СПОСОБ И УСТРОЙСТВО ДЛЯ МНОГОПЛАСТОВОГО ЗАКАНЧИВАНИЯ СКВАЖИНЫ (ВАРИАНТЫ)

Изобретение относится к многопластовому заканчиванию скважины. Обеспечивает повышение надежности устройства и повышение эффективности способа. Сущность изобретения: устройство содержит колонну, имеющую проход, и множество инструментов, установленных в колонне и приспособленных для установки в состояние захвата объектов по существу одинакового размера, перемещаемых вниз по стволу скважины через проход, при этом каждый инструмент, при установке в состояние захвата, способен ограничивать его внутренний диаметр от большего размера до меньшего размера для захвата одного из объектов. По способу используют колонну, имеющую множество инструментов и проход, проходящий через инструменты, и без спуска активизирующего инструмента в проход выборочно активизируют инструменты колонны для перехода каждого активизированного инструмента из первого состояния, в котором инструмент обеспечивает возможность перемещения свободнопадающего объекта через проход, во второе состояние, в котором инструмент обеспечивает ...

ВЫСОКОПРОИЗВОДИТЕЛЬНАЯ МНОГОБЛОЧНАЯ СИСТЕМА ИНТЕНСИФИКАЦИИ ДОБЫЧИ

Группа изобретений относится к скважинной сборке для обработки углеводородсодержащего пласта и, в частности, к его множественному гидроразрыву за одну операцию. Технический результат - повышение надежности работы скважинной сборки. Скважинная сборка имеет по меньшей мере две скользящие муфты, каждая из которых содержит корпус, имеющий наружный диаметр, внутренний диаметр, первое отверстие, обеспечивающее сообщение посредством флюида между внутренним диаметром и наружным диаметром, а также второе отверстие, обеспечивающее сообщение посредством флюида между внутренним диаметром и наружным диаметром, продольно смещенным от первого отверстия. Имеется вставка, расположенная в пределах внутреннего диаметра корпуса и имеющая наружный диаметр вставки, внутренний диаметр вставки, расцепляемое седло, профиль переключения, а также первое положение в корпусе, при котором поток флюида через первое и второе отверстия заблокирован. Имеется толкатель активирования расцепляемого седла для облегчения перемещения ...

СОСТОЯЩЕЕ ИЗ СЕГМЕНТОВ СКЛАДЫВАЮЩЕЕСЯ ГНЕЗДО ШАРА, ОБЕСПЕЧИВАЮЩЕЕ ИЗВЛЕЧЕНИЕ ШАРА

Изобретение относится к выборочно приводимым в действие барьерам для трубной колонны на подземной площадке. Технический результат заключается в предотвращении деформации отверстия гнезда шара, тем самым не допуская зависания шара. Выборочно приводимый в действие барьер для трубной колонны на подземной площадке содержит множество установленных по периметру сегментов, опирающихся на кожух и выполненных с возможностью перемещения из первого положения, где сегменты проходят в трубную колонну, во второе положение, где сегменты втягиваются для увеличения канала, образованного сегментами в кожухе в первом положении. Сегменты разнесены друг от друга снаружи канала во втором положении. Имеются сужающийся элемент, установленный в кожухе смежно с сегментами и имеющий отверстие сужения больше канала, когда сегменты находятся в первом положении; и предмет для спуска на сегмент, блокирующий канал, когда сегмент находится в первом положении, и проходящий через канал, когда сегмент втягивается во второе ...

ЗАХВАТНОЕ УСТРОЙСТВО

Группа изобретений относится к скважинному захватному устройству, способу захвата объекта внутри скважины и скважинному захватному инструменту для захвата объекта. Скважинное захватное устройство содержит множество выполненных с возможностью радиального перемещения посадочных элементов, расположенных по окружности вокруг продольной оси, в котором посадочные элементы выполнены с возможностью перемещения между радиально выдвинутой конфигурацией и радиально отведенной конфигурацией, и освобождаемое фиксирующее приспособление для освобождаемого радиального ограничения посадочных элементов в радиально выдвинутой конфигурации и против радиального перемещения по направлению к радиально отведенной конфигурации. Технический результат заключается в повышении эффективности захватного устройства. 3 н. и 35 з.п. ф-лы, 15 ил.

