента бурового раствора, а именно температура вспышки не ниже 80°C, температура помутнения порядка минус 68°C, предельная температура фильтруемости порядка минус 78°C и температура застывания порядка минус 79°C. Способ получения компонента для буровых растворов из нефти включает перегонку нефти с выделением мазута. Полученный мазут направляют на вакуумную разгонку с получением вакуумного газойля. Полученный вакуумный газойль подвергают гидрокрекингу. Непревращенный остаток, образовавшийся в процессе гидрокрекинга, направляют на изодепарафинизацию, затем на гидрофинишинг. Образовавшийся технологический продукт направляют на фракционирование. В качестве компонента буровых растворов отбирают фракцию, выкипающую в пределах 195-305°C. 1 з.п. ф-лы, 1 ил., 1 табл., 2 пр.

Антисальниковая добавка к буровому раствору на основе глицерина

Изобретение относится к области бурения нефтяных и газовых скважин, в частности к противоадгезионным добавкам к буровым растворам. Технический результат - снижение адгезии глинистых частиц к металлическим поверхностям за счет улучшения поверхностно-активных свойств промывочных жидкостей, улучшение их реологических свойств за счет снижения вязкости и повышение смазывающих свойств, повышение механической скорости бурения. Добавка к буровому раствору на глицериновой основе содержит, об.%: глицерол (глицерин) СН(ОН)88; эмульгатор - моноалкиловый эфир полиэтиленгликоля на основе жирной кислоты с добавкой оксиэтилена 10, гидрофобизатор - моноалкиламин 2. 3 табл.

СТАБИЛИЗИРУЮЩИЕ ГЛИНУ АГЕНТЫ И СПОСОБЫ ИХ ПРИМЕНЕНИЯ

КОМПОЗИЦИИ НА ОСНОВЕ ОРГАНОГЛИНЫ, СОДЕРЖАЩИЕ ИОН ЧЕТВЕРТИЧНОГО АММОНИЯ, ИМЕЮЩИЙ ОДИН ИЛИ БОЛЕЕ РАЗВЕТВЛЕННЫХ АЛКИДНЫХ ЗАМЕСТИТЕЛЕЙ

КОМПОЗИЦИИ БУРОВОГО РАСТВОРА С НИЗКОЙ ВОДООТДАЧЕЙ, СОДЕРЖАЩИЕ ДИБЛОК-СОПОЛИМЕРЫ

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Способ подготовки углеводородной фазы отработанных инвертно-эмульсионных буровых растворов в качестве основы для приготовления технологических жидкостей, используемых при бурении и освоении скважин

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ПОНИЖАЮЩИЕ ТРЕНИЕ КОМПОЗИЦИИ НА ОСНОВЕ ТЕРПОЛИМЕРА И СПОСОБ ГИДРОРАЗРЫВА ПЛАСТА

ОТВЕРЖДАЕМЫЙ СОСТАВ ДЛЯ ПРИМЕНЕНИЯ В КАЧЕСТВЕ МАТЕРИАЛА ДЛЯ ПРЕДОТВРАЩЕНИЯ ПОТЕРЬ

... 1. Способ снижения или предотвращения потерь для буровых скважин с применением отверждаемого состава, содержащего органическое вещество, способное подвергаться свободнорадикальной (со)полимеризации, описанной в следующей формуле:,где x - это целое число от 1 до 8;Fp - это функциональная группа, содержащая одну или более группу, способную подвергаться свободнорадикальной полимеризации;L - это органическая функциональная группа, представляющая собой (замещенную) ароматическую или (замещенную) алифатическую группу, содержащую один или более O, N, S и их сочетания; иQ отвечает замещенному или незамещенному одно- или многовалентному органическому радикалу, содержащему одну или более групп из следующего ряда: алкил, алкилен, алкенил, циклоалкил, циклоалкилен, арил, аралкил, алкарил, поли(оксиалкилен), поли(карбоалкоксиалкилен), замещенный гетероциклический радикал или незамещенный гетероциклический радикал.2. Способ по п. 1, в котором указанная органическая группа, подвергаемая свободнорадикальной ...

СПЕЦИАЛЬНАЯ ЖИДКОСТЬ ДЛЯ ОБРАБОТКИ КАРБОНАТНЫХ ПЛАСТОВ, СОДЕРЖАЩАЯ ХЕЛАТООБРАЗУЮЩИЙ АГЕНТ

... 1. Жидкость, подходящая для обработки карбонатных пластов, содержащая глутаминовую N,N-диуксусную кислоту или ее соль (GLDA) и/или метилглицин N,N-диуксусную кислоту или ее соль (MGDA), ингибитор коррозии, и поверхностно-активное вещество.2. Жидкость по п. 1, в которой количество GLDA и/или MGDA составляет от 5 до 30% мас., в расчете на полную массу жидкости.3. Жидкость по п. 1 или 2, содержащая GLDA.4. Жидкость по п. 1 или 2, в которой ингибитор коррозии присутствует в количестве 0,1-2% об. от общей жидкости.5. Жидкость по п. 1 или 2, в которой ингибитор коррозии выбирают из группы аминовых соединений, четвертичных аммониевых соединений и соединений серы.6. Жидкость по п. 1 или 2, в которой поверхностно-активное вещество присутствует в количестве 0,1-2% об. от общей жидкости.7. Жидкость по п. 1 или 2, в которой поверхностно-активное вещество является неионным или катионным поверхностно-активным веществом.8. Жидкость по п. 7, в которой поверхностно-активное вещество выбирают из группы четвертичных ...

ПЕНОГАСИТЕЛЬ ДЛЯ БУРОВЫХ И ТАМПОНАЖНЫХ РАСТВОРОВ

Изобретение относится к области нефтедобывающей промышленности, в частности к композициям и способам для обработки буровых и тампонажных растворов с целью подавления пенообразования и разрушения уже образовавшейся пены. По одному из вариантов осуществления изобретения пеногасящая композиция содержит смолу пиролизную тяжелую и активную добавку, при этом активная добавка представляет собой олеиновую кислоту, стеариновую кислоту или их смесь. По второму варианту осуществления изобретения пеногасящая композиция содержит дизельное топливо или бензиновую фракцию нефти в качестве углеводородного растворителя и активную добавку в виде олеиновой кислоты. Способ снижения пенообразования в буровом или тампонажном растворе включает добавление в буровой и тампонажный раствор данных композиций для подавления пенообразования и разрушения уже образовавшейся пены. Указанные композиции обеспечивают гашение пены и предотвращение пенообразования в буровых и тампонажных растворах с использованием в качестве ...

Реагент для приготовления буровых растворов

Изобретение относится к нефтегазодобывающей промышленности, а именно к производству химических реагентов для обработки буровых растворов. Технический результат - усиление влияния реагента на фильтрационные, ингибирующие и смазочные свойства бурового раствора. Реагент для приготовления буровых растворов содержит, мас.ч.: полиакриламид 5,8-11,7; комплексон - оксиэтилидендифосфоновую или нитрилотриметилфосфоновую кислоту 3,9-9,7; подщелачивающий агент - силикат натрия 75,7-85,4; тальк 2,9. 1 табл.

Polymere, flüssige Erdverfestigungszusammensetzung und Verfahren zu deren Gebrauch

Verfahren zur Herstellung von stabilen extrem tiefen oder extrem hohen Temperaturen ausgesetzten Emulsionen

Glycol derivatives and blends thereof as gas hydrate inhibitors in water base drilling,drill-in and completion fluids

Treatment fluids for reducing subterranean formation damage

Synergistic sulfide scavenging additives for use in oilfield operations

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

Modified starch,preparation method and use of the same and drilling fluid

Process

Sustained release system for reservoir treatment and monitoring

THICKENERS

... 1447556 Polymeric thickening agents ROHM & HAAS CO 6 Dec 1973 [6 Dec 1972] 56667/73 Heading C3P Polymeric thickening agents are obtained from (a) one or more ,#-unsaturated carboxylic acids and (b) one or more oligomers of an allyl group-containing ester of acrylic or methacrylic acid or a partially hydrolysed derivative thereof. Other monomers may be copolymerized or may be co-oligomerized. In examples allyl acrylate, allyl methacrylate, or allyloxyethyl methacrylate are oligomerized alone, with each other or with allyl alcohol or allyloxyethyl alcohol in solution in the presence of potassium tert. butoxide. The product may be partially hydrolysed with aqueous potassium hydroxide followed by acidfication. The products are polymerized with (meth)acrylic acid. in bulk or aqueous medium and the products are used in acid or salt form as thickening agents for aqueous or non-aqueous media.

Latex stabilizer for synthetic latex and methods of use

Drilling fluid composition including viscosifier and method of using the same

Smart filter cake for stengthening formations

Tracers

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

Fracture filling drilling fluid comprising resilient polymeric granules

A drilling fluid additive comprises polymeric granules that will fill rock fractures in a well (fig 1A). As the granules fill a fracture the pressure at the end of the fracture reduces and the fracture closes, crushing or squashing the granules (fig 1B). As pressure in the well is raised the fracture will begin to open (fig 1C); the polymeric granules are sufficiently resilient that they expand as the fracture opens. The granules will have a maximum diameter distribution peak between 200 microns and 1000 microns and will have a rebound of at least 10 percent, but preferably 15 percent, after compression by a load of 200 Newtons. The granules can be polypropylene.

Well fluid additive

Environmentally friendly defoamer

A defoamer containing an alkanol, lecithin and water has particular applicability in the treatment of hydraulic cements used in hydrocarbon-bearing formations and in the cleaning of pipes and pipe lines. The defoamer is composed of environmentally friendly components. The alcohol is selected from a group consisting of methanol, ethanol, isopropanol, butanol and monoethylene glycol. Preferably the alkanol is 1-butanol or 2-butanol. The lecithin is soya lecithin. Also claimed is a method of treating an oil or gas producing well using an antifoaming composition of the invention.

Dispersible hydrophilic polymer compositions

A hydrophilic polymer composition for use in thickening aqueous mediums comprising hydroxyethyl cellulose, a water miscible polar organic liquid which acts as solvating agent for the hydroxyethyl cellulose, the solvating agent being of a type which forms a semi-solid to viscous mixture with the hydroxyethyl cellulose under certain conditions. The polymeric composition alone, or in admixture with a diluting agent which is a non-solvating agent for the hydroxyethyl cellulose, can be added to aqueous mediums, particularly heavy brines, to produce well servicing fluids.

DISPERSIBLE HYDROPHILIC POLYMER COMPOSITIONS

SILICONE EMULSIFIER COMPOSITION INVERT EMULSIONS THEREFROM AND METHOD THEREFOR

Viscosifier polymer for treatment of a subterranean formation

Wellbore fluid

The present invention relates to a wellbore fluid comprising a particulate material composed of the reaction product of A) one or more water soluble organic compound having possessing a molecular weight of less than 30,000 and possessing at least two hydroxyl groups and B) any other organic compound(s) capable of forming acetal or hemiacetal cross-links with the hydroxyl groups of compound A. The invention relates also to the specific particulate material itself and to applications of the wellbore fluid of the invention for well processes such as drilling, under-reaming, completing, working over, sealing loss zones, sealing fractures, sealing cavities or other very high permeability conduits in a rock formation, or hydraulic fracturing to stimulate a hydrocarbon-producing zone.

Method of increasing lubricity of brine-based drilling fluids and completion brines

The lubricity of a drilling fluid or a completion fluid may be increased by incorporating into the fluid a water-soluble or water-dispersible salt of a sulfonated (sulfated) vegetable oil or a derivative thereof, such as a sulfonated (sulfated) castor oil. Suitable derivatives include the sodium, potassium, calcium, magnesium or ammonium salt. A non-ionic or anionic surfactant which is capable of enhancing the solubility of the salt may further be incorporated into the drilling fluid or completion fluid.

Use of carbonates as wellbore treatment

A method of drilling a subterranean formation includes drilling the subterranean formation with a drilling fluid including a carbonate base fluid and an aqueous base fluid. The carbonates may be selected from ethylene carbonate, propylene carbonate, glycerol carbonate, butylene carbonate, 1,3-propylene carbonate, dialkylcarbonates, dimethylcarbonate, and mixtures thereof. Drilling fluids may include a carbonate base fluid, an aqueous base fluid and an optional base oil.

Wellbore treatment fluid

Liquid crystals for drilling, completion and production fluids

Fluids containing liquid crystal-forming surfactants or polymeric surfactants, or polymers, or complex polymers or copolymers, or graphite nanotubes or Janus particles in a polar and/or non polar liquid, and optionally, co-surfactants, are useful in drilling, completion and production operations to give increased viscosity (solids suspension ability) and/or decreased fluid loss, as compared to otherwise identical fluids absent the liquid crystals. These liquid crystal compositions contain organized micelles. The liquid crystal-containing fluids are useful in completion fluids, fracturing fluids, formation damage remediation, waste management, lost circulation drilling optimization, reducing trapped annular pressure during the hydrocarbon production process, well strengthening, friction and drag reducers, fluids introduced through an injection well for geothermal wells, and the controlled release of additives into a wellbore, at a subterranean formation or at the oil production facilities ...

Drilling fluid systems comprising latex particles

Fluid loss additive for water based drilling fluids with improved thermal stability

A polymer microsphere for use as a fluid loss additive in drilling muds including a hydrophobic core of hydrophobic monomers and a hydrophilic shell of hydrophilic monomers wherein the hydrophilic shell surrounds the hydrophobic core. The polymer microsphere is capable of forming micelles or microgels in water without using surfactants and can be block, graft, and random copolymers. The hydrophilic shell is physically or chemically linked to the hydrophobic core. The polymer microsphere further includes crosslinkers, preferably where the crosslinkers are monomers containing at least two ethylenically unsaturated groups.

Improvements in treating fluid loss from a borehole

Methods and systems for acidizing subteranean formations

Method for freeing or unsticking drill stems stuck in well bores

... 1,074,551. Drilling wells. SOC. DE PRODUITS CHIMIQUES D'AUBY and SOC. NATTONALE DES PETROLES D'AQUITAINE. Aug. 21, 1964 [Aug. 31, 1963], No. 34258/64. Heading E1F. Drills are freed when stuck in well-bores drilled by aqueous drilling muds by injection of a cationic hydrophobic surface-active agent with a lubricant carrier vehicle so that water is driven from the sticking zone. Fatty amines and their salts and quaternary ammonium salts are generally used as agents.

Dry drilling fluid additives and methods relating thereto

Dry drilling fluid additives may include a dry mixture that comprises a clay stabilizing agent at about 76% to about 93% by weight of the dry mixture, a dispersant at about 3% to about 6% by weight of the dry mixture, and a surfactant at about 4% to about 18% by weight of the dry mixture. Such dry drilling fluid additives may be useful in methods and systems for drilling wellbore penetrating subterranean formations, especially deviated and highly-deviated wellbores.

Biodegradable additive suitable for use in wellbore fluids

Crosslinking agents for producing gels and polymer beads for oilfield applications

Fluid loss additive package for shallow well drilling fluids

Selective salt management for wellbore fluids using micrgel particles

HETEROPOLYSACCHARIDE S-88

Release system and method

A release system for releasing a released material into a release fluid comprises a matrix having at least one first matrix material and at least one second matrix material. The second matrix material is configured to at least partially erode when exposed to the release fluid. The releasable material is held in the matrix such that the at least partial erosion of the second matrix material causes the releasable material to be at least partially released from the matrix. The releasable material is preferably a solid particle and may be a tracer. The particle may be encapsulated in an encapsulating material within the matrix. The matrix material may be a thermoset polymer, glycol, wax. There is also a method of release and a method of monitoring using the released material shown.

Filter cake removal compositions and methods of making and using same

A breaker composition comprising (i) an acid precursor, (ii) an accelerating agent wherein the accelerating agent comprises a Lewis acid and (iii) an aqueous fluid wherein the effective operating temperature of the breaker composition ranges from about 15 °C to about 120 °C. The accelerating agent may preferably be ZnSO4 (zinc sulfate). Also shown is wellbore servicing system comprising (a) an aqueous-based drilling fluid, wherein the aqueous-based drilling fluid forms water-wet solids in the wellbore; and (b) a breaker composition comprising (i) an acid, (ii) an accelerating agent and (iii) an aqueous fluid; and a method of dissolving a filtercake comprising contacting the filtercake with a breaker solution comprising (i) an acid precursor, (ii) an accelerating agent and (iii) an aqueous fluid wherein the filtercake comprises calcium carbonate.

Solvent-stabilized colorimetric detection of amine-based additives

A method of detecting an amine-based additive in a wellbore servicing fluid (WSF) comprising contacting an aliquot of WSF with an amine detector compound and an aqueous salt solution to form a detection solution; wherein the aqueous salt solution comprises an inorganic salt and organic carboxylate salt; wherein the WSF comprises the amine-based additive; and wherein the detection solution is characterized by at least one absorption peak wavelength in the range of 380-760 nm; detecting an absorption intensity for detection solution at a wavelength within about +20% of the at least one absorption peak wavelength; comparing the absorption intensity of detection solution at the wavelength within about +20% of the at least one absorption peak wavelength with a target absorption intensity of amine-based additive to determine the amount of amine-based additive in WSF; and comparing the amount of amine-based additive in WSF with a target amount of amine-based additive.

Graphene oxide coated membranes to increase the density of water base fluids

The present invention relates to a method of servicing a wellbore extending from a surface of the earth and penetrating a subterranean formation, including recovering an aqueous-based wellbore servicing fluid from the wellbore; and removing water from the aqueous-based wellbore servicing fluid by contacting the aqueous-based wellbore servicing fluid with a porous substrate coated with a hydrophilic and oleophobic coating 40. The hydrophilic and oleophobic coating comprises graphene oxide and the coated porous substrate comprises a plurality of cylindrical tubes, fig 6A coated on an inside diameter, an outside diameter, or both the inside diameter and the outside diameter thereof with the hydrophilic and oleophobic coating, and whereby a water concentration and a volume of the aqueous-based wellbore servicing fluid are reduced and a density of the aqueous-based wellbore servicing fluid is increased to provide a modified aqueous-based wellbore servicing fluid.

BIOCIDAL SYSTEMS AND METHODS OF USE

Dispersible hydrophobic thickening agent in water and thickened aqueous composition obtained with this agent.

Process and product to improve the conditions of drilling.

Process for reversible thickening of a liquid.

Additive for increasing the density of a fluid forcasing annulus pressure control.

BIOCIDAL SYSTEMS AND METHODS OF USE

BIOCIDAL SYSTEMS AND METHODS OF USE

Synthetic polymer-based fluid loss pill

Die hier beschriebenen Zusammensetzungen können ein wässriges Fluid, ein vernetztes Polyvinylpyrrolidon (PVP) und ein Polymer auf Betainbasis beinhalten. Die hier beschriebenen Verfahren können Pumpen einer ausgewählten Menge einer Fluidverlustpille in eine Formation beinhalten, wobei die Fluidverlustpille ein vernetztes PVP und ein Polymer auf Betainbasis beinhaltet.

IMPROVED AQUEOUS ONE BOREHOLE LIQUIDS

DIALKYL-BIS (TRIALKANOLAMINE) ZIRKONATE.

COPOLYMERS OF ALKYL POLY (OXYALKYLEN) ESTERS OF ITACONSAEURE AND PROCEDUREPROCEDURE PROCEDURES THIS USE.

INVERSE EMULSIONS.

Wellbore fluid and methods of treating an earthen formation

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

Treatment of subterranean formations

A method of preparing and using a subterranean formation stabilization agent. The stabilization agent includes a guanidyl copolymer and may be admixed with a fracturing fluid and optionally brine. The stabilization agent is effective in preventing and/or reducing, for example, clay swelling and fines migration from a subterranean formation contacted with the stabilization agent.

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

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

Thermoset particles with enhanced crosslinking, processing for their production, and their use in oil and natural gas drilling applications

A method for fracture stimulation of a subterranean formation having a wellbore. The method comprise a series of steps. A slurry is injected into the wellbore at sufficiently high rates and pressures such that the formation fails and fractures to accept the slurry. The slurry comprises a fluid and a proppant, wherein said proppant comprises a styrene-ethylvinylbenzene-divinylbenzene terpolymer composition having a substantially cured polymer network, wherein said composition lacks rigid fillers or nanofillers. The proppant is emplaced within the fracture network in a packed mass or a partial monolayer of the proppant within the fracture, wherein the packed mass or partial monolayer props open the fracture; thereby allowing produced gases, fluids, or mixtures thereof, to flow towards the wellbore.

Methods to improve stability of high solid content fluid

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

PYROMELLITAMIDE GELLING AGENTS

A downhole fluid comprises a base fluid, for example a hydrocarbon base fluid, and a pyromellitamide gelling agent. The pyromellitamide gelling agent may have the general formula of: 1. A downhole fluid comprising a base fluid and a pyromellitamide gelling agent.3. The downhole fluid of in which R claim 2 , R claim 2 , R claim 2 , and Rare each hydrogens and one or more of R claim 2 , R claim 2 , R claim 2 , and Ris each an alkyl group.4. The downhole fluid of in which R claim 3 , R claim 3 , R claim 3 , and Rare each alkyl groups.5. The downhole fluid of in which R=R=R=R.6. The downhole fluid of in which R claim 5 , R claim 5 , R claim 5 , and Reach has at least 6 carbon atoms.7. The downhole fluid of in which each alkyl group has 6-24 carbon atoms.8. The downhole fluid of in which each alkyl group has 6-10 carbon atoms.9. The downhole fluid of in which each alkyl group is one or more of straight chain claim 3 , branched claim 3 , aromatic claim 3 , or cyclic.10. The downhole fluid of in which each alkyl group is straight chain.11. The downhole fluid of in which R claim 2 , R claim 2 , R claim 2 , and Rare each hydrogens claim 2 , and R claim 2 , R claim 2 , R claim 2 , and Rare each straight chain alkyl groups with 6-10 carbon atoms.12. The downhole fluid of in which R claim 11 , R claim 11 , R claim 11 , and Rhave 6 carbon atoms.13. The downhole fluid of in which the base fluid comprises hydrocarbons.14. The downhole fluid of in which the hydrocarbons have 3-8 carbon atoms.15. The downhole fluid of in which the hydrocarbons comprise liquefied petroleum gas.16. The downhole fluid of further comprising a breaker.17. The downhole fluid of in which the breaker further comprises one or more of a bromide salt claim 16 , a chloride salt claim 16 , an organic salt claim 16 , and an amine salt.18. The downhole fluid of in which the breaker comprises one or more of an alcohol or alkoxide salt.19. The downhole fluid of in which the one or more of an alcohol or alkoxide salt ...

CATALYST SYSTEM FOR THE PREPARATION OF AN ESTER AND PROCESSES EMPLOYING THIS ESTER

The present invention relates to a process for the preparation of an ester in a reactor, wherein at least one of at least two different catalysts is an electron donor and a further catalyst is a sulphur-containing proton donor; a device, a process for the preparation of a thermoplastic composition comprising the ester prepared according to the invention, a process for the production of a shaped article comprising the ester according to the invention or the thermoplastic composition according to the invention, a process for the production of a packed product, a process for the production of an at least partly coated object, and uses of the esters according to the invention as an additive in various compositions. 2. The process according to claim 1 , wherein the carboxylic acid component contains non-metal atoms chosen from the group of carbon claim 1 , oxygen claim 1 , Nitrogen or hydrogen.3. The process according to or claim 1 , wherein the carboxylic acid component comprises more than 5 carbon atoms.4. The process according to one of the preceding claims claim 1 , wherein the amount of electron donor claim 1 , based on the total amount of catalysts claim 1 , is more than 12.5 wt. %.5. The process according to one of the preceding claims claim 1 , whereinaa. sulphuric acid, or{'sub': 1', '10, 'bb. an aliphatic, cycloaliphatic or aromatic C- to C-sulphonic acid,'}or a combination of two or more of these, is chosen as the sulphur-containing proton donor.6. The process according to one of the preceding claims claim 1 , wherein a metal claim 1 , a metal compound claim 1 , or a reducing acid claim 1 , or a combination of two or more of these claim 1 , is employed as the electron donor.7. The process according to one of the preceding claims claim 1 , whereinaa) a metal chosen from the group consisting of: titanium, tin, zirconium, in particular tin, orbb) a metal compound chosen from the group consisting of tetraalkyl titanate, organotitanium complex, titanium salt, tin ...

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

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

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).

Biocide Compositions Comprising Quaternary Ammonium and Urea and Methods for Their Use

Composition and method for treating and/or preventing biological contamination using a biocide composition comprising at least one quaternary ammonium compound and urea. The method includes drying urea, and thereafter combining at least one quaternary ammonium compound and urea and may produce a potent biocide composition that is stable and able to chemically treat biological contamination in a variety of difficult to reach locations. Uses of the composition are also described. 1. A method of making a biocide composition comprising:drying urea; and thereafter,combining at least one quat and urea to form a quat/urea biocide composition.2. The method of claim 1 , wherein the step of drying the urea comprises heating the urea.3. The method of claim 1 , further comprising the step of drying the at least one quat before the combining step.4. The method of claim 3 , wherein the step of drying the at least one quat comprises heating the at least one quat and the step of drying the urea comprises heating the urea.5. The method of claim 4 , wherein the step of heating the at least one quat comprises gradually heating the at least one quat to a temperature in a range from about 30 to about 40° C.6. The method of claim 4 , wherein the step of heating the at least one quat comprises heating the at least one quat in the presence of a solvent.7. The method of claim 4 , wherein the step of heating the urea comprises heating the urea to a temperature in a range from about 80 to about 120° C.8. The method of claim 4 , wherein the step of heating the at least one quat comprises gradually heating the at least one quat to a temperature in a range from about 30° C. to about 40° C. claim 4 , and the step of heating the urea comprises heating the urea to a temperature in a range from about 80° C. to about 120° C.9. The method of claim 4 , wherein the step of combining the at least one quat and urea comprises spraying the at least one quat onto the urea.10. The method of claim 4 , further ...

Methods for Servicing Subterranean Wells

Methods for controlling fluid flow through one or more pathways in one or more rock formations penetrated by a borehole in a subterranean well, comprise injecting into or adjacent to the formation a treatment fluid comprising at least one viscoelastic surfactant; fibers, or a mixture of fibers and particles; and one or more flocculation initiators. Flocculation of the mixture produces fibrous masses that migrate to formation-rock openings such as pores, cracks, fissures and vugs. As a result, the fibrous masses are useful for curing lost circulation, providing fluid-loss control and as diverting agents. 1. A method for controlling fluid flow through one or more pathways in one or more rock formations penetrated by a borehole in a subterranean well , comprising injecting into or adjacent to the formation a treatment fluid comprising:i. at least one viscoelastic surfactant;ii. fibers, or a mixture of fibers and particles; andiii. one or more flocculation initiators.2. A method for curing lost circulation in a subterranean well penetrated by a borehole comprising injecting into or adjacent to the formation a treatment fluid comprising:i. at least one viscoelastic surfactant;ii. fibers, or a mixture of fibers and particles; andiii. one or more flocculation initiators.3. A method of treating a subterranean formation penetrated by a wellbore , comprising injecting into or adjacent to the formation a treatment fluid comprising:i. at least one viscoelastic surfactant;ii. fibers, or a mixture of fibers and particles; andiii. one or more flocculation initiators.4. The method of claim 1 , wherein the flocculation initiator comprises one or more members of the list comprising: acids claim 1 , bases claim 1 , multivalent ions claim 1 , mutual solvents claim 1 , surfactants claim 1 , polymers and oxidizers.5. The method of claim 1 , wherein the viscoelastic surfactant comprises a fatty-acid carboxylate.6. The method of claim 1 , wherein the viscoelastic-surfactant concentration ...

GRAPHENE-BASED MATERIAL FOR SHALE STABILIZATION AND METHOD OF USE

Methods and compositions for use in drilling a wellbore into an earthen formation that includes the use of a graphene-based material, where the graphene-based material may be at least one of graphene, graphene oxide, chemically converted graphene, and derivatized graphite oxide are shown and described. In certain examples, the methods and compositions reduce permeability damage and/or stabilize shales. 1. A method for stabilizing shales while drilling a wellbore into an earthen formation , comprising: 'a graphene-based material selected from graphene, graphene oxide, chemically converted graphene, and derivatized graphite oxide, wherein the graphene-based material is present in a sufficient weight percent to stabilize the shales.', 'circulating a wellbore fluid into the wellbore while drilling through shales, wherein the wellbore fluid comprises2. The method of claim 1 , wherein the wellbore fluid is an aqueous based wellbore fluid.3. The method of claim 1 , wherein the aqueous based wellbore fluid comprises an aqueous continuous phase.4. The method of claim 1 , wherein the wellbore fluid is an invert emulsion wellbore fluid.5. The method of claim 4 , wherein the invert emulsion wellbore fluid comprises an oleaginous external phase and a non-oleaginous internal phase.6. The method of claim 1 , wherein the graphene-based material is functionalized with at least one of alkyl groups claim 1 , carboxyl groups claim 1 , amines claim 1 , quaternary amines claim 1 , ethoxylated ethers claim 1 , propoxylated ether claim 1 , glycol derived groups claim 1 , polyglycol claim 1 , polyvinyl alcohol claim 1 , silanes claim 1 , silane oxides claim 1 , and combinations thereof.7. The method of claim 1 , wherein the graphene-based material comprises from about 0.1% to about 1% by volume of the wellbore fluid.8. The method of claim 1 , wherein the graphene-based material is chemically converted graphene.9. The method of claim 8 , wherein the chemically converted graphene is prepared ...

Antifoaming and Defoaming Agents for Drilling Fluids

A method is provided for treating a drilling fluid to reduce foaming therein. The method comprises (a) providing a drilling fluid; and (b) treating the drilling fluid by adding a composition thereto which comprises (a) an alkylene glycol, (b) a polyol having first and second primary hydroxyl groups, (c) an unsaturated vegetable oil, and (d) an alkoxylated alcohol. 1. A method for treating a drilling fluid to reduce foaming therein , comprising:providing a drilling fluid; andtreating the drilling fluid by adding a composition thereto which comprises (a) an alkylene glycol, (b) a polyol having first and second primary hydroxyl groups, (c) an unsaturated vegetable oil, and (d) an alkoxylated alcohol, thereby obtaining treated drilling fluid.2. The method of claim 1 , wherein said alkylene glycol is selected from the group consisting of ethylene glycol and propylene glycol.3. The method of claim 1 , wherein said alkylene glycol is propylene glycol.4. The method of claim 1 , wherein said polyol is glycerol.5. The method of claim 1 , wherein said unsaturated vegetable oil is selected from the group consisting of canola oil claim 1 , cottonseed oil claim 1 , olive oil claim 1 , corn oil and safflower oil.6. The method of claim 1 , wherein said unsaturated vegetable oil is cottonseed oil.7. The method of claim 1 , wherein said alkoxylated alcohol is an ethoxylated alcohol.8. The method of claim 1 , wherein said alkoxylated alcohol is linear.9. The method of claim 1 , wherein said alkylene glycol is present in said composition in an amount of 5% to 60% by weight claim 1 , based on the total weight of said composition.10. The method of claim 1 , wherein said alkylene glycol is present in said composition in an amount of 10% to 50% by weight claim 1 , based on the total weight of said composition.11. The method of claim 1 , wherein said alkylene glycol is present in said composition in an amount of 20% to 40% by weight claim 1 , based on the total weight of said composition.12 ...

AGGREGATING COMPOSITIONS, MODIFIED PARTICULATE METAL-OXIDES, MODIFIED FORMATION SURFACES, AND METHODS FOR MAKING AND USING SAME

A method for treating solid materials is disclosed, where the treating compositions coats surfaces or portions of surfaces of the solid materials changing an aggregation or agglomeration propensity of the materials. Treating composition and treated solid materials are also disclosed. The methods and treated materials are ideally suited for oil field applications. 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. The method of claim 34 , wherein a pressure of the drilling fluid is operated in an over-balanced pressure condition claim 34 , an under-balanced pressure condition or a managed pressure condition.26. (canceled)27. (canceled)28. (canceled)29. (canceled)30. (canceled)31. (canceled)32. (canceled)33. (canceled)34. A method for drilling comprising the step of:while drilling, circulating a drilling fluid, to provide bit lubrication, heat removal and cutting removal, where the drilling fluid includes an aggregating composition including a polymer comprising homopolymers selected from the group consisting of poly-2-vinyl pyridine, poly-4-vinyl pyridine, and mixtures or combinations thereof and copolymers selected from the group consisting of copolymers of 2-vinyl pyridine and 4-vinyl pyridine, copolymers of ethylene and 2-vinyl pyridine and/or 4-vinyl pyridine, copolymers of propylene and 2-vinyl pyridine and/or 4-vinyl pyridine, copolymers of acrylic acid and 2-vinyl pyridine and/or 4-vinyl pyridine, copolymers of methacrylic acid and 2-vinyl pyridine and/or 4-vinyl pyridine, copolymers of acrylates and 2-vinyl pyridine and/or 4-vinyl pyridine, copolymers of methacrylates and 2-vinyl pyridine and/or 4-vinyl pyridine, and mixtures or combinations thereof and where the composition increases ...

Fluids and methods including nanocellulose

Treatment fluids and methods for treating a subterranean formation are disclosed that include introducing a treatment fluid into a subterranean formation, the treatment fluid containing a nanocrystalline cellulose.

METHOD OF USING MULTI-COMPONENT FIBERS AS LOST-CIRCULATION MATERIAL

A method of forming a subterranean well and a method of reducing lost circulation in a subterranean well while drilling the subterranean well are disclosed. The methods include using multi-component fibers as lost-circulation materials. The multi-component fibers having external surfaces and include at least a first polymeric composition and a second polymeric composition. At least a portion of the external surfaces of the multi-component fibers includes the first polymeric composition, which at least partially adhesively bonds the mud cake formed during the method. 1. A method of forming a subterranean well , the method comprising:drilling the subterranean well with a drilling mud comprising lost-circulation material; andforming a mud cake comprising drill cuttings and the lost-circulation material, wherein the lost-circulation material comprises multi-component fibers having external surfaces and comprising at least a first polymeric composition and a second polymeric composition, wherein at least a portion of the external surfaces of the multi-component fibers comprises the first polymeric composition, and wherein the first polymeric composition at least partially adhesively bonds the mud cake.2. The method of claim 1 , wherein the drilling mud comprises an oil-based drilling fluid comprising at least one of crude oil claim 1 , diesel oil claim 1 , biodiesel oil claim 1 , kerosene claim 1 , mineral oil claim 1 , gasoline claim 1 , naphtha claim 1 , or toluene.3. The method of claim 1 , wherein the drilling mud comprises an aqueous drilling fluid.4. The method of claim 1 , wherein the multi-component fibers are non-fusing at a temperature encountered in the well.5. The method of claim 1 , wherein the second polymeric composition has a melting point higher than a temperature encountered in the well.6. The method of claim 1 , wherein the second polymeric composition comprises at least one of an ethylene-vinyl alcohol copolymer claim 1 , a polyamide claim 1 , a ...

DRILLING LOST CIRCULATION MATERIAL

An engineered composition for reducing lost circulation in a well includes a mixture of coarse, medium and optional fine particles, and a blend of long fibers and short fibers. The long fibers are rigid and the short fibers are flexible. The long fibers form a tridimensional mat or net in the lost-circulation pathway that traps the mixture of particles and short flexible fibers to form a mud cake. The mixture of particles and blend of fibers may be added to water based and oil-based drilling fluids. The composition, size, and concentration of each component of the mixture of particles and blend of fibers may be fine-tuned for each application. 1. A method for reducing lost circulation in a well comprising: (1) a mixture of coarse particles having an average particle size between 300 and 1200 μm, medium particles having an average particle size between 20 and 150 μm and optionally fine particles having an average particle size between 5 and 15 μm; and', '(2) a blend of long fibers having an average length between 8 and 15 mm, and short fibers having an average length between 1 and 8 mm; and, '(i) adding to a drilling fluid a composition comprising(ii) circulating the drilling fluid in the well.2. The method of claim 1 , wherein the particle mixture comprises from about 0 to about 15 weight percent fine particles claim 1 , about 20 to about 40 weight percent medium particles claim 1 , and about 40 to about 60 weight percent coarse particles.3. The method of claim 1 , wherein the particles are selected from the group consisting of alkaline earth carbonates claim 1 , poly-paraphenyleneterephthalamide claim 1 , mica claim 1 , rubber claim 1 , polyethylene claim 1 , polypropylene claim 1 , polystyrene claim 1 , poly(styrenebutadiene claim 1 , fly ash claim 1 , silica claim 1 , mica claim 1 , alumina claim 1 , glass claim 1 , barite claim 1 , ceramic claim 1 , metals and metal oxides claim 1 , starch and modified starch claim 1 , hematite claim 1 , ilmenite claim 1 , ...

CURABLE CROSS-LINKABLE COMPOSITIONS FOR USE AS LOST CIRCULATION MATERIAL

The present invention relates to compositions and methods for reducing or preventing the loss of drilling fluids and other well servicing fluids into a subterranean formation during drilling or construction of boreholes in said formation. Specifically, this invention comprises a curable cross-linkable composition capable of free radical polymerization for creating lost circulation material. The curable cross-linkable composition comprises a mixture of (i) an organic compound capable of free radical (co)polymerization comprising a moiety derived from an diisocyanate and a moiety derived from an organic polyol comprising two or more hydroxyl groups having a molecular weight of from 400 to 4,000 and (ii) a reactive diluent comprising an organic compound with a reactive group and a moiety derived from an organic polyol comprising two or more hydroxyl groups having a molecular weight of from 60 to 500. 2. The curable cross-linkable composition of wherein said moieties comprising a free radical polymerizable group (Fpand Fp) independently comprise a vinyl ether claim 1 , a vinyl ester claim 1 , an allyl ether claim 1 , an allyl ester claim 1 , a vinyl ketone claim 1 , styrene claim 1 , α-methylstyrene claim 1 , a vinyl amide claim 1 , an allyl amide claim 1 , an acrylamide claim 1 , a maleate claim 1 , a fumarate claim 1 , or a (meth)acrylate.3. The curable cross-linkable composition of wherein said moieties comprising a free radical polymerizable group (Fpand Fp) are independently derived from a (meth)acrylate.4. The curable cross-linkable composition of wherein the bond connecting the organic compound with a reactive group (Fp) to the moiety (L) derived from a diisocyanate is a urethane link.5. The curable cross-linkable composition of wherein:{'sub': '1', 'i the polyvalent organic radical (Q) is derived from a polyethylene oxide polyol, a polypropylene oxide polyol, a polybutylene oxide polyol, a copolymer of polyalkylene oxide polyol, a terpolymer of polyalkylene ...