СКВАЖИННОЕ ПОТОЧНОЕ УСТРОЙСТВО

Настоящее изобретение относится к скважинному поточному устройству для управления потоком текучей среды между затрубным пространством и внутренним каналом скважинной трубчатой металлической конструкции. Скважинное поточное устройство состоит из скользящей муфты и трубчатой части, вытянутой в осевом направлении и содержащей первое отверстие и второе отверстие, смещенное относительно первого в осевом направлении. Скользящая муфта выполнена с возможностью скольжения внутри трубчатой части между первым положением, обеспечивающим закрывание отверстия, и вторым положением, обеспечивающим полное открывание отверстия. Трубчатая часть содержит первую и вторую канавки. Первая канавка расположена на первом расстоянии от второй канавки вдоль осевого направления. Скользящая муфта содержит выступающую часть, выполненную с возможностью зацепления с первой канавкой в первом положении и со второй канавкой во втором положении. Трубчатая часть содержит третью канавку, выполненную с возможностью ее зацепления ...

ВПУСКНОЕ УСТРОЙСТВО

Группа изобретений относится к нефтегазодобывающей отрасли, в частности к впускному устройству (1) для регулирования потока текучей среды между коллектором (2) углеводородов и эксплуатационной обсадной колонной в скважине. Устройство включает первую трубу (4), имеющую осевую протяженность и по меньшей мере одно впускное отверстие (5) и первую стенку (6) с по меньшей мере первым осевым каналом (7), проходящим в первой стенке от указанного впускного отверстия, вторую трубу (8), имеющую первый и второй конец (9) и по меньшей мере одно выпускное отверстие (11). Вторая труба установлена с возможностью вращения внутри первой трубы, при этом она имеет вторую стенку (12) с по меньшей мере вторым осевым каналом, проходящим во второй стенке от первого конца к выпускному отверстию. Повышается надежность, расширяются технологические возможности. 3 н. и 13 з.п. ф-лы, 14 ил.

УЗЕЛ МУФТЫ ГИДРОРАЗРЫВА, УСТРОЙСТВО НА ЕГО ОСНОВЕ И СПОСОБ ЕГО ИСПОЛЬЗОВАНИЯ

Группа изобретений относится к горному делу и может быть применена при гидроразрыве пласта. Узел муфты гидроразрыва содержит композитную муфту и открывающий инструмент. Композитная муфта и открывающий инструмент могут автоматически сцепляться друг с другом с помощью размещенных на них зубообразных элементов для того, чтобы открыть композитную муфту. Устройство на основе муфты гидроразрыва содержит множество композитных муфт и открывающих инструментов, где каждая композитная муфта и каждый открывающий инструмент могут осуществлять уникальное сцепление. Кроме того, предложен способ использования устройства на основе муфты гидроразрыва. Технический результат заключается в повышении эффективности гидроразрыва пласта. 5 н. и 26 з.п. ф-лы, 30 ил.

ТОЛКАТЕЛЬ

Забойный толкатель для смещения забойного компонента содержит корпус с позиционирующим устройством, созданным на корпусе для сцепления или взаимодействия с забойным компонентом для обеспечения совмещения толкателя с компонентом. Инструмент дополнительно включает в себя соединительный элемент, созданный на корпусе и перемещающийся для избирательного зацепления соединительного профиля забойного компонента. Технический результат заключается в повышении эффективности забойного толкателя для смещения забойного компонента. 3 н. и 49 з.п. ф-лы, 7 ил.

СКОЛЬЗЯЩАЯ МУФТА

Изобретение относится к технической области освоения нефтегазовых скважин и стимуляции залежи. Скользящая муфта содержит верхний соединитель, нижний соединитель, внешний корпус, внутреннюю гильзу и сдвиговый штифт. Верхний соединитель и нижний соединитель соответственно соединены с двумя концами наружного корпуса. Внутренняя гильза фиксируется во внешнем корпусе посредством сдвигового штифта. Отверстие для направления потока выполнено во внешнем корпусе. Внутренняя гильза может открывать или закрывать отверстие для направления потока. По меньшей мере одна канавка для зацепления с по меньшей мере одним соответствующим зубчатым элементом на инструменте для открывания скользящей муфты расположена вдоль осевого направления во внутренней гильзе. В канавке встроено эрозионно-устойчивое кольцо и внутренний диаметр этого эрозионно-устойчивого кольца больше внутреннего диаметра внутренней гильзы. Достигается технический результат – предотвращение разрушения скользящей муфты за счет противодействия ...

СКОЛЬЗЯЩАЯ МУФТА, ИМЕЮЩАЯ СУЖАЮЩЕЕСЯ, СДВОЕННО СЕГМЕНТИРОВАННОЕ ШАРОВОЕ СЕДЛО

Группа изобретений относится к скользящим муфтам и способам для обработки ствола скважины текучей средой. Технический результат заключается в обеспечении заклиненной посадки заглушки в седле для восприятия высокого давления, облегчения дробления заглушки, исключения ее скалывания или срезания по бокам. Скользящая муфта, открывающаяся сброшенной заглушкой, содержит корпус, образующий первый канал и расходное отверстие, соединяющее первый канал с внешней средой корпуса; внутреннюю муфту, образующую второй канал и перемещаемую в осевом направлении из закрытого положения в открытое положение внутри первого канала по отношению к расходному отверстию; и седло, расположенное во втором канале внутренней муфты. Седло содержит посадочное кольцо, расположенное во втором канале в первом осевом положении и имеющее первый контактный размер, и сжимаемое кольцо, расположенное во втором канале и образующее пространство между верхним расширенным участком сжимаемого кольца и вторым каналом. Посадочное кольцо ...

СКОЛЬЗЯЩАЯ МУФТА С ИНВЕРТИРУЮЩИМСЯ ШАРОВЫМ ГНЕЗДОМ

Изобретение относится к средствам для ступенчатого гидроразрыва пласта. Скользящая муфта открывается сброшенным шаром. Муфта имеет гнездо, установленное в корпусе, и гнездо имеет сегменты с отклонением наружу друг от друга разрезным кольцом или другим отклоняющим элементом. Вначале гнездо имеет расширенное состояние в скользящей муфте, при этом сегменты гнезда расширены наружу в упор к каналу корпуса. Когда шар надлежащего диаметра сбрасывается на забой скважины, шар сцепляется с расширенным гнездом. Подаваемое давление текучей среды, действующее на посаженный в гнездо шар, перемещает гнездо в канал внутренней втулки. Гнездо сокращается, что увеличивает площадь сцепления гнезда с шаром. В конечном итоге гнездо достигает заплечика во внутренней втулке, при этом подаваемое давление, действующее на посаженный в гнездо шар, перемещает внутреннюю втулку в корпусе для открытия окна прохода потока скользящей муфты. Технический результат заключается в повышении эффективности скользящей муфты, открывающейся ...

СПОСОБ И УСТРОЙСТВА ДЛЯ ОСУЩЕСТВЛЕНИЯ КАРОТАЖА ПРИ ПОДНЯТИИ БУРОВОЙ КОЛОННЫ ИЗ СКВАЖИНЫ

Изобретение относится к технике бурения и предназначено для осуществления каротажа скважины во время подъема буровой колонны. Задачей изобретения является обеспечение получения каротажной диаграммы скважины, включая распределение пород по стволу, химические и физические характеристики. Перед началом обычного процесса бурения к буровой колонне непосредственно за долотом или как можно ближе к нему крепится переходник. Перед началом подъемного процесса в переходнике закрепляется измерительное устройство. В момент закрепления измерительного устройства в переходнике открывается окно, что дает возможность датчикам измерительного устройства взаимодействовать со скважиной. Во время подъема буровой колонны измерительное устройство собирает данные по длине скважины. 3 с. и 36 з.п.ф-лы, 6 ил.

СКВАЖИННАЯ КЛАПАННАЯ СИСТЕМА

Группа изобретений относится к скважинной клапанной системе для управления притоком текучей среды в пласт и из пласта, а также способу управления потоком текучей среды. Система содержит обсадную колонну, имеющую внутреннюю поверхность, наружный диаметр и внутренний диаметр, а также поперечное сечение, определенное внутренним диаметром. Обсадная колонна содержит множество клапанов, расположенных на расстоянии друг от друга для управления притоком текучей среды из пласта через обсадную колонну. Кроме того, система содержит множество автономных регулировочных устройств, каждое из которых управляет одним из множества клапанов и каждое из которых содержит корпус, имеющий наружный диаметр корпуса и поперечное сечение корпуса. При этом множество автономных регулировочных устройств закреплено внутри обсадной колонны для обеспечения возможности протекания текучей среды между наружным диаметром корпуса автономного регулировочного устройства и обсадной колонной. Технический результат заключается в ...