Environmentally Friendly Solvent Systems/Surfactant Systems For Drilling Fluids

A oil field production fluid, namely a drilling mud composition, comprising a mixture of: (a) at least one base oil component; and (b) an additive component comprising a blend of dibasic esters. The functional fluid can optionally comprise additional additive components. The blend of dibasic esters comprises two or more of dialkyl methylglutarate, dialkyl adipate, dialkyl ethylsuccinate, dialkyl succinate, dialkyl glutarate.

Lost Circulation Material With A Multi-Modal Large Particle Size Distribution

Compositions for lost circulation materials (LCM) and methods for using same in drilling and/or completing wellbores that help solve lost circulation problems in a wide range of fracture sizes, thereby advantageously eliminating the need for a variety of products for lost circulation in a field at any one time. An unexpected synergy and improved reduction in lost circulation is obtained. The invention provides specific LCM components in specific ratios that are analogs to lost circulation fractures and that yield superior performance in preventing or alleviating lost circulation in drilling and cementing boreholes. The invention compositions have a multi-modal particle size distribution (PSD) which provides a higher concentration of component materials in the same range of two or more fracture widths, thus allowing plugging to occur over a wider range than a single mode or narrow PSD. 1. A method for avoiding or reducing lost circulation in a subterranean formation during drilling a borehole in said formation , the method comprising: treating the subterranean formation with a lost circulation material or composition comprising: walnut pieces in three different sizes or size ranges and calcium carbonate particles in three different sizes or size ranges ,wherein the walnut pieces comprise fine pieces having a one particle size of about 100 microns to about 3,000 microns, medium pieces having a one particle size in the range of from about 200 microns to about 3,000 microns, and coarse pieces having a one particle size in the range of from about 300 microns to about 4,000 microns, andwherein the calcium carbonate particles comprise fine particles having a one particle size from about 1 micron to about 500 microns, medium particles having a one particle size from about 100 microns to about 1500 microns, and coarse particles having a one particle size from about 500 microns to about 3,000 microns.2. The method of wherein the concentration of the lost circulation material ...

Equipment and Methods for Preparing Curved Fibers

The invention is related in general to equipment and methods for preparing curved fibers in a batch or continuous process. Fiber strands comprising a thermoplastic material are placed on a cylindrical surface and heated such that they soften and become malleable. The fiber strands assume the curvature of the cylindrical surface and, upon cooling below their softening temperature, retain the curvature. The curved-fiber strands are then cut to a desired length. 1. An apparatus for preparing curved fibers , comprising:i. a rotating cylindrical screw feeder;ii. a rolling zone comprising means for transporting and guiding one or more strands of fiber onto the screw feeder;iii. a heating zone comprising means for heating the fiber as it travels down the screw feeder;iv. a cooling zone comprising means for cooling the fiber as it travels down the screw feeder;v. an unrolling zone comprising means for guiding and transporting one or more strands of fiber away from the screw feeder;vi. means for cutting the fiber.2. The apparatus of claim 1 , wherein the means for heating the apparatus is one or more members of the list comprising: an oven claim 1 , a heating rod claim 1 , a forced-air heater and an infrared heater.3. A method of preparing curved fibers claim 3 , using the apparatus of claim 3 , comprising;i. selecting a cylindrical screw feeder whose diameter between the threads provides a desired curvature;ii. selecting one or more continuous fiber strands, the fibers having a composition with a workability-temperature range;iii. threading the fiber strands through the opposing wheels in the rolling zone, and wrapping the strands onto the entire length of the screw feeder between the threads toward the unrolling zone;iv. guiding the fiber strands off of the screw feeder and threading them through the opposing wheels in the unrolling zone;v. initiating rotation of the screw feeder;vi. activating a heat source in the heating zone, such that the fiber composition passing ...

CURABLE COMPOSITION FOR USE AS LOST CIRCULATION MATERIAL

The present invention relates to compositions and methods for reducing or preventing the loss of drilling fluids and other well servicing fluids into a subterranean formation during drilling or construction of boreholes in said formation. Specifically, this invention comprises a curable composition capable of free radical polymerization for creating lost circulation material in-situ. The curable composition comprises an organic compound capable of free radical (co)polymerization represented by the formula (I): wherein x is an integer from 1 to 8; Fp comprises one or more moiety comprising a free radical polymerizable group; L is an organic moiety comprising a (substituted) aromatic or (substituted) aliphatic group comprising one or more O, N, S, or combinations thereof; and Q comprises a substituted or unsubstituted mono- or polyvalent organic radical comprising one or one or more moiety selected from alkyl, alkylene, alkenyl, cycloalkyl, cycloalkylene, aryl, aralkyl, alkaryl, poly(oxyalkylene), poly(carboalkoxyalkylene), a substituted heterocyclic radical, or an unsubstituted heterocyclic radical. 2. The curable composition of wherein said free radical polymerizable organic group (Fp) comprises one or more unsaturated carbon-carbon double or triple bond.3. The curable composition of wherein said moiety comprising a free radical polymerizable group (Fp) comprises a vinyl ether claim 1 , a vinyl ester claim 1 , an allyl ether claim 1 , an allyl ester claim 1 , a vinyl ketone claim 1 , styrene claim 1 , α-methylstyrene claim 1 , a vinyl amide claim 1 , an allyl amide claim 1 , an acrylamide claim 1 , a maleate claim 1 , a fumarate claim 1 , or a (meth)acrylate.4. The curable composition of wherein said moiety comprising a free radical polymerizable group (Fp) is derived from an α claim 1 ,β-unsaturated acid or an ester of an α claim 1 ,β-unsaturated acid.5. The curable composition of wherein said moiety comprising a free radical polymerizable group (Fp) is derived ...

Dispersants having biobased compounds

The present disclosure is directed to compositions having lecithin and an organic acid and related methods. The disclosed compositions may also include one or more co-surfactants such as anionic surfactants and/or non-ionic surfactants, and may be used as a dispersant.

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.

ACRYLOYLMORPHOLINE POLYMER AND USE THEREOF AND FILTRATE REDUCER FOR DRILLING FLUID

The present invention provides an acryloylmorpholine polymer and the use thereof and a filtrate reducer for drilling fluid. The acryloylmorpholine polymer comprises structural units expressed by formula (1), structural units expressed by formula (2), and structural units expressed by formula (3), wherein, at least a part of the structural units expressed by formula (2) can be bonded with at least a part of the structural units expressed by formula (3) into cross-linked structural unit expressed by formula (4); wherein, R-Rare H or C-Clinear or branched alkyl respectively, y is an integer within 1-5 range, M is H or an alkali metal element, X is O or NH, and Ris C-Clinear or branched alkylidene. The acryloylmorpholine polymer and filtrate reducer for drilling fluid have outstanding filtrate reduction and viscosity increasing effects. 2. The acryloylmorpholine polymer according to claim 1 , wherein in formula (1) claim 1 , R-Rare H.3. The acryloylmorpholine polymer according to claim 1 , wherein in formula (2) claim 1 , Rand Rare H claim 1 , Rand Rare methyl claim 1 , y is 1 claim 1 , and M is Na.5. The acryloylmorpholine polymer according to claim 1 , wherein an apparent viscosity of a 1 wt. % water solution of the acryloylmorpholine polymer is 30-55 mPa·s.7. The filtrate reducer for drilling fluid according to claim 6 , wherein the aqueous solvent is water.8. The filtrate reducer for drilling fluid according to claim 7 , wherein the monomer B is used in a form of 40-60 wt. % water solution; the method for homogeneously mixing the initiator and monomer mixture in the aqueous solvent comprising: homogeneously mixing a water solution of monomer B with water claim 7 , adding monomer A and cross-linked monomer C and agitating to homogeneous state claim 7 , adjusting the pH of the obtained mixture to 6-9 claim 7 , and then adding the initiator.9. The filtrate reducer for drilling fluid according to claim 6 , wherein the monomer A is N-acryloylmorpholine.10. The filtrate ...

PHOSPHONATE-CONTAINING POLYMER AND USE THEREOF AND PHOSPHONATE-CONTAINING POLYMER VISCOSITY REDUCER FOR DRILLING FLUID

The present invention provides a phosphonate-containing polymer and use thereof and a phosphonate-containing polymer viscosity reducer for drilling fluid. The phosphonate-containing polymer comprises structural units expressed by formula (1), structural units expressed by formula (2), and structural units expressed by formula (3) and/or structural units expressed by formula (4), wherein, the ratio of the mole number of the structural units expressed by formula (1), mole number of the structural units expressed by formula (2), and total mole number of the structural units expressed by formula (3) and structural units expressed by formula (4) is 10-85:10-75:5-55. The phosphonate-containing polymer still has outstanding viscosity reducing effect after high-temperature aging when it is applied in brine drilling fluids and high-density drilling fluids. 4. The phosphonate-containing polymer according to claim 1 , wherein in formula (3):{'sub': 7', '8', '2, 'Ris H, Ris H, and Mis H; or,'}{'sub': 7', '8', '2, 'Ris H, Ris methyl, and Mis H; or,'}{'sub': 7', '8', '2, 'Ris —COOH, Ris H, and Mis H; or,'}{'sub': 7', '8', '2', '2, 'Ris H, Ris —CHCOOH, and Mis H.'}5. The phosphonate-containing polymer according to claim 1 , wherein in formula (4):{'sub': 7', '8', '9', '10, 'Ris H, Ris H, and Rand Rare a bond.'}6. The phosphonate-containing polymer according to claim 1 , wherein a number-average molecular weight of the phosphonate-containing polymer is 1 claim 1 ,500-8 claim 1 ,000.8. The phosphonate-containing polymer viscosity reducer for drilling fluid according to claim 7 , wherein the monomer A is 2-acrylamide-2-methyl propanephosphoric acid.9. The phosphonate-containing polymer viscosity reducer for drilling fluid according to claim 7 , wherein the monomer B is one or more selected from the group consisting of 2-acrylamide-2-methyl propane sulfonic acid claim 7 , sodium vinyl sulfonate claim 7 , sodium p-styrene sulfonate claim 7 , and sodium allyl sulfonate.10. The ...

Triggerable Lost Circulation Material and Method of Use

Methods for preventing or alleviating the loss of drilling fluids and other well treatment fluids into a subterranean formation during drilling or construction of boreholes therein include a drilling fluid including a lost circulation material. The lost circulation material includes a suspension of swelled particles of a pH sensitive polymeric material, the swelled particles capable of reversibly attaching to other swelled particles of the polymeric material. The pH of the aqueous solution is such that each particle of the swelled pH sensitive polymeric material is not attached to other swelled particles, and wherein upon lowering the pH of the suspension, the swelled particles attach to each other. 1. A method comprising:introducing directly into a subterranean zone penetrated by a wellbore, a mixture having a first pH, the mixture containing separate swelled particles of a polymeric material capable of reversibly attaching to other swelled particles of the polymeric material, andintroducing a material sufficient to lower the pH of the polymeric material to a second pH lower than the first pH, thereby resulting in the swelled particles attaching to each other.2. The method of claim 1 , wherein the first pH is from 4 to 14.3. The method of claim 1 , wherein the first pH is from 7 to 14.4. The method of claim 1 , wherein the second pH is 4 or less.5. The method of claim 1 , wherein the second pH is 3 or less.6. The method of claim 1 , wherein the swelled particles are comprised of a polymer of an N-acryloyl acid.7. The method of claim 6 , wherein the N-acryloyl acid is N-acryloyl 6-aminocaproic acid.8. The method of claim 7 , wherein the polymer of N-acryloyl 6-aminocaproic acid is polymerized by free-radical polymerization.9. A method comprising:introducing directly into a subterranean zone penetrated by a wellbore, a mixture having a first pH, the mixture containing separate swelled particles of a polymeric material capable of reversibly attaching to other swelled ...

METHOD FOR TREATING MINERAL SLURRIES WITH A BIOCIDE

A method of treating mineral slurries to inhibit bacterial growth includes adding an effective amount of one or more of sodium N-methyldithiocarbamate or methylammonium monomethyldithiocarbamate to the mineral slurry to inhibit bacterial growth. 1. In a method of treating a mineral slurry to inhibit bacterial growth by adding an effective amount of a biocide to the mineral slurry , the improvement comprising adding an effective amount of one or more of sodium or potassium N-methyldithiocarbamate and methylammonium monomethyldithiocarbamate to the mineral slurry to inhibit bacterial growth.2. The method claim 1 , wherein the effective amount further comprises 0.04-0.45% by weight based on the total formulation.3. The method of claim 1 , wherein the mineral slurry further comprises a slurry containing water and one or more of a starch claim 1 , a clay claim 1 , calcium carbonate claim 1 , or titanium dioxide.4. The method of claim 3 , wherein the clay is a kaolin clay and the calcium carbonate is a ground or precipitated calcium carbonate.5. The method of claim 3 , wherein the water is fresh water or reclaimed water.6. The method of claim 1 , further comprising adding an effective amount of an additional biocide selected from the group consisting of glutaraldehyde claim 1 , 1 claim 1 ,2 benzithiazolin-3-one claim 1 , tetrahydro-3-5-methyl-2H-1 claim 1 ,3 claim 1 ,5-thiadizine-2-thione claim 1 , isothiazoline claim 1 , bronopol claim 1 , 2 claim 1 ,2-dibromo-3-nitrilopropionamide claim 1 , or orthophenyl phenate.7. In a method of treating water used in an oil field application to inhibit bacterial growth by adding an effective amount of a biocide to the water claim 1 , the improvement comprising adding an effective amount of methylammonium monomethyldithiocarbamate to the water to inhibit bacterial growth.8. The method claim 7 , wherein the effective amount further comprises 200-4500 ppm weight based on the total formulation.9. The method of claim 7 , wherein the water ...

POLYOXALATES AND A PROCESS FOR THE PRODUCTION THEREOF

A polyoxalate containing, as a chief constituent unit, a recurring unit represented by the following formula (1): —(—CO—CO—O-A-O—)— wherein n is a positive number, and A is a divalent organic group, and having a quantity of heat of fusion ΔHm of not less than 60 J/g as measured by DSC in the first time of elevating the temperature, thereby permitting the components to be volatilized in an amount of not more than 2.0% by weight when the temperature is elevated up to 200° C. as measured by the TGA, and having a 5% weight loss temperature (Td5%) of not higher than 230° C. Also disclosed is a process for production of the polyoxalate. 2. The polyoxalate according to claim 1 , wherein the organic group A in the recurring unit is an ethylene glycol residue.3. The polyoxalate according to claim 1 , wherein the recurring unit is contained in an amount of not less than 90 mol %.4. A process for producing a polyoxalate by the esterification/polymerization reaction of an oxalic acid diester and a dialcohol in the absence of solvent by using a polymerization reactor equipped with a distill-off pipe that has a vertex portion claim 1 , comprising:executing the esterification/polymerization reaction in the polymerization reactor in two steps of polymerization under normal pressure accompanied by the removal of alcohol from the oxalic acid diester and polymerization under reduced pressure accompanied by the removal of dialcohol following the polymerization under normal pressure, wherein:in the step of polymerization under normal pressure, the distill-off pipe of from the reactor up to the vertex portion is at least partly maintained at a temperature which is not higher than the boiling point of the alcohol that is distilled off plus 6° C. in order to suppress the distillation of the oxalic acid diester; andthe step of polymerization under reduced pressure is executed maintaining the temperature of the reaction solution in the polymerization reactor at 180 to 210° C.5. The ...

Lubricant Compositions Comprising Diol Functional Groups and Methods of Making and Using Same

Lubricant compositions having at least one base oil composition including about 1.0 to about 15.0 wt % water, and a friction-reducing composition including a glycerol or thioglycerol compositions are described. Methods for making such lubricant compositions and methods of drilling using such lubricant compositions are also described. 2. The composition of claim 1 , wherein T is O or S and Ris selected from Cto Chydrocarbyl groups.3. The composition of claim 1 , wherein T is C(O)O and Ris selected from n-dodecyl (lauryl) claim 1 , n-tetradecyl (myristyl) claim 1 , n-hexadecyl (palmityl) claim 1 , n-octadecyl (stearyl) claim 1 , n-9-octadecenyl (oleyl) claim 1 , and n-eicosenyl groups claim 1 , and at least one X is H.4. The composition of claim 1 , wherein the compound according to Formula I is selected from glycerol monostearate claim 1 , glycerol mono-oleate claim 1 , glycerol di-stearate claim 1 , and glycerol di-oleate.5. The composition of claim 1 , wherein T is O or S and R1 is selected from n-dodecyl (lauryl) claim 1 , n-tetradecyl (myristyl) claim 1 , n-hexadecyl (palmityl) claim 1 , n-octadecyl (stearyl) claim 1 , n-9-octadecenyl (oleyl) claim 1 , and n-eicosenyl groups.6. The composition of claim 1 , wherein T is O or S and Ris selected from n-dodecyl (lauryl) claim 1 , n-tetradecyl (myristyl) claim 1 , n-hexadecyl (palmityl) claim 1 , n-octadecyl (stearyl) claim 1 , n-9-octadecenyl (oleyl) claim 1 , and n-eicosenyl groups claim 1 , and at least one X is H.8. The method of claim 7 , wherein T is O or S and Ris selected from Cto Chydrocarbyl groups.9. The method of claim 7 , wherein T is C(O)O and Ris selected from n-dodecyl (lauryl) claim 7 , n-tetradecyl (myristyl) claim 7 , n-hexadecyl (palmityl) claim 7 , n-octadecyl (stearyl) claim 7 , n-9-octadecenyl (oleyl) claim 7 , and n-eicosenyl groups claim 7 , and at least one X is H.10. The method of claim 7 , wherein the compound according to Formula I is selected from glycerol monostearate claim 7 , glycerol ...

Glycerol Carbamate Based Lubricant Compositions and Methods of Making and Using Same

A lubricant composition having at least one base oil composition and a friction-reducing composition comprising at least a first glycerol carbamate compound are described. Methods for making such compounds and methods of drilling using such lubricant compositions are also described. 1. A lubricant composition comprising:a) at least one base oil composition andb) a friction-reducing composition comprising at least a first glycerol carbamate compound.3. The lubricant composition of claim 2 , wherein Ris CH(CH)C═C(CH)CH— claim 2 , wherein x ranges from 5 to 10 and y ranges from 5 to 10.5. The lubricant composition of claim 4 , wherein Ris CH(CH)C═C(CH)CH— claim 4 , wherein x ranges from 5 to 10 and y ranges from 5 to 10.6. The lubricant composition of claim 4 , wherein the friction-reducing composition comprises about 1 to about 99 mol % of the first glycerol carbamate compound and about 1 to 99 mol % of the second glycerol carbamate compound claim 4 , based on the total number of moles of the first and second glycerol carbamate compounds.7. The lubricant composition of claim 1 , comprising about 50.0 to <100 wt % of the base oil composition and >0 to about 50 wt % of the friction reducing composition.8. The lubricant composition of claim 1 , having a coefficient of friction at least about 20% less than the coefficient of friction of the lubricant composition in the absence of the friction-reducing composition.9. A method of making a lubricant composition comprising:a) mixing a friction-reducing composition comprising at least a first glycerol carbamate compound and at least one base oil composition.11. The method of claim 9 , wherein Ris CH(CH)C═C(CH)CH— claim 9 , wherein x ranges from 5 to 10 and y ranges from 5 to 10.13. The method of claim 12 , wherein Ris CH(CH)C═C(CH)CH— claim 12 , wherein x ranges from 5 to 10 and y ranges from 5 to 10.14. The method of claim 9 , comprising about 50.0 to <100 wt % of the base oil composition and >0 to about 50 wt % of the ...

Lubricant Compositions and Methods of Making and Using Same

Lubricant compositions resulting from the combination of ≧about 90 wt % of at least one base oil composition having about 1.0 to about 15.0 wt % water therein and from about 1.0 to about 10.0 wt % of a friction-reducing composition are described. Methods of making such compositions and methods of using such compositions are also described. 2. The lubricant composition of claim 1 , wherein Rand Rare each (CH)— groups.4. The lubricant composition of claim 3 , wherein y is about 5 to about 10 and z is about 5 to about 10.5. The lubricant composition of claim 1 , having a coefficient of friction at least about 20% less than the coefficient of friction of the lubricant composition in the absence of the friction-reducing composition.9. The method of claim 8 , wherein y is about 5 to about 10 and z is about 5 to about 10.10. The lubricant composition of claim 6 , having a coefficient of friction at least about 20% less than the coefficient of friction of the lubricant composition in the absence of the friction-reducing composition.12. The lubricant composition of claim 11 , wherein Ris a —(CH)— group.14. The lubricant composition of claim 13 , wherein y is about 5 to about 10 and z is about 5 to about 10.16. The method of claim 15 , wherein Ris a —(CH)— group.18. The method of claim 17 , wherein y is about 5 to about 10 and z is about 5 to about 10.19. A method of providing a lubricant composition to a drilling operation claim 17 , comprising:a) providing to said drilling operation at least one base oil composition, the base oil composition comprising about 1.0 to about 15.0 wt % water;b) operating said drilling operation for a period of time with said base oil composition; and{'claim-ref': {'@idref': 'CLM-00001', 'claim 1'}, 'c) adding to the drilling operation a friction-reducing composition of .'}20. The method of claim 19 , wherein adding the friction-reducing composition comprises adding the friction-reducing composition at a rate sufficient to provide a concentration ...

Lubricant Compositions Containing Phosphates and/or Phosphites and Methods of Making and Using Same

A lubricant compositions having at least one base oil composition and a friction-reducing composition including a substituted phosphate ester and/or substituted hydrogen phosphites are described. Methods for making such compounds and methods of drilling using such lubricant compositions are also described.

Lubricant Compositions and Methods of Making and Using Same

Lubricant compositions having at least one base oil composition and a friction-reducing composition comprising at least a first diol compound are described. Methods for making such compounds and methods of drilling using such lubricant compositions are also described. 2. The lubricant composition of claim 1 , one or more of R claim 1 , R claim 1 , or Ris H.3. The lubricant composition of claim 1 , wherein Ris selected from unbranched Cto Calkyl groups claim 1 , and wherein R claim 1 , R claim 1 , and Rare each H.4. The lubricant composition of claim 1 , wherein the at least one compound represented by Formula I comprises 1 claim 1 ,2-decanediol; 1 claim 1 ,2-undecanediol; 1 claim 1 ,2-dodecanediol; 1 claim 1 ,2-tridecanediol; 1 claim 1 ,2-tetradecanediol; 1 claim 1 ,2-pentadecanediol; 1 claim 1 ,2-hexadecanediol; 1 claim 1 ,2-heptadecanediol; 1 claim 1 ,2-octadecanediol; 1 claim 1 ,2-˜nonadecanediol; 1 claim 1 ,2-eicosanediol; 1 claim 1 ,2-heneicosanediol; 1 claim 1 ,2-docosanediol; 1 claim 1 ,2-tricosanediol; or 1 claim 1 ,2-tetracosanediol.5. The lubricant composition of claim 1 , wherein the at least one compound represented by Formula I comprises 1 claim 1 ,2-octadecanediol.6. The lubricant composition of claim 1 , wherein the composition comprises ≦0.01 wt % of a phosphorus compound represented by Formula III:{'br': None, 'sup': '5', 'sub': '2', '(RO)PH═O \u2003\u2003Formula III'}{'sup': '5', 'wherein Ris an alkyl group or an alkenyl group with from 12 to 18 carbon atoms.'}8. The method of claim 7 , wherein one or more of R claim 7 , R claim 7 , or Ris H.9. The method of claim 7 , wherein Ris selected from unbranched Cto Calkyl groups claim 7 , and wherein R claim 7 , R claim 7 , and Rare each H.10. The method of claim 7 , wherein the at least one compound represented by Formula I comprises 1 claim 7 ,2-decanediol; 1 claim 7 ,2-undecanediol; 1 claim 7 ,2-dodecanediol; 1 claim 7 ,2-tridecanediol; 1 claim 7 ,2-tetradecanediol; 1 claim 7 ,2-pentadecanediol; 1 ...

Methods and Compositions for In-Situ Polymerization Reaction to Improve Shale Inhibition

A method of modifying an alteration zone of a formation near a wellbore using a non-Newtonian polymeric composition created from a reaction of a non-Newtonian combination comprises the steps of mixing an anhydrous tetraborate and a fluid to create a crosslinker solution, mixing a crosslinkable polyvinyl alcohol and water to create a polymer solution, where the crosslinker solution and the polymer solution form the non-Newtonian combination, pumping the non-Newtonian combination to a reaction zone in the wellbore, where pumping the non-Newtonian combination is configured to induce mixing of the polymer solution and the crosslinker solution, allowing the non-Newtonian combination to react to form the non-Newtonian polymeric composition, allowing the non-Newtonian polymeric composition to migrate to the alteration zone, where the non-Newtonian polymeric composition migrates due to gravity, and allowing the non-Newtonian polymeric composition to interact with the alteration zone to modify the alteration zone. 1. A method of modifying an alteration zone of a formation near a wellbore using a non-Newtonian polymeric composition created from a reaction of a non-Newtonian combination , the method comprising the steps of:mixing an anhydrous tetraborate and a fluid to create a crosslinker solution; 'wherein the crosslinker solution and the polymer solution form the non-Newtonian combination;', 'mixing a polyvinyl alcohol solution and a polyvinyl acetate solution to create a polymer solution,'} 'wherein a rate of dissolution of the polymer solution depends on the temperature in the reaction zone;', 'pumping the non-Newtonian combination to a reaction zone in the wellbore, wherein the pumping of the non-Newtonian combination is configured such that the crosslinker solution is isolated from the polymer solution until the reaction zone, the reaction zone being defined as a point which allows the reaction between the crosslinker solution and the polymer solution to proceed to a ...

Chitin nanocrystal containing wellbore fluids

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

CROSSLINKED POLYMER COMPOSITIONS WITH TWO CROSSLINKERS FOR USE IN SUBTERRANEAN FORMATION OPERATIONS

A crosslinked polymer comprising reactants of a first repeating unit, a second repeating unit, a first crosslinker, and a second crosslinker that react to form the crosslinked polymer, wherein the first repeating unit is a sulfonic acid-containing monomer present from 50% to 99% by weight of the reactants, wherein the second repeating unit is selected from the group consisting of an N-vinyl amide-containing monomer, a terminal double bond-containing monomer, and any combination thereof, and is present from 1% to 50% by weight of the reactants, wherein the first crosslinker comprises at least two olefinic bonds, wherein the second crosslinker comprises at least two olefinic bonds, and wherein the first and second crosslinkers combined are present in the range of about 0.01% to about 25% by weight of the reactants. 1. A crosslinked polymer comprising: wherein the first repeating unit is a sulfonic acid-containing monomer present from 50% to 99% by weight of the reactants,', 'wherein the second repeating unit is selected from the group consisting of an N-vinyl amide-containing monomer, a terminal double bond-containing monomer, and any combination thereof, and is present from 1% to 50% by weight of the reactants,', 'wherein the first crosslinker comprises at least two olefinic bonds,', 'wherein the second crosslinker comprises at least two olefinic bonds, and', 'wherein the first and second crosslinkers combined are present in the range of about 0.01% to about 25% by weight of the reactants., 'reactants of a first repeating unit, a second repeating unit, a first crosslinker, and a second crosslinker that react to form the crosslinked polymer,'}2. The crosslinked polymer of claim 1 , wherein the first crosslinker is a crosslinker with at least two allyl groups claim 1 , andthe second crosslinker is selected from the group consisting of a crosslinker with at least two vinyl groups; a crosslinker with at least two acrylate groups; a crosslinker with at least two ...

Flaky Date Fruit Qulansuwa (CAP) for Moderate to Severe Loss Control

A lost circulation material (LCM) having date fruit caps is provided. The date fruit cap LCM includes date fruit caps from a date tree. The date fruit caps have multiple flakes (for example, three flakes) attached at one end to an end cap and free at the other end. The date fruit caps may be obtained from the waste product of date tree and date fruit processing. The date fruit cap LCM may be added to a drilling fluid (for example, a drilling mud) to mitigate or prevent such lost circulation in a well. Methods of lost circulation control with the date fruit cap LCM are also provided.

Date Tree Waste-Based Compound Fibrous LCMs

A date tree waste-based lost circulation material (LCM) is provided. The date tree waste LCM may include includes fibers from the date tree waste produced from processing date trees in the production of date fruits. The date tree waste may include fibers from one or more of the following: date tree trunks, date tree rachis, date tree leaflets, date tree panicles, and date tree roots. The date tree waste LCM may include fibers having lengths in the range of 5 millimeters (5 mm) to 15 mm, diameters in the range of 0.5 mm to 0.8 mm, and having an aspect ratio range of 6 to 30. Methods of lost circulation control using and manufacture of a date tree waste LCM are also provided. 1. A method to control lost circulation in a lost circulation zone in a wellbore , comprising:introducing an altered drilling fluid into the wellbore such that the altered drilling fluid contacts the lost circulation zone and reduces a rate of lost circulation into the lost circulation zone, where the altered drilling fluid comprises a drilling fluid and a lost circulation material (LCM), wherein the LCM comprises a plurality of date tree waste fibers produced from date tree waste, wherein the date tree waste comprises waste from date palm processing.2. The method of claim 1 , wherein the altered drilling fluid consists of the drilling fluid and the LCM.3. The method of claim 1 , wherein the LCM consists of the plurality of date tree waste fibers produced from date tree waste.4. The method of claim 1 , wherein the date tree waste comprises at least one of: date tree trunks claim 1 , date tree rachis claim 1 , date tree leaves claim 1 , date tree leaflets claim 1 , and date tree roots.5. The method of claim 1 , wherein the date tree waste fibers comprise fibers produced from at least one of: date tree trunks claim 1 , date tree rachis claim 1 , date tree leaves claim 1 , date tree leaflets claim 1 , and date tree roots.6. The method of claim 1 , wherein the plurality of date tree waste fibers ...

CROSSLINKED POLYMER COMPOSITIONS FOR USE IN SUBTERRANEAN FORMATION OPERATIONS

A crosslinked polymer comprising reactants of a first repeating unit, a second repeating unit, and a crosslinker that react to form the crosslinked polymer, wherein the first repeating unit is a sulfonic acid-containing monomer present from 50% to 99% by weight of the reactants, wherein the second repeating unit is selected from the group consisting of an N-vinyl amide-containing monomer, a terminal double bond-containing monomer, and any combination thereof, and is present from 1% to 50% by weight of the reactants, and wherein the crosslinker comprises at least two olefinic bonds, and is present in the range of about 9% to about 25% by weight of the reactants. 1. A crosslinked polymer comprising: wherein the first repeating unit is a sulfonic acid-containing monomer present from 50% to 99% by weight of the reactants,', 'wherein the second repeating unit is selected from the group consisting of an N-vinyl amide-containing monomer, a terminal double bond-containing monomer, and any combination thereof, and is present from 1% to 50% by weight of the reactants, and', 'wherein the crosslinker comprises at least two olefinic bonds, and is present in the range of about 9% to about 25% by weight of the reactants., 'reactants of a first repeating unit, a second repeating unit, and a crosslinker that react to form the crosslinked polymer,'}2. The crosslinked polymer of claim 1 , wherein the sulfonic acid-containing monomer is selected from the group consisting of an acrylic sulfonic acid claim 1 , a methylallyl sulfonic acid claim 1 , an allyl sulfonic acid claim 1 , a styrene sulfonic acid claim 1 , a vinyl sulfonic acid claim 1 , a vinyl aromatic sulfonic acid claim 1 , any salt thereof claim 1 , and any combination thereof.3. The crosslinked polymer of claim 1 , wherein the sulfonic acid-containing monomer is selected from the group consisting of 2-acrylamido-2-methylpropane sulfonic acid claim 1 , 2-methacrylamido-2-methylpropanesulfonic acid claim 1 , α-methyl ...

Date Palm Seed-Based Lost Circulation Material (LCM)

A date palm seed-based lost circulation material (LCM) is provided. A date palm seed LCM may be manufactured by drying date palm seeds and grinding the dried date palm seeds to create a plurality of particles. The particles may have sizes less than 4 mm, from 1 mm to 2 mm, or from 2 mm to 4 mm. The date palm seed LCM may have a volumetric swelling greater than an LCM formed from tree nuts and may have a volumetric swelling of at least 0.3 cubic centimeters per gram. The date palm seed LCM may have a D50 shift factor less than an LCM formed from calcium carbonate and may have a D50 shift factor of at least 0.38%. The date palm seed LCM may have a stability index of at least 0.95. Methods of lost circulation control and manufacture of a date palm seed LCM are also provided. 1. A method to control lost circulation in a lost circulation zone in a wellbore , comprising:introducing an altered drilling fluid into the well bore such that the altered drilling fluid contacts the lost circulation zone and reduces a rate of lost circulation into the lost circulation zone, where the altered drilling fluid comprises a drilling fluid and a lost circulation material (LCM), and where the LCM comprises a plurality of untreated particles comprising ground date palm seeds.2. The method of claim 1 , comprising adding the lost circulation material to the drilling fluid to create the altered drilling fluid.3. The method of claim 1 , wherein the untreated particles consist of ground date palm seeds.4. The method of claim 1 , wherein the LCM consists of a plurality of untreated particles consisting essentially of ground date palm seeds.5. The method of claim 1 , wherein the altered drilling fluid consists of the drilling fluid and the LCM claim 1 , where the LCM consists essentially of a plurality of untreated particles consisting essentially of ground date palm seeds.6. The method of claim 1 , wherein the reduced rate of lost circulation is at least 80% less by volume than before ...

Date Tree Waste-Based Compound Fibrous LCMs

An altered drilling fluid having a drilling fluid and a date tree waste-based lost circulation material (LCM). The date tree waste LCM may include includes date tree waste fibers produced from one or more of the following: date tree trunks, date tree rachis, date tree leaflets, date tree panicles, and date tree roots. The date tree waste LCM may include fibers having lengths in the range of 5 millimeters (5 mm) to 15 mm, diameters in the range of 0.5 mm to 0.8 mm, and having an aspect ratio range of 6 to 30. Methods of manufacture of a date tree waste LCM are also provided. 1. An altered drilling fluid , comprising:a water-based drilling fluid or an oil-based drilling fluid; anda lost circulation material (LCM), wherein the LCM comprises a plurality of date tree waste fibers produced from at least one of: date tree trunks, date tree rachis, date tree leaves, date tree leaflets, and date tree roots, wherein each of the plurality of date tree waste fibers has a length in the range of 5 millimeters (mm) to 15 mm and the plurality of date tree waste fibers have a moisture content of less than 3% by weight.2. The altered drilling fluid of claim 1 , wherein the water-based drilling fluid comprises water claim 1 , a clay claim 1 , a water hardness remover claim 1 , and a base.3. The altered drilling fluid of claim 2 , wherein the water comprises freshwater or seawater.4. The altered drilling fluid of claim 2 , wherein the water hardness remover comprises soda ash.5. The altered drilling fluid of claim 2 , wherein the base comprises sodium hydroxide.6. The altered drilling fluid of claim 1 , wherein the water-based drilling fluid has a pH of at least 10.7. The altered drilling fluid of claim 1 , wherein the oil-based drilling fluid comprises a base oil claim 1 , a primary emulsifier claim 1 , a secondary emulsifier claim 1 , a viscosifier and filtrate control additive.8. The oil-based drilling fluid of claim 7 , wherein the base oil comprises diesel or crude oil.9. The ...

Lubricating compositions for use with downhole fluids

An aqueous-based downhole fluid having a lubricant therein may be circulated within a subterranean reservoir wellbore where the downhole fluid may be or include a drilling fluid, a completion fluid, a fracturing fluid, a drill-in fluid, a workover fluid, and combinations thereof. The lubricant may include a clay stabilizer and a vegetable oil derivative, such as but not limited to, a sulfonated vegetable oil. The downhole fluid may include the lubricant in an effective amount for lubricating a first surface.

Lost Circulation Drilling Fluids Comprising Elastomeric Rubber Particles and a Method for Decreasing Whole Mud Loss Using Such Composition

The disclosed invention is a unique drilling fluid composition and method for reducing lost mud circulation in wellbores due to seepage loss into fluid permeable subterranean formations. The drilling fluid composition comprises a variety of shapes and sizes of distinctive unadulterated elastomeric rubber particles derived from the tire retreading (recapping) process. These elastomeric rubber particles are incorporated into an aqueous, hydrocarbon, or synthetic drilling fluid in sufficient amounts as to plug holes, fractures, and fissures, form a mud cake, and thus stem the loss of drilling fluids from the lost circulation zone.

COMPOSITION AND USE THEREOF, OIL-BASED DRILLING FLUID AND A METHOD FOR RAISING SHEARING FORCE OF OIL-BASED DRILLING FLUID

A composition and use thereof are disclosed herein. The composition comprises at least two selected from the group of amphiphilic block copolymer, polyurethane and acidic ionic compound. Also an oil-based drilling fluid comprising the composition and a method improving shearing force of oil-based drilling fluid are disclosed. The composition disclosed herewith can raise the shearing force of oil-based drilling fluid. 2. The composition according to claim 1 , wherein on the basis of the total amount of the composition claim 1 , the content of the amphiphilic block copolymer is 10-50 wt % claim 1 , and the content of polyurethane is 50-90 wt %; orthe content of the amphiphilic block copolymer is 10-50 wt %, and the content of acidic ionic compound is 50-90 wt %; orthe content of the polyurethane is 55-95 wt %, and the content of acidic ionic compound is 5-45 wt %; orthe content of the amphiphilic block copolymer is 5-25 wt %, the content of the polyurethane is 55-75 wt %, the content of acidic ionic compound is 10-25 wt %.3. The composition according to claim 1 , wherein on the basis of the total amount of the composition claim 1 , the content of the amphiphilic block copolymer is 20-40 wt % claim 1 , and the content of polyurethane is 60-80 wt %; orthe content of the amphiphilic block copolymer is 20-40 wt %, and the content of acidic ionic compound is 60-80 wt %; orthe content of the polyurethane is 60-90 wt %, and the content of acidic ionic compound is 10-40 wt %; orthe content of the amphiphilic block copolymer is 10-20 wt %, the content of the polyurethane is 60-70wt %, the content of acidic ionic compound is 10-20 wt %.5. The composition according to claim 4 , wherein each of R claim 4 , R claim 4 , R claim 4 , R claim 4 , R claim 4 , R claim 4 , R claim 4 , R claim 4 , R claim 4 , Rand Ris H claim 4 , methyl claim 4 , ethyl claim 4 , propyl claim 4 , vinyl claim 4 , allyl claim 4 , propenyl claim 4 , phenyl or tolyl claim 4 , and at least one of R claim 4 , R ...

Stabilizing Formation Laminae in Coal Seam Wellbores

Methods including introducing a treatment fluid into a wellbore in a subterranean formation, wherein the subterranean formation includes a coal seam gas reservoir, a freshwater reservoir, and formation laminae interposed therebetween, and the wellbore penetrating each, and wherein the treatment fluid comprises an aqueous base fluid and an aqueous curable resin; penetrating at least a portion of the formation laminae with the aqueous curable resin while maintaining the treatment fluid in the wellbore at a pressure sufficient to prevent the flow of freshwater from the freshwater reservoir into the wellbore; curing the aqueous curable resin, thereby stabilizing the formation laminae; creating permeability pathways in the coal seam gas reservoir itself; removing the treatment fluid from the wellbore; recovering gas from the coal seam gas reservoir. 1. A method comprising: wherein the subterranean formation includes a coal seam gas reservoir, a freshwater reservoir, and formation laminae interposed therebetween, and the wellbore penetrating each,', 'and wherein the treatment fluid comprises an aqueous base fluid and an aqueous curable resin;, 'introducing a treatment fluid into a wellbore in a subterranean formation,'}penetrating at least a portion of the formation laminae with the aqueous curable resin while maintaining the treatment fluid in the wellbore at a pressure sufficient to prevent the flow of freshwater from the freshwater reservoir into the wellbore;curing the aqueous curable resin, thereby stabilizing the formation laminae;removing the treatment fluid from the wellbore; andrecovering gas from the coal seam gas reservoir.2. The method of claim 1 , wherein the aqueous curable resin is selected from the group consisting of an epoxy-based resin claim 1 , a novolak resin claim 1 , a polyepoxide resin claim 1 , a phenol-aldehyde resin claim 1 , a urea-aldehyde resin claim 1 , a urethane resin claim 1 , a phenolic resin claim 1 , a furan resin claim 1 , a furan/ ...

IMIDAZOLINIUM COMPOUNDS AS DUAL CORROSION INHIBITORS

A method comprises obtaining or providing a treatment fluid comprising an imidazolinium compound and placing the treatment fluid in a subterranean formation. The imidazolinium compound functions as a viscoelastic surfactant (VES) gelling agent and as a corrosion inhibitor. 2. The method of claim 1 , wherein the treatment fluid has a viscosity of about 30 cP to about 150 cP at a shear rate of about 20 sto about 200 sat about 225° F. in the presence of spent acid.3. The method of claim 1 , wherein Rand Rare each claim 1 , independently claim 1 , an optionally substituted C-Chydrocarbyl group; Ris a C-Chydrocarbyl group; and R-Rare each claim 1 , independently claim 1 , H or an optionally substituted C-Chydrocarbyl group.4. The method of claim 1 , wherein Rand Rare each claim 1 , independently claim 1 , an optionally substituted C-Chydrocarbyl group; Ris a C-Chydrocarbyl group; and R-Rare each H.5. The method of claim 1 , wherein Ris an unsubstituted C-Chydrocarbyl group; Ris a hydroxyl-substituted C-Chydrocarbyl group; Ris a C-Chydrocarbyl group; R-Rare each claim 1 , independently claim 1 , an H or an optionally substituted C-Chydrocarbyl group.6. The method of claim 1 , wherein Y is an organic counterion.7. The method of claim 6 , wherein the organic counterion is selected from the group consisting of an alkoxide claim 6 , a carboxylate claim 6 , an organic sulfate claim 6 , and an organic sulfonate.8. The method of claim 6 , wherein the organic counterion is an organic sulfate.9. The method of claim 6 , wherein the organic counterion is an organic sulfate of the formula ROSO claim 6 , wherein Rrepresents a C-Chydrocarbyl group.12. The method of claim 1 , wherein the treatment fluid exhibits viscoelastic behavior.13. The method of claim 1 , wherein the treatment fluid further comprises spent acid.14. The method of claim 1 , wherein the treatment fluid further comprises a gelling agent and a crosslinking agent.15. The method of claim 14 , wherein the gelling agent ...

Synthetic Acid and Associated Methods

Glycine is an organic compound that can be used in the making of a synthetic acid that obviates all the drawbacks of strong acids such as hydrochloric acid. The new compound is made by dissolving glycine in water, in a weight ratio of approximately 1:1 to 1:1.5. The solution is mixed until the glycine is essentially fully dissolved in the water. Once dissolution is complete, hydrogen chloride gas is dissolved in the solution to produce the new compound, which can be referred to as hydrogen glycine. Also disclosed is a method for adjusting the pH of a fluid, the method comprising adding an effective amount of a solution to the fluid for adjusting the pH thereof to a desired level, wherein the solution is prepared by mixing glycine in water to form a glycine solution; and adding hydrogen chloride to the glycine solution. 1. A synthetic acid made by a process comprising:dissolving glycine into water to generate a solution; andintroducing hydrogen chloride gas into the solution.2. The synthetic acid of claim 1 , wherein the dissolving comprises mixing the glycine into the water with the use of an eductor pump.3. The synthetic acid of claim 1 , wherein the introducing is performed with the use of an inline eductor.4. The synthetic acid of claim 1 , wherein the dissolving is performed with the use of an inline static mixer.5. The synthetic acid of claim 1 , wherein a corrosion level of the synthetic acid is about 0.04 mmpy.6. A synthetic acid formed from a combination of glycine claim 1 , water claim 1 , and hydrogen chloride.7. The synthetic acid of claim 6 , wherein a corrosion level of the synthetic acid is about 0.04 mmpy. This application is a Continuation of, and claims priority to, U.S. patent application Ser. No. 16/915,204, filed Jun. 29, 2020, which itself is a Continuation of, and claims priority to, U.S. patent application Ser. No. 16/433,760, filed Jun. 6, 2019, now U.S. Pat. No. 10,723,640, which itself is a Continuation of, and claims priority to U.S. ...

DELAYED ENHANCEMENT OR BREAKING OF VISCOSITY FOR VISCOELASTIC SURFACTANT CONTAINING WELLBORE FLUIDS

A wellbore fluid is provided having controllable viscosity, which includes a brine having a monovalent salt and/or a polyvalent salt; an encapsulated monovalent salt and/or an encapsulated polyvalent salt; and a viscoelastic surfactant, where the wellbore fluid contains at least one monovalent salt and at least one polyvalent salt in the form of a brine and/or an encapsulated salt. 1. A wellbore fluid having controllable viscosity , comprisinga brine comprising a monovalent salt and/or a polyvalent salt;an encapsulated monovalent salt and/or an encapsulated polyvalent salt; anda viscoelastic surfactant,wherein the wellbore fluid contains at least one monovalent salt and at least one polyvalent salt in the form of a brine and/or an encapsulated salt.2. The wellbore fluid of claim 1 , wherein the viscoelastic surfactant is amphoteric or zwitterionic.3. The wellbore fluid of claim 1 , wherein the viscoelastic surfactant is a betaine surfactant.4. The wellbore fluid of claim 3 , wherein the betaine surfactant is oleylamidopropyl betaine surfactant.5. The wellbore fluid of claim 1 , wherein the viscoelastic surfactant is an amidoamine oxide surfactant.6. The wellbore fluid of claim 5 , wherein the amidoamine oxide surfactant is a tallowalkylamidopropyl dimethylamine oxide surfactant7. The wellbore fluid of claim 1 , wherein the release mechanism of the encapsulated monovalent salt and/or the encapsulated polyvalent salt is upon exposure to an external stimulus comprising one or more of heat claim 1 , pH claim 1 , enzymatic degradation claim 1 , or the presence of a solvent capable of solubilizing the encapsulant.8. The wellbore fluid of claim 1 , wherein the encapsulated monovalent salt and/or the encapsulated polyvalent salt comprises one or more encapsulated monovalent salts and/or encapsulated polyvalent salts having different release profiles or release mechanisms.9. The wellbore fluid of claim 1 , wherein the encapsulated monovalent salt and/or the encapsulated ...

TWO-COMPONENT LOST CIRCULATION PILL FOR SEEPAGE TO MODERATE LOSS CONTROL

A two-component lost circulation material (LCM) is provided having a polymer component and a sodium hydroxide component. The polymer component may include a carrier fluid such as water, a particulate material such as fly ash, a fibrous material such as polypropylene fibers, and an acrylic polymer. The sodium hydroxide component may include water and sodium hydroxide. The sodium hydroxide component is introduced to contact the polymer component to form the two-component LCM. Methods of lost circulation control and manufacture of a two-component LCM are also provided. 1. A lost circulation material (LCM) composition , comprising: a carrier fluid;', 'fly ash;', 'polypropylene fibers; and', 'an acrylic polymer; and, 'a first component comprisinga second component comprising sodium hydroxide.2. The LCM composition of claim 1 , wherein the carrier fluid of the first component comprises water.3. The LCM composition of claim 1 , wherein the LCM composition consists of the first component and the second component.4. The LCM composition of claim 1 , wherein the first component consists of:the carrier fluid;fly ash;polypropylene fibers; andthe acrylic polymer.5. The LCM composition of claim 1 , wherein the second component comprises water.6. The LCM composition of claim 5 , wherein the second component consists of sodium hydroxide and water.7. The LCM composition of claim 5 , wherein the second component comprises 25% by weight of the sodium hydroxide.8. The LCM composition of claim 1 , wherein the fly ash of the first component comprises an amount in the range of 200 grams to 400 grams.9. The LCM composition of claim 1 , wherein the polypropylene fibers of the first component comprises an amount in the range of 2 grams to 6 grams.10. The LCM composition of claim 1 , wherein the acrylic polymer comprises an acrylic polymer solution comprising water and at least 30% by weight acrylic polymer.11. The LCM composition of claim 10 , wherein the acrylic polymer solution of the first ...

Synergist for water-based drilling fluid and preparation method therefor, water-based drilling fluid and application thereof

The present disclosure provides a synergist for a water-base drilling fluid and a preparation method therefor, a water-base drilling fluid and an application thereof, and belongs to the field of drilling fluid technologies. The synergist is prepared from raw materials comprising the following parts by weight: 15˜25 parts of sodium styrene sulfonate, 8˜15 parts of allyl trimethyl ammonium chloride, 2˜8 parts of didodecyldimethylammonium bromide, 1˜5 parts of n-octyl triethoxysilane, 1˜5 parts of propyltriethoxysilane, 1˜5 parts of disodium lauryl sulfosuccinate, 10˜20 parts of nano silica, 8˜15 parts of paraffin, and the like.

Re-assembling polymer particle package for conformance control and fluid loss control

This invention is broadly concerned with compositions and processes for oilfield applications. More specifically, this invention relates to novel polymer constructed packages that, when pumped into a petroleum well, provide tunable characteristics of transformation and delayed self-assembly with each other under reservoir conditions to yield strong, elastic, bulk gel materials. The compositions comprise a polymer, assembling agents, and optional additives used for the re-assembly stage are uniformly-distributed within the initial gel particles. The polymer particle packages absorb water and swell upon exposure to water, thus exposing the “assembling agents” that enable re-assembly. Both swelling and re-assembly are proportionally controlled via compositions to be tunable to allow functional dispersion and subsequent self-assembly under various reservoir conditions.

POLYLACTIC ACID COMPOSITION

A polylactic acid composition of a dispersion structure using, as a matrix, a lowly crystalline or amorphous polylactic acid having a crystallinity of not more than 40%, the matrix containing, as a pulverization promotor dispersed therein, an organically modified polysaccharide or a lamellar silicate that is swollen or that is treated to be swollen. 1. A polylactic acid composition of a dispersion structure using , as a matrix , a lowly crystalline or amorphous polylactic acid having a crystallinity of not more than 40% , the matrix containing , as a pulverization promotor dispersed therein , an organically modified polysaccharide or a lamellar silicate that is swollen or that is treated to be swollen.2. The polylactic acid composition according to claim 1 , wherein as the polylactic acid claim 1 , use is made of a DL-isomer in which an L-isomer and a D-isomer are contained at a weight ratio (L/D) in a range of 98/2 to 2/98.3. The polylactic acid composition according to claim 2 , wherein the polylactic acid composition assumes the granular form having a grain size of not more than 1000 μm.4. The polylactic acid composition according to claim 1 , wherein the pulverization promotor is contained in an amount of 1 to 10 parts by weight per 100 parts by weight of the polylactic acid.5. The polylactic acid composition according to claim 1 , wherein as the lamellar silicate that is the pulverization promotor claim 1 , use is made of a montmorillonite in which organic cations are introduced or a synthetic mica.6. The polylactic acid composition according to claim 1 , wherein the polylactic acid composition is used for the preparation of an aqueous dispersion solution for drilling. This invention relates to a polylactic acid composition obtained by blending a polylactic acid with a fracture promotor.The polylactic acid has been known as a resin having excellent biodegradable property. From the standpoint of improving environments, study has now been forwarded in an attempt ...

SMART LCM FOR STRENGTHENING EARTHEN FORMATIONS

Methods for treating an earthen formation may include: drilling at least a section of a wellbore using a first wellbore fluid containing a first base fluid, and a first LCM-forming component; injecting, upon experience of a fluid loss, a second wellbore fluid containing a second base fluid, and a second LCM-forming component; and reacting the first LCM-forming component with the second LCM-forming component to form an LCM that reduces the fluid loss. A fluid system may include a first component containing a first base fluid and a first LCM-forming component; and a second component containing a second base fluid and a second LCM-forming component, wherein the second LCM-forming component is capable of reacting with the first LCM-forming component to form a LCM. 1. A method comprising: a first base fluid, and', 'a first LCM-forming component;, 'drilling at least a section of a wellbore using a first wellbore fluid comprising a second base fluid, and', 'a second LCM-forming component; and, 'injecting, upon experience of a fluid loss, a second wellbore fluid comprisingreacting the first LCM-forming component with the second LCM-forming component to form an LCM that reduces the fluid loss.2. The method of claim 1 , wherein the first base fluid is an invert emulsion.3. The method of claim 1 , further comprising resuming drilling operations after the formed LCM reduces fluid loss.4. The method of claim 1 , wherein injecting the second wellbore fluid comprises injecting the second wellbore fluid through an opening present on a drill bit and/or drill string.5. The method of claim 1 , wherein forming an LCM is triggered by temperature claim 1 , electromagnetic radiation claim 1 , pH claim 1 , or shear.6. The method of claim 1 , wherein the second LCM-forming component is encapsulated.7. The method of claim 5 , wherein the encapsulated second LCM-forming component remains encapsulated when exposed to shear forces below about 15 claim 5 ,000 s.8. The method of claim 6 , wherein ...

CONTROLLING SOLID SUSPENSION IN FLUIDS

A treatment to temporarily block highly permeable areas in a wellbore having a temperature of less than 160° F. A diverting agent, a catalyzer, and a viscosifier are mixed together and pumped in the wellbore where the treatment flows in the most highly permeable areas. The diverting agent then begins to block those areas as the well is treated finally causing the fluid to divert to other now more highly permeable areas of the wellbore. After less than 48 hours the diverting agent degrades sufficiently to restore the permeablility of the wellbore. 1. A fluid system for treating a well comprising:a diverting agent, wherein the diverting agent is a solid urea derivative,further wherein the diverting agent is present in an amount of from about 20 percent by weight of the fluid system to about 50 percent by weight of the fluid system,a viscosifier, anda catalyzing agent.2. The system of wherein claim 1 , the fluid system has a downhole temperature of 160° F. or less.3. The system of wherein claim 1 , the fluid system has a downhole temperature of 140° F. or less.4. The system of wherein claim 1 , the viscosifier is a guar gum.5. The system of wherein claim 1 , the viscosifier is a guar derivative.6. The system of wherein claim 1 , the viscosifier is a carboxymethylcellulose.7. The system of wherein claim 1 , the viscosifier is a cellulose derivative.8. The system of wherein claim 1 , the viscosifier is a polyacrylamide polymer.9. The system of wherein claim 1 , the viscosifier is a polyacrylamide copolymer.10. The system of wherein claim 1 , the diverting agent is a solid isobutylene urea.11. The system of wherein claim 1 , the diverting agent is a solid formaldehyde urea.12. The system of wherein claim 1 , the catalyzing agent is an organic acid.13. The system of wherein claim 12 , the organic acid is citric acid.14. The system of wherein claim 12 , the organic acid is acetic acid.15. The system of wherein claim 12 , the organic acid is formic acid.16. The system of ...

Synergistic Effect of Cosurfactants on the Rheological Performance of Drilling, Completion and Fracturing Fluids

The invention relates to the viscoelastic surfactant based fluids and methods for utilizing same in oilfield applications including, but not limited to gravel packing, cleanup, drilling, acidizing, fracturing and the like in a subterranean formation. The viscoelastic fluid of the invention comprises at least one amphoteric surfactant and at least one synergistic cosurfactant that increases the gel strength and extends the brine tolerance of said viscoelastic-based fluid. 2. The viscoelastic fluid of wherein in general formula (I) claim 1 , R1 is a fatty aliphatic group derived from natural fats or oils having an iodine value of from about 1 to 140.3. The viscoelastic fluid of wherein in general formula (I) claim 2 , R1 is a fatty aliphatic group derived from natural fats or oils having an iodine value of from 30 to 90.4. The viscoelastic fluid of wherein in general formula (I) claim 3 , R1 is a fatty aliphatic group derived from natural fats or oils having an iodine value of from 40 to 70.5. The viscoelastic fluid of wherein in general formula (I) claim 2 , R1 is a fatty aliphatic group derived from natural fats claim 2 , oils claim 2 , or petroleum stocks of a single chain length or of mixed chain length claim 2 , wherein said natural fats and oils or petroleum stocks are selected from tallow alkyl claim 2 , hardened tallow alkyl claim 2 , rapeseed alkyl claim 2 , hardened rapeseed alkyl claim 2 , tall oil alkyl claim 2 , hardened tall oil alkyl claim 2 , coco alkyl claim 2 , oleyl claim 2 , erucyl claim 2 , soya alkyl or combinations and/or mixtures thereof.6. The viscoelastic fluid of wherein in the viscoelastic surfactant of general Formula (I) R1 is an unsaturated alkyl group having 21 carbons claim 1 , R2 and R3 are methyl group claim 1 , R4 is hydroxyl group claim 1 , k equals 3 claim 1 , both m and n are 1.7. The viscoelastic fluid of wherein the viscoelastic surfactant of general formula (I) is selected from erucamidopropyl hydroxypropyl sulfobetaine claim ...

Date Seed-based Multi-Modal Particulate Admixture for Moderate to Severe Loss Control

A date palm seed lost circulation material (LCM) is provided having a date palm seed admixture of date palm seed particles of various sizes. The date palm seed particles may have a size greater than about 2380 microns in a range of about 40% to about 42% by weight, particles having a size greater than about 595 microns and less than about 2381 microns in a range of about 46% to about 48% by weight, particles having a size greater than about 400 microns and less than about 596 microns in a range of about 4% to about 6% by weight, particles having a size less than about 210 microns in a range of about 4% to about 6% by weight, and particles having a size less than about 149 microns in a range of about 1% to about 3% by weight. Methods of lost circulation control using and manufacture of a date palm seed LCM are also provided. 1. A method to control lost circulation in a lost circulation zone in a wellbore comprising:introducing an altered drilling fluid into the well bore such that the altered drilling fluid contacts the lost circulation zone and reduces a rate of lost circulation into the lost circulation zone, where the altered drilling fluid comprises a drilling fluid and a lost circulation material (LCM), wherein the LCM comprises:a first plurality of untreated particles having a first particle size;a second plurality of the untreated particles having a second particle size, wherein the untreated particles comprise ground date palm seeds.2. The method of claim 1 , comprising adding the LCM to the drilling fluid to create the altered drilling fluid.3. The method of claim 1 , wherein the untreated particles consist of ground date palm seeds.4. The method of claim 1 , wherein the altered drilling fluid consists of the drilling fluid and the LCM.5. The method of claim 1 , wherein the first particle size comprises greater than 400 microns and the second particle size comprises less than 210 microns.6. The method of claim 1 , wherein the LCM comprises:a third plurality ...

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

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

COMPOSITIONS AND METHODS FOR SCAVENGING H2S

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

PROCESS AND DEVICE FOR THE PREPARATION OF AN ESTER IN GRANULE FORM

The present invention relates to a process for the preparation of an ester comprising an after-treatment of the ester to give an ester in granule form of defined particle size distribution, a device for carrying out this process, a process for the preparation of a thermoplastic composition comprising the ester prepared according to the invention, a process for the production of a shaped article comprising the ester according to the invention or the thermoplastic composition according to the invention, a process for the production of a packed product, a process for the production of an at least partly coated object, and uses of the esters according to the invention as an additive in various compositions. 3. The process according to claim 1 , wherein the particles obtainable as a particle stream in after-treatment step ee. havea mass mean particle size in the range of from 400 to 800 μm, andup to 20 wt. % of these particles have a particle size of less than 200 μm, andup to 20 wt. % of these particles have a particle size of more than 1,000 μm.4. The process according to claim 1 , wherein the particles obtainable as a particle stream in after-treatment step ee. havea mass mean particle size in the range of from 400 to 800 μm, andup to 15 wt. % of these particles have a particle size of less than 200 μm, andup to 15 wt. % of these particles have a particle size of more than 1,000 μm.5. The process according to claim 1 , wherein the entry temperature of the cooling fluid is in a range of from −5 to +30° C.6. The process according to claim 1 , wherein the contact region is flowed through by the cooling fluid with a flow rate in a range of from 10 claim 1 ,000 to 60 claim 1 ,000 m/h.7. The process according to claim 1 , wherein the fluid stream prior to atomization is charged with a pressure in a range of from 1 claim 1 ,500 to 40 claim 1 ,000 mbar.8. The process according to claim 1 , wherein the carboxylic acid component is chosen from the group consisting of caprylic ...

FLUID LOSS ADDITIVE FOR WATER BASED DRILLING FLUIDS WITH IMPROVED THERMAL STABILITY

A polymer microsphere for use as a fluid loss additive in drilling muds including a hydrophobic core of hydrophobic monomers and a hydrophilic shell of hydrophilic monomers wherein the hydrophilic shell surrounds the hydrophobic core. The polymer microsphere is capable of forming micelles or microgels in water without using surfactants and can be block, graft, and random copolymers. The hydrophilic shell is physically or chemically linked to the hydrophobic core. The polymer microsphere further includes crosslinkers, preferably where the crosslinkers are monomers containing at least two ethylenically unsaturated groups. 1. A polymer microsphere for use as a fluid loss additive comprising:a hydrophobic core of hydrophobic monomers; anda hydrophilic shell of hydrophilic monomers;wherein the hydrophilic shell surrounds the hydrophobic core.2. The polymer microsphere of wherein each polymer microsphere has a particle size of between about 0.01 to about 1000 microns.3. The polymer microsphere of wherein each polymer microsphere has a particle size of between about 0.1 and about 100 microns.4. The polymer microsphere of wherein the polymer microsphere is capable of forming micelles or microgels in water without using surfactants.5. The polymer microsphere of wherein each polymer microsphere is selected from the group consisting of block claim 1 , graft claim 1 , and random copolymers.6. The polymer microsphere of wherein the hydrophilic shell is physically or chemically linked to the hydrophobic core.7. The polymer microsphere of wherein the hydrophobic monomers are selected from a group consisting of styrene claim 1 , substituted styrene claim 1 , alkyl acrylate claim 1 , alkyl methacrylate claim 1 , acrylonitrile claim 1 , methacrylonitrile claim 1 , N-alkyl acrylamide claim 1 , N-alkyl methacrylamide claim 1 , vinyl acetate claim 1 , vinyl esters claim 1 , N-vinylamides claim 1 , isoprene claim 1 , butadiene claim 1 , diesters of maleic claim 1 , fumaric claim 1 , and ...

Crosslinked polymer compositions and methods for use in subterranean formation operations

A crosslinked polymer comprising reactants of a first repeating unit, a second repeating unit, and a crosslinker that react to form the crosslinked polymer, wherein the first repeating unit is a sulfonic acid-containing monomer present from 1% to 45% by weight of the reactants, wherein the second repeating unit is selected from the group consisting of an N-vinyl amide-contain ing monomer, a terminal double bond-containing monomer, and any combination thereof, and is present from 55% to 99% by weight of the reactants, and wherein the crosslinker comprises at least two olefinic bonds.

FLAVONOID AND PLANT PHENOLIC ACID ADDITIVES FOR DOWNHOLE FLUIDS

A downhole fluid includes an additive composition, wherein the additive composition includes a flavonoid or a plant phenolic acid. A method includes circulating a downhole fluid composition into a subterranean reservoir wellbore, wherein the downhole fluid composition includes an additive composition, wherein the additive composition includes a flavonoid or a plant phenolic acid 1. A downhole fluid , comprising an additive composition , wherein the additive composition comprises a flavonoid or a plant phenolic acid.2. The downhole fluid of claim 1 , wherein the flavonoid is a flavonol glycoside naturally found in plants.4. The downhole fluid of claim 3 , wherein the sugar is glucose claim 3 , rhamnose claim 3 , galactose claim 3 , xylose and arabinose.5. The downhole fluid of claim 3 , wherein the flavonol glycoside is a kaempferol and Ris OH and Rand Rare H; or the flavonol glycoside is a quercetin and Rand Rare OH claim 3 , and Ris H.6. The downhole fluid of claim 3 , wherein the flavonol glycoside is rutin claim 3 , quercimetrin claim 3 , cyaroside claim 3 , hesperidin claim 3 , myricetin claim 3 , or a combination thereof.7. The downhole fluid of claim 1 , wherein the flavonoid or plant phenolic acid is added to a base fluid claim 1 , and wherein the base fluid is a drilling fluid claim 1 , a completion fluid claim 1 , a production fluid claim 1 , a servicing fluid claim 1 , an injection fluid claim 1 , a refinery fluid claim 1 , or a combination thereof.8. The downhole fluid of claim 7 , wherein the flavonoid or plant phenolic acid is in an amount of about 1 ppm to about 10 ppt as compared to the total base fluid.9. The downhole fluid of claim 1 , further comprising an additional additive claim 1 , wherein the additional additive is a winterizing agent claim 1 , a kinetic hydrate inhibitor claim 1 , a pour point depressant claim 1 , an anti-agglomerant claim 1 , a fracturing fluid additive claim 1 , or a combination thereof.10. The downhole fluid of claim 1 , ...

METHOD OF USING CATIONIC POLYMERS COMPRISING IMIDAZOLIUM GROUPS FOR PERMANENT CLAY STABILIZATION

Method of inhibiting the swelling of clay in subterranean formations by introducing carrier fluid comprising at least one clay inhibitor into the formation, wherein at least one of the clay inhibitors is a cationic polymer comprising imidazolium groups having a high weight average 118.-. (canceled)20. The method according to claim 19 , wherein the weight average molecular weight Mis from 70 claim 19 ,000 g/mol to 1 claim 19 ,000 claim 19 ,000 g/mol.21. The method according to claim 19 , wherein the weight average molecular weight Mis from 80 claim 19 ,000 g/mol to 600 claim 19 ,000 g/mol.22. The method according to claim 19 , wherein R claim 19 , R claim 19 , Rcomprise 4 to 20 carbon atoms.23. The method according to claim 19 , wherein R claim 19 , R claim 19 , Rcomprise at least one group selected from the group of ether groups claim 19 , secondary amino groups or tertiary amino groups and apart from these no further functional groups.24. The method according to claim 19 , wherein R claim 19 , R claim 19 , Rare aliphatic groups.25. The method according to claim 19 , wherein Ris a Cto Calkylene group.26. The method according to claim 19 , wherein Ris a Cto Calkylene group.27. The method according to claim 19 , wherein the cationic polymer comprises repeating units (Ia).28. The method according to claim 27 , wherein the amount of repeating units (Ia) is at least 80 mol % relating to the total amount of all repeating units.29. The method according to claim 19 , wherein Yis an anion of a mono- or polycarboxylic acid.30. The method according to claim 29 , wherein Yis an acetate ion.31. The method according to claim 19 , wherein the cationic polymer is available by reacting at least an α-dicarbonyl compound claim 19 , an aldehyde claim 19 , at least one amino compound having 2 to 4 primary amino groups claim 19 , and a protic acid with one another.32. The method according to claim 19 , wherein the concentration of the cationic polymers in the carrier fluid is from 0.001% ...

AMIDE BRANCHED AROMATIC GELLING AGENT BREAKERS

Breakers for gelling agents are disclosed, for example pyromellitamide gelling agents. The breakers include sulfonic acids in one example. 1. A method of breaking a gel , the gel comprising base fluid and gelling agent , each gelling agent having a pair of amide groups distributed about an aromatic core , each of the amide groups having one or more organic groups , the method comprising modifying the molecular structure of the gelling agent by using a breaker to cleave or make a covalent bond in the gelling agent.2. The method of in which modifying comprises cleaving a covalent bond in the gelling agent.3. The method of in which cleaving comprises cleaving one or more of the amide groups.4. The method of in which cleaving comprises converting a pair of the amide groups into an imide group.5. The method of in which the imide group and aromatic core form a phthalimide substructure.6. The method of in which the breaker acts as a catalyst for the modifying.7. The method of in which the breaker comprises an acid.8. The method of in which the acid comprises a sulfonic acid.9. The method of in which the sulfonic acid comprises para toluenesulfonic acid.10. The method of in which the sulfonic acid comprises one or more of Camphor-10-sulfonic acid claim 8 , ethane sulfonic acid claim 8 , 2-naphthalene sulfonic acid claim 8 , 2-sulfobenzoic acid hydrate claim 8 , benzene sulfonic acid claim 8 , and trifluoromethane sulfonic acid.11. The method of in which the acid comprises one or more of fluoroantimonic acid claim 7 , fluorosulfuric antimony pentafluoride claim 7 , and trifluoroacetic acid.12. The method of in which the breaker comprises a strong acid that is soluble in the base fluid.13. The method of in which the strong acid is a super acid.14. The method of further comprising claim 1 , prior to modifying claim 1 , supplying the breaker into the base fluid in particulate form claim 1 , each particulate having a coating shell.15. The method of in which the coating shell is ...

METHOD OF ENHANCING HYDRATION OF VISCOSIFIERS USING CONTROLLED MECHANICALLY INDUCED CAVITATION

A method of hydrating a dry powdered viscosifier such as a powdered polymer is disclosed. The method includes mixing the powdered viscosifier with a solvent such as water to form a mixture; moving the mixture through a cavitation zone; inducing energetic shock waves and pressure fluctuations in the mixture by mechanically inducing cavitation events within the mixture, the shock waves and pressure fluctuations untangling, separating, and straightening polymer molecule chains and distributing the chains throughout the mixture, and extracting the resulting hydrated viscosifier from the cavitation zone. 1. A method of enhancing hydration of a powdered viscosifier comprising the steps of:(a) introducing a viscosifier containing non-hydrated powdered particles into a flow of a solvent or hydrating fluid to produce a mixture;(b) feeding the mixture into a controlled cavitation reactor, wherein the mixture flows from sides of a rotor of the controlled cavitation reactor through a cavitation zone defined between an outer peripheral surface of the rotor and a wall of a housing of the controlled cavitation reactor, and into the rotor through a plurality of bores formed in the rotor(c) as the rotor of the controlled cavitation reactor is rotated, generating cavitation events within the mixture in a low shear environment within the controlled cavitation reactor;(d) controlling a rotor rotation rate as the mixture flows through the cavitation zone to control the cavitation events for generating shock waves that result in cavitation induced pressure variations that propagate through the mixture as the mixture flows through the cavitation zone to substantially separate and disperse the non-hydrated powdered particles of the viscosifier within the mixture and increase surface area contact between the solvent or hydrating fluid and the non-hydrated powdered particles of the viscosifier;(e) as a result of step (d), forcing solvent molecules into and out of the powder particles to ...

Additive to enhance sag stability of drilling fluid

A method including providing a drilling fluid that comprises a base fluid, a weighting agent, and a sag stability enhancer, wherein the sag stability enhancer comprises polyethylene glycol (PEG) having a molecular weight of greater than or equal to about 200 g/mol; and placing the drilling fluid in a subterranean formation via a wellbore penetrating the subterranean formation. A method including forming a fluid comprising a base fluid, a weighting agent, and from about 0.5 ppb (1.4 kg/m 3 ) to about 30 ppb (85.5 kg/m 3 ) of a sag stability enhancer, wherein the sag stability enhancer comprises a glycol; and introducing the fluid into at least a portion of a well. A drilling fluid containing a base fluid, a weighting agent, and a sag stability enhancer comprising polyethylene glycol (PEG) having a molecular weight of greater than or equal to about 200 g/mol.

SHALE SWELLING INHIBITORS

The present invention provides amidic polymers, which exhibit shale swelling inhibitor activity having improved bio-degradability. The amidic polymers of the invention may be employed in a wide variety of compositions, particularly in subterranean drilling operations. Non-limiting generic structures of the amidic polymers are set out below: (1) wherein R-Rand integers m and n are defined herein. 113-. (canceled)14. An amidic polymer comprising a (a) polymer having a hydroxyl group reacted with a (c) vinyl amide to provide the amidic polymer.15. The amidic polymer according to claim 14 , wherein the (a) polymer having a hydroxyl group is selected from the group consisting of partially and fully hydrolyzed poly(vinyl alcohol)s claim 14 , polysaccharides claim 14 , and mixtures thereof.16. The amidic polymer according to claim 15 , wherein the polysaccharides are derived from celluloses claim 15 , hydroxyethyl celluloses claim 15 , carboxymethyl celluloses claim 15 , hydroxyethyl celluloses claim 15 , hydropropyl celluloses claim 15 , hydroxypropyl methyl celluloses claim 15 , ethyl celluloses claim 15 , carageenans claim 15 , chitosans claim 15 , chondroitin sulfates claim 15 , heparins claim 15 , hyaluronic acids claim 15 , starches claim 15 , chitins claim 15 , perctins claim 15 , guars claim 15 , xanthans claim 15 , dextrans claim 15 , welan gums claim 15 , gellan gums claim 15 , diutans claim 15 , pullulana claim 15 , and mixtures thereof.17. The amidic polymer according to claim 14 , wherein the (c) vinyl amide is selected from the group consisting of N-vinyl pyrrolidone; N-vinyl piperidone; N-vinyl caprolactam; N-vinyl-3-methyl pyrrolidone; N-vinyl-4-methyl pyrrolidone; N-vinyl-5-methyl pyrrolidone; N-vinyl-3-ethyl pyrrolidone; N-vinyl-3-butyl pyrrolidone; N-vinyl-3 claim 14 ,3-dimethyl pyrrolidone; N-vinyl-4 claim 14 ,5-dimethyl pyrrolidone; N-vinyl-5 claim 14 ,5-dimethyl pyrrolidone; N-vinyl-3 claim 14 ,3 claim 14 ,5-trimethyl pyrrolidone; N-vinyl-5-methyl-5- ...

SYNTHESIZED LUBRICANTS FOR WATER-BASED DRILLING FLUID SYSTEMS

The present application discloses water-based drilling fluid systems and methods of making water-based drilling fluids systems. According to one embodiment, a drilling fluid system may include a drilling fluid and a lubricant. The lubricant may be synthesized from waste vegetable oil. 1. A water-based drilling fluid system comprising:a water-based drilling fluid; anda synthesized lubricant comprising a plant-based alkyl ester, and a plant-based free fatty acid;wherein the synthesized lubricant comprises more plant-based alkyl ester than plant-based free fatty acid.2. The water-based wellbore drilling fluid system of claim 1 , wherein the ratio of plant-based alkyl ester to plant-based free fatty acids is from 1.5:1 to 3:1 by weight.3. The water-based wellbore drilling fluid system of claim 1 , wherein the plant-based alkyl ester is derived from a plant-based oil.4. The water-based wellbore drilling fluid system of claim 3 , wherein the plant-based alkyl ester is derived from a waste vegetable oil.5. The water-based wellbore drilling fluid system of claim 1 , wherein the plant-based alkyl ester is a methyl ester.6. The water-based wellbore drilling fluid system of claim 1 , wherein the plant-based free fatty acid is derived from a tall oil.7. The water-based wellbore drilling fluid system of claim 1 , wherein the synthesized lubricant is a homogenous mixture.8. The water-based wellbore drilling fluid system of claim 1 , wherein the drilling fluid system has a before hot rolled (BHR) coefficient of friction of from about 0.01 to about 0.10 when measured according to API Recommended Practice 13B.9. The water-based wellbore drilling fluid system of claim 1 , wherein the drilling fluid system has an after hot rolled (AHR) coefficient of friction of from about 0.01 to about 0.09 when measured according to API Recommended Practice 13B.10. The water-based wellbore drilling fluid system of claim 1 , wherein the system comprises from about 0.5 weight percent (wt. %) to about ...

ENVIRONMENTALLY-FRIENDLY LUBRICANT FOR OIL FIELD DRILLING FLUID APPLICATIONS

The present application discloses water-based drilling fluid system compositions and methods for making water-based drilling fluids systems. According to one embodiment, a drilling fluid system may include a drilling fluid and a lubricant. The lubricant may be synthesized from plant-based raw material oil. 1. A method of producing a synthesized lubricant for water-based drilling fluid systems comprising:contacting a plant-based raw material oil with a base to produce a mixture comprising free fatty acids and glycerol;treating the mixture with a brine to isolate the glycerol; andremoving the glycerol to produce a synthesized lubricant comprising free fatty acids.2. The method of claim 1 , wherein the base comprises sodium hydroxide.3. The method of claim 1 , wherein the plant-based raw material oil is contacted with the base at a temperature from about 50° C. to about 75° C.4. The method of claim 3 , further comprising heating the plant-based raw material oil and the base for a period of from about 4 hours to about 8 hours.5. The method of claim 1 , wherein the plant-based raw material oil comprises a vegetable oil.6. The method of claim 1 , wherein the plant-based raw material oil is a waste vegetable oil.7. A method of producing a water-based drilling fluid system comprising:treating a plant-based raw material oil with a base to produce a synthesized lubricant comprising free fatty acids; andcombining the synthesized lubricant with a base drilling fluid to produce a water-based drilling fluid system; andwherein the water-based drilling fluid system is homogeneous.8. The method of claim 7 , wherein the base comprises sodium hydroxide.9. The method of claim 7 , wherein treating the plant-based raw material oil further comprises heating the plant-based raw material oil and the base at a temperature from about 50° C. to about 75° C.10. The method of claim 7 , wherein the plant-based raw material oil is treated for a period of from about 4 hours to about 8 hours.11. The ...

Methods of treatment of a subterranean formation with polymeric structures formed in situ

Methods of treating a subterranean formation are disclosed that include placing a treatment fluid into a subterranean formation, the treatment fluid containing a one or more polymers capable of consolidating to form a polymeric structure at a downhole location. Also disclosed are treatment fluids including a polymeric structure for treating a subterranean formation.

Controlling metal sulfide scale in drilling operations

Described herein are methods for controlling or limiting the deposition of inorganic sulfide scale in wellbore operations. In some cases, method can include introducing a treatment fluid including a cationic polymeric quaternary amine or a polyethyleneimine polymer into a treatment area of a wellbore having metal cations, such as iron, zinc, and/or lead cations, and sulfide anions and contacting the metal cations and sulfide anions with the treatment fluid to reduce or prevent formation of metal sulfide particles in the treatment area. The polymers can include poly(methacrylamido-4,4,8,8-tetramethyl-4,8-diaza-6-hydroxylnonamethylene dichloride), poly(vinylbenzyl trimethyl ammonium chloride), polydimethyldiallyl ammonium chloride, or quaternized ammonium salt polyethyleneimine.

THERMOSET NANOCOMPOSITE PARTICLES, PROCESSING FOR THEIR PRODUCTION, AND THEIR USE IN OIL AND NATURAL GAS DRILLING APPLICATIONS

Use of two different methods, either each by itself or in combination, to enhance the stiffness, strength, maximum possible use temperature, and environmental resistance of thermoset polymer particles is disclosed. One method is the application of post-polymerization process steps (and especially heat treatment) to advance the curing reaction and to thus obtain a more densely crosslinked polymer network. The other method is the incorporation of nanofillers, resulting in a heterogeneous “nanocomposite” morphology. Nanofiller incorporation and post-polymerization heat treatment can also be combined to obtain the benefits of both methods simultaneously. The present invention relates to the development of thermoset nanocomposite particles. Optional further improvement of the heat resistance and environmental resistance of said particles via post-polymerization heat treatment; processes for the manufacture of said particles; and use of said particles in the construction, drilling, completion and/or fracture stimulation of oil and natural gas wells are described. 189.-. (canceled)90. A method for lightening a load of cement comprising: a polymer matrix; and', 'from 0.001 to 60 volume percent of nanofiller particles possessing a length that is less than 0.5 microns in at least one principal axis direction; said nanofiller particles comprising at least one of fine particulate material, fibrous material, discoidal material, or a combination of such materials, said nanofiller particles being selected from the group consisting of natural nanoclays, synthetic nanoclays or mixtures thereof wherein said nanofiller particles are substantially dispersed throughout said polymeric nanocomposite particles, wherein said polymeric nanocomposite particle has a diameter ranging from 0.1 mm to 4 mm; and, '(a) mixing an uncured cement composition with an effective amount of a polymeric nanocomposite bead comprising(b) placing the mixture in a selected location.91. The method of claim 90 , ...

Clay Stabilization Composition

A clay swelling inhibitor additive for oil and gas well treatment is disclosed. The additive comprises an aqueous solution of a water-soluble polymer and ammonium acetate. The additive composition synergistically retards water absorption by the down-hole clay formation. 1. A composition for clay stabilization consisting essentially of ammonium acetate , poly(diallyl dimethylammonium chloride) and water.2. The composition of wherein the ammonium acetate is in solution form prepared by dissolving an ammonium acetate powder in water or by reacting aqueous ammonia with acetic acid.3. The composition of wherein the ammonium acetate comprises from about 30 percent to about 70 percent by weight of the aqueous composition.4. The composition of wherein the ammonium acetate comprises from about 45 percent to about 55 percent by weight of the aqueous composition.5. The composition of wherein the ammonium acetate comprises from about 47 percent to about 50 percent by weight of the aqueous composition.6. The composition of wherein the poly(diallyl dimethylammonium chloride) or poly-DADMAC has a very low claim 1 , low claim 1 , medium or high molecular weight.7. The composition of wherein the poly(diallyl dimethylammonium chloride) has a medium molecular weight.8. The composition of wherein the poly-DADMAC has a molecular weight of <500 claim 6 ,000 daltons.9. The composition of wherein the poly-DADMAC has a molecular weight of <100 claim 8 ,000 daltons or the poly-DADMAC has a molecular weight of 100 claim 8 ,000-200 claim 8 ,000 daltons or the poly-DADMAC has a molecular weight of 200 claim 8 ,000-350 claim 8 ,000 daltons or the poly-DADMAC has a molecular weight of 400 claim 8 ,000-500 claim 8 ,000 daltons.10. The composition of wherein the poly-DADMAC has a molecular weight of 100 claim 9 ,000-350 claim 9 ,000 daltons.11. The composition of wherein the poly-DADMAC has a molecular weight of 200 claim 10 ,000-350 claim 10 ,000 daltons.12. The composition of wherein the poly- ...

DRILLING FLUIDS COMPRISING DEEP EUTECTIC SOLVENTS AND METHODS FOR DRILLING WELLS IN SUBTERRANEAN FORMATIONS

According to one or more embodiments of the present disclosure, a drilling fluid may comprise one or more deep eutectic solvents in an amount greater than or equal to 70 wt. % based on the total weight of the drilling fluid. Each deep eutectic solvent may comprise at least one hydrogen bond acceptor compound and at least one hydrogen bond donor compound. A molar ratio of the total moles of the hydrogen bond donor compounds to the total moles of the hydrogen bond acceptor compounds in each deep eutectic solvent may be from 0.1 to 1.0. The drilling fluid may have a density greater than or equal to 200 kg/m. The drilling fluid may have a viscosity greater than or equal to 0.5 Pa·s when measured at 25° C. Methods for drilling wells in subterranean formations using the drilling fluid are also disclosed. 1. A drilling fluid comprising:one or more deep eutectic solvents in an amount greater than or equal to 70 weight percent based on the total weight of the drilling fluid, each deep eutectic solvent comprising at least one hydrogen bond acceptor compound and at least one hydrogen bond donor compound,wherein a molar ratio of the total moles of the hydrogen bond donor compounds to the total moles of the hydrogen bond acceptor compounds in each deep eutectic solvent is from 0.1 to 1.0;the drilling fluid has a density greater than or equal to 200 kilograms per cubic meter; andthe drilling fluid has a viscosity greater than or equal to 0.5 pascal-seconds when measured at 25 degrees Celsius.2. The drilling fluid of claim 1 , wherein the at least one hydrogen bond acceptor compound comprises one or more of a quaternary ammonium salt claim 1 , a phosphonium salt claim 1 , a sulfonium salt claim 1 , a pyridinium salt claim 1 , or a metallic salt.3. The drilling fluid of claim 1 , wherein the at least one hydrogen bond acceptor compound has the chemical structure: RRRRNX claim 1 , wherein R claim 1 , R claim 1 , R claim 1 , and Rare each independently one or more of a hydrogen claim ...

Ecofriendly emulsifier synthesis from esterified waste vegetable oil for wellbore drilling fluids

Ecofriendly emulsifier synthesis from esterified waste vegetable oil for wellbore drilling fluids is described. A raw material waste vegetable oil is esterified to produce a methyl ester of the raw material waste vegetable oil. A caustic soda solution is added to the methyl ester resulting in a mixture. The mixture is thermally treated. A pH of the mixture is adjusted resulting in formation of an aqueous phase and a non-aqueous phase. The aqueous phase is separated from the non-aqueous phase.

LUBRICANTS THAT INCLUDE ALKYL ESTERS AND FATTY ACIDS

One or more embodiments presently described are directed to lubricants and methods for making such lubricants. According to one embodiment, a lubricant suitable for use in a water-based drilling fluid may comprise one or more alkyl esters and a fatty acid blend comprising one or more medium-chain fatty acids. The one or more medium-chain fatty acids may be at least 50 weight percent (wt. %) of the fatty acid blend. The weight ratio of the one or more alkyl esters to the fatty acid blend may be from 1:1 to 3:1. 1. A lubricant suitable for use in a water-based drilling fluid , the lubricant comprising:one or more alkyl esters; anda fatty acid blend comprising one or more medium-chain fatty acids, where the one or more medium-chain fatty acids are at least 50 wt. % of the fatty acid blend,where the weight ratio of the one or more alkyl esters to the fatty acid blend is from 1:1 to 3:1.2. The lubricant of claim 1 , where the one or more medium-chain fatty acids comprise at least caproic acid and caprylic acid.3. The lubricant of claim 2 , where the molar ratio of caproic acid to caprylic acid is from 10:90 to 90:10.4. The lubricant of claim 1 , where each of the one or more medium-chain fatty acids have a melting point of less than or equal to 50° C.5. The lubricant of claim 1 , where the one or more alkyl esters are derived from vegetable oil.6. The lubricant of claim 1 , where the one or more alkyl esters are from 50 wt. % to 75 wt. % of the lubricant.7. The lubricant of claim 1 , where the fatty acid blend is from 25 wt. % to 50 wt. % of the lubricant.8. The lubricant of claim 1 , where the fatty acid of the lubricant is a liquid.9. A method for making a drilling fluid lubricant claim 1 , the method comprising:mixing one or more medium-chain fatty acids to make a liquid fatty acid blend;mixing the liquid fatty acid blend with one or more alkyl esters to from a lubricant precursor; andheating the lubricant precursor to a temperature of at least 50° C. and mechanically ...

SPACER FLUIDS AND CEMENT SLURRIES THAT INCLUDE SURFACTANTS

According to at least one embodiment of the present disclosure, a well bore cementing system may comprise a spacer fluid and a cement slurry. The spacer fluid may be positioned within a well bore, and the spacer fluid may comprise a first surfactant package comprising one or more surfactants. The cement slurry may be positioned within the well bore, and the cement slurry may comprise a second surfactant package comprising one or more surfactants. 1. A well bore cementing system comprising: a base fluid that is an aqueous-based fluid; and', {'sub': 2', '4', 'x1, 'a first surfactant package consisting essentially of one or more surfactants having the chemical structure R1-(OCH)—OH, where R1 is a hydrocarbyl group having from 5 to 20 carbon atoms, and x1 is an integer from 5 to 15, where the one or more surfactants of the first surfactant package has a HLB of from 11 to 13.5; and'}], 'a spacer fluid positioned within a well bore, the spacer fluid comprising{'sub': 2', '4', 'x2, 'a cement slurry positioned within the well bore, the cement slurry comprising a second surfactant package consisting essentially of one or more surfactants having the chemical structure R2-(OCH)—OH, where R2 is a hydrocarbyl group having from 5 to 20 carbon atom, and x2 is an integer from 5 to 15, where the one or more surfactants of the second surfactant package has a HLB of from 11 to 13.5.'}2. The well bore cementing system of claim 1 , where the cement slurry is in contact with the spacer fluid.3. The well bore cementing system of claim 1 , where the spacer fluid is in contact with a drilling fluid and the cement slurry.4. The well bore cementing system of claim 1 , where the one or more surfactants of the first surfactant package has a HLB of from 12.5 to 13 claim 1 , the one or more surfactants of the second surfactant package has a HLB of from 12.5 to 13 claim 1 , or both.5. The well bore cementing system of claim 1 , where x1 is an integer from 5 to 10 claim 1 , x2 is an integer from 5 ...

Substituted cellulose acetates and uses thereof

The present invention relates to substituted cellulose acetates and methods of use thereof. One embodiment of the present invention provides a coating having a substituted cellulose acetate having a polar substituent that has an oxygen atom covalently bonded to a nonmetal selected from the group of sulfur, phosphorus, and boron; wherein the nonmetal is present in at least about 0.01% by weight of the substituted cellulose acetate.

Compositions for treating subterranean formations

A method comprises obtaining or providing a treatment fluid comprising compounds comprising a structure of the formula (I) or (Ia) or compounds of the formula (Ib) and placing the treatment fluid in a subterranean formation.

POLYMERIC SURFACTANT CONTAINING A PROTEIN HEAD GROUP AND LIPID TAIL GROUP

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

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

Methods and compositions (e.g., 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 embodiments, an emulsion or the microemulsion comprises water, a solvent, and a surfactant, and optionally, one or more additives, such as a co-surfactant or a linker. In some embodiments, a concentrate is provided which may be used to form an emulsion or microemulsion. 1. A method of treating a well having a wellbore , comprising:injecting a thermodynamically unstable emulsion into the wellbore, wherein the emulsion comprises: a first type of surfactant;', 'a second type of surfactant, wherein the second type of surfactant is selected from the group consisting of polyamines, polyimines, polyesters, and resins;', 'a first type of solvent comprising a terpene; and, 'a concentrate comprisinga dilution fluid comprising a second type of solvent and an acid.2. The method of claim 1 , wherein the first type of surfactant is selected from the group consisting of a nonionic surfactant claim 1 , a cationic surfactant claim 1 , an anionic surfactant claim 1 , an amphoteric surfactant claim 1 , a zwitterionic surfactant claim 1 , a Gemini surfactant claim 1 , an extended surfactant claim 1 , and combinations thereof.3. The method of claim 1 , wherein the first type of surfactant is a cationic surfactant.4. The method of claim 3 , wherein the cationic surfactant is selected from the group consisting of bis(hydroxyethyl) cocobenzylammonium chloride and cocoalkylmethyl PEG (polyethylene glycol)-15 ammonium chloride.5. The method of claim 1 , wherein the first type of surfactant is an anionic surfactant.6. The method of claim 5 , wherein the anionic surfactant is selected from the group consisting of sodium lauryl glucose carboxylate claim 5 , sodium dodecyl diphenyloxide disulfonate claim 5 , and sodium tridecyl ether with 0-20 ethylene oxide (EO) units and/or 0-20 propylene oxide (PO) units.7. The method of claim ...

POLYMER SYSTEM FOR FLUID LOSS CONTROL

A combination of three polymers including a crosslinked acrylamide-TBAS copolymers in inverse emulsion form, N-vinyl pyrrolidone-acrylamide-TBAS terpolymer, and crosslinked N-vinyl pyrrolidone-acrylamide-TBAS acts as high temperature, high pressure fluid loss control additives for water-based drilling fluids systems. The combination is particularly useful for high salt, high density drilling fluids, and high temperature applications. 1. A composition for fluid loss control comprising an acrylamide monomer at 30-80%;', 'a 2-acrylamide-2-methylpropanesulfonic acid monomer at 10-50%; and', 'a NVP monomer at 5-30%;, 'a first polymer comprising an acrylamide-NVP-2-acrylamide-2-methylpropanesulfonic acid terpolymer comprising'} an acrylamide monomer at 30-80%;', 'a 2-acrylamide-2-methylpropanesulfonic acid monomer at 10-50%;', 'an NVP monomer at 5-20%; and', 'a crosslinking monomer at 0.05%-0.5%; and, 'a second polymer comprising a crosslinked acrylamide-NVP-2-acrylamide-2-methylpropanesulfonic acid terpolymer comprising'} an acrylamide monomer at 30-80%;', 'a 2-acrylamide-2-methylpropanesulfonic acid monomer at 20-70%; and', 'a crosslinking monomer at 0.1-1%., 'a third polymer comprising a crosslinked acrylamide-2-acrylamide-2-methylpropanesulfonic acid copolymer in inverse emulsion comprising'}2. The composition of wherein the first polymer comprises an acrylamide-NVP-2-acrylamide-2-methylpropanesulfonic acid terpolymer comprisingan acrylamide monomer at 40-60%;a 2-acrylamide-2-methylpropanesulfonic acid monomer at 25-40%; anda NVP monomer at 10-20%.3. The composition of wherein the second polymer comprises a crosslinked acrylamide-NVP-2-acrylamide-2-methylpropanesulfonic acid terpolymer comprisingan acrylamide monomer at 40-60%;a 2-acrylamide-2-methylpropanesulfonic acid monomer at 25-40%;an NVP monomer at 10-20%; anda crosslinking monomer at 0.1-0.3%.4. The composition of wherein the third polymer comprises a crosslinked acrylamide-2-acrylamide-2-methylpropanesulfonic ...

Methods of treating oil and gas well fractures

Embodiments of the present disclosure provide for loss circulation materials, methods of making loss circulation materials, methods treating oil and gas well fractures using loss circulation materials, and the like.

Fluorescent Dye Loaded Polymeric Taggants for Depth Determination in Drilling Wells

A method of surface logging a well includes adding each of multiple polymeric taggants to a circulating drilling fluid in an addition sequence while drilling the well. Each polymeric taggant includes a polymer and a respective fluorescent dye having an emission wavelength or excitation wavelength different from that of each other fluorescent dye. The method includes taking a sample of drill cuttings carried by a drilling fluid while drilling a well, wherein the sample of drill cuttings includes polymeric taggants attached to the drill cuttings. The method includes extracting the dyes from the sample of drill cuttings into an extract solution; determining an indication of the type of and the concentration of each of the dyes in the extract solution; and determining a depth associated with the sample of drill cuttings based on the indication of the concentration of each of the dyes and on the addition sequence. 1. A method of surface logging a well , the method comprising:adding each of multiple polymeric taggants to a circulating drilling fluid in an addition sequence while drilling the well, wherein each polymeric taggant comprises a polymer and a respective fluorescent dye, wherein each fluorescent dye has an emission wavelength different from the emission wavelength of each other fluorescent dye, an excitation wavelength different from the excitation wavelength of each other fluorescent dye, or both;taking a sample of drill cuttings carried by a drilling fluid while drilling a well in the presence of the drilling fluid, wherein the sample of drill cuttings includes polymeric taggants attached to the drill cuttings;extracting the dyes from the sample of drill cuttings into an extract solution;determining an indication of the type of and the concentration of each of the dyes in the extract solution; anddetermining a depth associated with the sample of drill cuttings based on the indication of the concentration of each of the dyes and on the addition sequence.2. The ...

Viscoelastic Fluid Compositions, Oil Flowable/Oil Dispersion Compositions, and Drilling Fluid Compositions

Viscoelastic fluid compositions are provided that have improved properties for suspending particulate active ingredients. Methods for forming the compositions are also provided. The compositions preferably have a non-Newtonian behavior, so that the viscosity of the composition at low shear rates is suitable for keeping solid particles in the form of a stable suspension while also providing a reduced viscosity at higher shear rates (such as a substantially reduced or minimized viscosity) to allow for pumping, tank mixing, and/or distribution of the composition, for instance by spraying. 1. A viscoelastic fluid composition , comprising:(a) a hydrocarbon fluid having a total paraffinic hydrocarbon content of at least about 80 wt % relative to the weight of the hydrocarbon fluid and an aromatic content of less than about 20 wt % relative to the weight of the hydrocarbon fluid, the hydrocarbon fluid having an initial boiling point of about 95° C. to about 280° C. and a final boiling point of about 100° C. to about 315° C.; and(b) about 1.0 wt % to about 10.0 wt %, relative to the weight of the hydrocarbon fluid, of a thickening agent comprising a block copolymer having a peak molecular weight of about 10,000 g/mol to about 500,000 g/mol, wherein at least one end block of the block copolymer comprises an aromatic polymer and wherein the weight of said at least one end block is about 20 wt % to about 50 wt % of the block copolymer.2. The composition of claim 1 , wherein the hydrocarbon fluid comprises at least about 50 wt % n-paraffins claim 1 , or wherein the hydrocarbon fluid comprises at least about 50 wt % cylcoparaffins.3. A viscoelastic fluid composition claim 1 , comprising:(c) a hydrocarbon fluid having a total paraffinic hydrocarbon content of at least about 80 wt % relative to the weight of the hydrocarbon fluid, an isoparaffin content of less than about 50 wt % relative to the weight of the hydrocarbon fluid, a n-paraffin content of less than about 50 wt % ...

WELLBORE SERVICING COMPOSITIONS AND METHODS OF MAKING AND USING SAME

A method of servicing a wellbore in a subterranean formation having one or more lost circulation zones comprising placing a wellbore servicing fluid comprising a sealing composition into the wellbore, wherein the sealing composition comprises a latex and an accelerator and wherein the latex, the accelerator or both are encapsulated with an encapsulation material. A wellbore servicing fluid comprising a latex and an accelerator wherein the latex, the accelerator, or both are encapsulated. 1. A method of servicing a wellbore in a subterranean formation having one or more lost circulation zones comprising:placing a wellbore servicing fluid in a wellbore, the wellbore servicing fluid comprising a latex and an accelerator;wherein the latex is selected from the group consisting of a solid latex or a latex emulsion;wherein the latex is encapsulated with a first encapsulation material;wherein the first encapsulation material deteriorates; andwherein in the absence of the first encapsulation material, the latex and the accelerator react to form a sealing composition.2. The method of claim 1 , wherein the sealing composition forms a mass on the surface of a subterranean formation or a mass within a lost circulation zone claim 1 , the mass being operable to reduce or eliminate the loss of material to a lost circulation zone.3. The method of claim 1 , wherein the first encapsulation material comprises at least two coatings claim 1 , each coating being selected from the group consisting of a first coating claim 1 , a second coating claim 1 , and an external coating.4. The method of claim 1 , wherein the latex is coated with a material that reacts with water to form the first encapsulation material.5. The method of claim 1 , wherein the accelerator is encapsulated with the first encapsulation material or a second encapsulation material.6. The method of claim 5 , wherein the first encapsulation material or the second encapsulation material comprise at least two coatings claim 5 , ...

COMPOSITIONS AND METHODS TO RECOVER IRREDUCIBLE WATER FOR ENHANCEDFORMATION EVALUATION

Provided here are compositions and improved methods for recovering portion of irreducible water saturation in a porous rock sample. Compositions used here contain a displacement fluid and a surfactant, and lead to an increased recovery of the irreducible water from the porous rock sample. 1. A method of recovering portion of irreducible water saturation in a porous rock sample , comprising the steps of:providing a composition containing a displacement fluid and a surfactant to a porous rock sample with an irreducible water saturation to produce a treated rock sample; andsubjecting the treated rock sample to centrifugation to extract a portion of irreducible water.2. The method of claim 1 , wherein the porous rock sample is a rock representative of a hydrocarbon reservoir.3. The method of claim 1 , wherein the centrifugation is under conditions to preserve physical integrity of the porous rock sample.4. The method of claim 1 , wherein the displacement fluid is less dense than water.5. The method of claim 1 , wherein the displacement fluid is diesel.6. The method of claim 1 , wherein the displacement fluid is toluene.7. The method of claim 1 , wherein the displacement fluid is dodecane.8. The method of claim 1 , wherein the surfactant is an organic surfactant.9. The method of claim 1 , wherein the composition contains diesel and an organic surfactant.10. The method of claim 9 , wherein the organic surfactant is at least 0.01 wt % of the composition containing diesel and the organic surfactant.11. A method of enhanced recovery of irreducible water from a porous rock sample claim 9 , comprising the steps of:mixing a displacement fluid and a surfactant to produce a composition;allowing the composition to interact with a porous rock sample with an irreducible water saturation to produce a treated rock sample; andsubjecting the treated rock sample to centrifugation under conditions that preserve physical integrity of the porous rock sample to obtain an amount of ...

Method for controlled release of antimicrobial compounds

wherein X is O or NH; R is an acrylic polymer, a saturated polyester, an alkyd resin, a polyether or a polycarbonate and R optionally has additional XC(O)NHCHR′R″ substituents; R′ is hydroxyl or NHC(O)XR; and R″ is an organic substituent group having from one to twenty carbon atoms and which optionally has additional CHR′NHC(O)XR substituents.

DEVELOPMENT OF ANTI-BIT BALLING FLUIDS

Anti-bit balling drilling fluids and methods of making and using drilling fluids are provided. The anti-bit balling drilling fluid contains water, a clay-based component, and at least one of a surfactant having the formula: R—(OCH)—OH, where R is a hydrocarbyl group having from 10 to 20 carbon atoms and x is an integer from 1 and 10, or a polyethylene glycol having the formula: H—(O—CH—CH)—OH, where n is an integer from 1 to 50. Methods of making and using these drilling fluids are also provided. 2. The method of claim 1 , where the surfactant has an HLB of from 8 to 16.3. The method of claim 1 , where R is:an alkyl group comprising 12 to 15 carbons; oran alkenyl group comprising from 12 to 15 carbon atoms.4. The method of claim 1 , where x is from 5 to 10.5. The method of claim 1 , where the surfactant has an HLB of from 13 to 15.6. The method of claim 1 , where the surfactant comprises ethylene oxide condensate of branched isotridecyl alcohol.7. The method of claim 1 , where the polyethylene glycol has a weight average molecular weight of from 300 grams per mol (g/mol) to 500 g/mol claim 1 , as measured according to GPC.8. The method of claim 1 , where the drilling fluid comprises from 28 to 850 lb/bbl water based on total weight of the drilling fluid.9. The method of claim 1 , where the drilling fluid comprises from 28 to 720 lb/bbl of the clay-based component based on total weight of the drilling fluid.10. The method of claim 1 , where the drilling fluid comprises from 0.02 to 180 lb/bbl of the surfactant claim 1 , the polyethylene glycol claim 1 , or both claim 1 , based on total weight of the drilling fluid.11. The method of claim 1 , where the clay-based component comprises one or more components selected from the group consisting of lime (CaO) claim 1 , CaCO claim 1 , bentonite claim 1 , montmorillonite clay claim 1 , barium sulfate (barite) claim 1 , hematite (FeO) claim 1 , mullite (3AlO.2SiOor 2AlO.SiO) claim 1 , kaolin claim 1 , (AlSiO(OH)or kaolinite) ...

Hydrocarbon Wells Including Crosslinked Polymer Granules as Lost Circulation Material and Methods of Drilling the Hydrocarbon Wells

Hydrocarbon wells including crosslinked polymer granules as lost circulation material and methods of drilling the hydrocarbon wells. The hydrocarbon wells include a wellbore that extends within a subsurface region, a drilling rig, a drilling mud supply system, a lost circulation detection structure, and a lost circulation material supply system that includes a lost circulation material. The lost circulation material includes a plurality of crosslinked polymer granules, and a characteristic dimension of each crosslinked polymer granule is at least 20 micrometers and at most 1 millimeter. Each crosslinked polymer granule contains a highly crosslinked polymeric material that includes a plurality of polyethylene polymer chains. The methods include rotating a drill string to extend a length of a wellbore and, during the rotating, flowing a drilling mud stream. The methods also include detecting a lost circulation event and, responsive to the detecting, providing a lost circulation material to the wellbore. 1. A hydrocarbon well , comprising:a wellbore that extends within a subsurface region;a drilling rig including a drill string, wherein the drill string includes a drill bit, and further wherein the drill bit is positioned within a downhole end region of the wellbore;a drilling mud supply system configured to provide a drilling mud stream to the downhole end region of the wellbore at a drilling mud stream pressure and a drilling mud stream flow rate;a lost circulation detection structure configured to detect a lost circulation event within the wellbore; anda lost circulation material supply system that includes a lost circulation material, wherein the lost circulation material supply system is configured to selectively provide the lost circulation material to the wellbore responsive to detection of the lost circulation event by the lost circulation detection structure, wherein the lost circulation material includes a plurality of crosslinked polymer granules, wherein a ...

Gas generating compositions

The present application provides a gas-generating aqueous fluid containing a gas-generating compound like an azo compound, and an organic amine like a primary, secondary or tertiary amine, a hydrazine, a hydrazide, or a semicarbazide. The aqueous fluid may also a viscosifler, and a foaming surfactant. The present application also provides a method of using the gas-generating composition to modulate density of a wellbore fluid for use in downhole applications. The method optionally includes adding an oxidizer to the wellbore fluid.

PROCESS FOR MAKING PELLET PRODUCT FOR USE IN SOIL NEUTRALIZATION AND OTHER APPLICATIONS

Recycled carpet mineral filler material is processed to form pellets that can be used in a variety of applications, such as an agricultural lime product, an asphalt paving additive, a loss control material, or cat litter. Used carpet undergoes a shredding process separating valuable resin fibers from the mineral filler and the residual glue. The mineral filler/residual glue undergoes a screening process and then a pelletizing process to produce an agricultural lime product. A liquid or dry adhesive binder can be added to facilitate compaction of the mineral filler in such a manner as to form a pellet, which reduces dust and increases the ease of handling. 1. A cat litter pellet made by a process comprising:(a) providing a used carpet material comprising reusable carpet fibers and an adhesive material comprising an adhesive and a mineral filler;(b) shredding the used carpet material and separating the reusable carpet fibers from the adhesive material;(c) compressing the adhesive material into a dense piece; and(d) forming the dense piece into a pellet adapted for use as cat litter.2. The cat litter pellet according to claim 1 , wherein the cat litter pellet has a size of +1 millimeter to −6 millimeter mesh.3. The cat litter pellet according to claim 1 , wherein the step of forming the dense piece into a pellet adapted for use as cat litter comprises:(a) granulating the dense piece into smaller pieces; and(b) screening the smaller pieces to produce a pellet having a size of +1 millimeter to −6 millimeter mesh.4. The cat litter pellet according to claim 1 , wherein the mineral filler comprises at least one selected from the group consisting of calcium carbonate and magnesium carbonate.5. The cat litter pellet according to claim 1 , wherein the step of compressing the adhesive material into a dense piece comprises mixing the adhesive material with a binding agent adapted for facilitating compression of the adhesive material.6. The cat litter pellet according to claim 5 ...

HIGH TEMPERATURE STABILIZER FOR POLYMER-BASED TREATMENT FLUIDS

A method of treating a subterranean formation, the method includes forming a fluid comprising: a crosslinkable component and a water soluble phenolic compound that has at least a substituted hydroxyl or alkyloxy group at the ortho or meta position, or a phenolic cyclic derivative of the general formula (1). The formed fluid comprising a combination of the crosslinkable component and the phenolic compound or the phenolic cyclic derivatives of formula 1 exhibits a fluid viscosity greater than 100 cP at 100/s and 93° C. or greater for at least 30 minutes. 2. The method of claim 1 , wherein the crosslinkable component is selected from the group consisting of guar claim 1 , guar derivatives claim 1 , polyacrylamide claim 1 , partially hydrolyzed polyacrylamide (PHPA) claim 1 , copolymers of acrylamide and acrylic acid claim 1 , neutralized copolymers of acrylamide and acrylic acid claim 1 , copolymers of acrylamide and sodium acrylate claim 1 , partially hydrolyzed polyacrylamide claim 1 , copolymers of acrylamide and AMPS claim 1 , cationic polyacrylamides claim 1 , vinylpyrrolidone claim 1 , or a combination thereof.3. The method of claim 1 , wherein the crosslinkable component is crosslinked.4. The method of claim 1 , wherein the water solubility of the phenolic compound or phenolic derivative is greater than 10 mg/L.5. The method of claim 1 , wherein the fluid further comprises a borate ion.6. The method of claim 1 , wherein the fluid further comprises a metal crosslinker.7. The method of claim 6 , wherein the metal crosslinker comprises zirconium claim 6 , aluminum claim 6 , titanium claim 6 , and/or other Group IV metals.8. The method of claim 1 , wherein the water soluble phenolic compound is selected from the group consisting of methoxyphenol claim 1 , ethoxyphenol claim 1 , propoxyphenol claim 1 , butoxyphenol claim 1 , dimethoxyphenol claim 1 , trimethoxyphenol claim 1 , dihydroxy-methoxybenzene claim 1 , dihydroxy-dimethoxybenzene claim 1 , trihydroxyphenol ...

Methods And Compositions For Suspending Components In Oils Without Suspending Agents

Methods and compositions for a suspending-agent free suspension may include one or more solids having at least 30 wt % of the suspending-agent free suspension being suspended in one or more oils. The one or more solids may be, for example, proppants, oxidizers, reducers, gums, starches, minerals, resins, and/or polymers, and the foregoing one or more solids may exist in various forms, including, for example, gelatinous, encapsulated, powder, crystalline, fine, course, natural, flake, or combinations el thereof. The one or more oils may be natural, synthetic, or combinations of both natural and synthetic oils. The one or more oils may or be free from benzene, toluene, ethylbenzene, and xylene, i.e., BTEX-free. The one or more oils may also include one or more viscosified oils through the addition of comprise one or more polymers. The suspending-agent free suspension may include one or more surfactants. 1. A suspending-agent free suspension comprising:one or more solids comprising at least 30 wt. % of the suspending-agent free suspension, wherein the one or more solids are suspended in one or more oils viscosified with one or more polymers comprising 10 wt. % or less of the suspending-agent free suspension,wherein the suspending-agent free suspension has a dispersion stability within a range of months to years.2. (canceled)3. The suspending-agent free suspension of claim 1 , further comprising a temperature stability within a range of from 0° C. to 55° C.4. The suspending-agent free suspension of claim 1 , further comprising one or more surfactants.5. The suspending-agent free suspension of claim 1 , wherein the one or more polymers is selected from a group comprising ethylene-propylene-diene monomer (EPDM) terpolymers; copolymers of isoprene and styrene sulfonate salt; copolymers of chloroprene and styrene sulfonate salt; copolymers of isoprene and butadiene; copolymers of styrene and styrene sulfonate salt; copolymers of butadiene and styrene sulfonate salt; ...

COMPOSITIONS AND METHODS FOR SERVICING SUBTERRANEAN WELLS

Well treatment compositions comprise water, a polysaccharide and cellulose fibers. The cellulose fibers may have lengths between 100 nm and 10 mm, and diameters between 4 nm and 40 μm. The compositions may be used as spacer fluids during well cementing operations. The spacer fluids may prevent commingling of a cement slurry with a drilling fluid. The drilling fluid may be water-base, oil-base, synthetic-base or an emulsion. 1. A method for treating a subterranean well , comprising:(i) preparing a composition that comprises water, a water soluble polymer and cellulose fibers; and(ii) placing the composition in the well.2. The method of claim 1 , wherein the composition displaces and removes a drilling fluid from the subterranean well.3. The method of claim 1 , wherein the water soluble polymer comprises a polysaccharide or a synthetic polyelectrolyte or both.4. The method of claim 3 , wherein the polysaccharide comprises carboxymethyl cellulose claim 3 , the carboxymethyl cellulose having a molecular weight between 100 kDa and 2000 kDa claim 3 , and being present at a concentration between 0.001 wt % and 1 wt %.5. The method of claim 1 , wherein the cellulose fibers have lengths between 100 and 10 mm claim 1 , and diameters between 4 nm and 40 μm.6. The method of claim 1 , wherein the composition further comprises a halide salt.7. The method of claim 1 , wherein the composition further comprises a portland cement claim 1 , a weighting agent claim 1 , a surfactant claim 1 , a clay claim 1 , a solvent or an antifoam agent or a combination thereof.8. A method for cementing a subterranean well claim 1 , comprising:(i) preparing a composition that comprises water, a water soluble polymer and cellulose fibers;(ii) placing the composition in the well; and(iii) placing a cement slurry in the well,wherein the composition separates the cement slurry and a drilling fluid.9. The method of claim 8 , wherein the drilling fluid is water-base claim 8 , oil-base claim 8 , synthetic- ...

Acoustic Imaging with Expandable Microcapsules

The present disclosure relates generally to expandable microcapsules and their utilization for acoustic imaging within a geological formation. The present disclosure further relates to expandable microcapsules with a multicomponent core and disclosure to practical utilization of multicomponent cores for controlling the expansion properties (e.g., temperature and pressure of expansion, expansion volume ratio, and shell thickness) of the resulting microbubbles. 1. A method of acoustically imaging geological reservoirs comprising:injecting expandable microcapsules into a geological reservoir;propagating sound waves through the geological reservoir;receiving sound waves reflected off the expandable microcapsules; andcreating an image of the sound waves reflected off the expandable microcapsules.2. The method of acoustically imaging geological reservoirs according to claim 1 , wherein the expandable microcapsules comprise a polymeric shell encapsulating two or more components with at least one component being a blowing agent.3. The method of acoustically imaging geological reservoirs according to claim 1 , wherein the geological reservoir is an oil and/or gas wellbore connected to an oil and/or gas-bearing formation.4. The method of acoustically imaging geological reservoirs according to claim 3 , further comprising dispersing the expandable microcapsules in a fluid.5. The method of acoustically imaging geological reservoirs according to claim 4 , further comprising pressurizing the fluid to create fractures in the oil and/or gas-bearing formation.6. The method of acoustically imaging geological reservoirs according to claim 5 , further comprising dispersing the fluid in the fractures created in the oil and/or gas-bearing formation.7. An expandable microcapsule comprising:a polymeric shell; anda multicomponent expandable core comprising at least one blowing agent, wherein the expandable microcapsule expands at an expansion temperature.8. The expandable microcapsule of ...

Methods of Using Fluid Loss Additives Comprising Micro Gels

Methods and fluids are provided that include, but are not limited to, a drilling fluid comprising an aqueous base fluid and a fluid loss control additive that comprises at least one polymeric micro gel and a method comprising: providing an aqueous based treatment fluid comprising a fluid loss control additive that comprises at least one polymeric micro gel; placing the aqueous based treatment fluid in a subterranean formation via a well bore penetrating the subterranean formation; allowing the fluid loss control additive to become incorporated into a filter cake located on a surface within the subterranean formation; allowing the filter cake to be degraded; and producing hydrocarbons from the formation. Additional methods are also provided. 127-. (canceled)28. A method comprising: wherein the fluid loss control additive comprises at least one at least partially spherical, non-fibrous polymeric micro gel that comprises a reaction product formed by a polymerization reaction of a polymer or copolymer and a crosslinking agent,', 'wherein the polymer or copolymer comprises at least one unit based on at least one compound selected from the group consisting of polybutylene succinate, polybutylene succinate-co-adipate, polyhydroxybutyrate-valerate, polyhydroxybutyrate-covalerate, polyester amides, polyethylene terephthalates, sulfonated polyethylene terephthalate, aliphatic aromatic copolyester, chitins, chitosans, poly(hydroxy ester ethers), poly(orthoesters), poly(phosphazenes), a copolymer thereof, a homopolymer thereof, a tetrapolymer thereof, and any derivative thereof;, 'providing a treatment fluid comprising an aqueous base fluid and a fluid loss control additive,'}placing the treatment fluid in a subterranean formation via a wellbore penetrating the subterranean formation; andallowing the fluid loss control additive to become incorporated into a filter cake located on a surface within the subterranean formation.29. The method of claim 28 , wherein the fluid loss ...

Cationic nitrogen-containing heterocycles and their application in wellbore stability

In accordance with one or more embodiments of the present disclosure, a method of inhibiting shale formation during water-based drilling of subterranean formations includes introducing a shale inhibitor to the subterranean formation during the water-based drilling, the shale inhibitor comprising a cationic polymer comprising repeating units of [A-B]. A is a substituted benzene or a substituted triazine of formula (2). B is a N-containing heterocycle. The cationic polymer and a method of making the cationic polymer are also described.

Profile control and oil displacement agent for oil reservoir and preparation method thereof

The present disclosure relates to a profile control and oil displacement agent for an oil reservoir and a preparation method thereof. The profile control and oil displacement agent is prepared by uniformly dispersing polymer microspheres, an activator and a solvent. The polymer microspheres are micron-sized dry-powdered microspheres, which are prepared by stirring and polymerizing a first monomer, a second monomer, an initiator, a hydrophobic nano-powder and water in a specific proportion. The profile control and oil displacement agent of the present disclosure can reduce the oil-water interfacial tension, has good long-term stability, simple preparation and low cost, avoids solvent waste, and can be applied to the deep profile control and oil displacement system of oil fields.