ДВУНАПРАВЛЕННЫЙ ИНСТРУМЕНТ С БАЙОНЕТНЫМ ПАЗОМ

Предложен многопозиционный инструмент для использования на забойном конце транспортировочной колонны для выполнения работ в обсадной колонне. Этот инструмент содержит оправку, соединенную с транспортировочной колонной; корпус механизма приведения в действие, выполненный с возможностью скольжения в осевом направлении вдоль оправки между устьевым положением, по меньшей мере одним промежуточным положением и забойным положением; устройство с устьевой стороны, выполненное с возможностью функционирования между положением приведения в действие, в котором корпус механизма приведения в действие находится в устьевом положении, и нерабочим положением; и устройство с забойной стороны, выполненное с возможностью функционирования между положением приведения в действие, в котором корпус механизма приведения в действие находится в забойном положении, и нерабочим положением. Как устройство как с устьевой, так и устройство с забойной стороны находятся в их нерабочих положениях, когда корпус механизма приведения ...

СКВАЖИННЫЙ ШАРОВОЙ КЛАПАН С ДВУНАПРАВЛЕННЫМ УПЛОТНЕНИЕМ И МЕХАНИЧЕСКИМ УПРАВЛЕНИЕМ

Изобретение относится к скважинным клапанным системам и может быть применено в лубрикаторном устройстве. Клапан смонтирован на колонне труб и отличается шаром, вращающимся вокруг своей оси и размещенным в клетке, где предусмотрено уплотнение относительно потоков, направленных в сторону забоя и устья скважины. Клетка взаимодействует с золотником, эксцентричным образом входящим в зацепление с шаром и вызывающим его поворот между положениями открытия и закрытия. Втулка приводится в движение механическим образом и перемещается в противоположных направлениях сдвигающим устройством, управляемым посредством троса. Перепад давления на шаре, находящемся в положении закрытия, не оказывает влияния на исполнительный поршень вследствие уравнивания давлений на этом поршне, благодаря чему перепад давления на шаре, находящемся в положении закрытия, сохраняется. Технический результат заключается в том, что запорный клапан способствует уравниванию давлений на исполнительном поршне, в то время как шар остается ...

СКВАЖИННАЯ КАМЕРА

Полезная модель относится к нефтяной промышленности, а именно к скважинному оборудованию, и может быть использована при добыче нефти или подаче рабочей жидкости в пласт.Технической задачей полезной модели является повышение потребительских свойств путем сокращения времени, необходимого для перехода на другие режимы работы пласта или скважины.Цель достигается тем, что скважинная камера, содержащая рубашку (корпус), соединенную с верхним и нижним переводниками, с расположенными внутри ниппелями и имеющую канал, соединяющий с затрубным пространством, и нижний переводник выполнен цельным и снабжен соединяющим с затрубным пространством скважины параллельным оси ступенчатым каналом, в котором закреплено калиброванное седло, взаимодействующее с установленным на внутреннем торце нижнего переводника плунжером регулирующего устройства управляемого, опускаемым во внутреннюю полость скважинной камеры приводом, при этом калиброванный канал в седле выполнен из расчета максимальной пропускной способности ...

ЦИРКУЛЯЦИОННЫЙ КЛАПАН БУРИЛЬНОЙ КОЛОННЫ

Изобретение относится к циркуляционным клапанам бурильной колонны. Клапан содержит трубчатый корпус, золотниковую втулку, размещенную внутри корпуса и имеющую седло, выполненное в центральном канале золотниковой втулки, направляющее кольцо, установленное во входной части корпуса, пружину, прижимающую золотниковую втулку к направляющему кольцу, через внутренние полости корпуса и седла золотниковой втулки осуществляется насосная подача текучей среды, а также содержит два закрепленных в корпусе циркуляционных порта с расходными отверстиями, циркуляционные порты закрыты золотниковой втулкой в неактивном режиме, при котором осуществляется насосная подача текучей среды по бурильной колонне, и открыты и обеспечивают сообщение с внутренним пространством бурильной колонны, когда циркуляционный клапан в активном режиме, а также содержит сбрасываемый активационный шар, выполненный с возможностью деформации и прохождения через седло золотниковой втулки при движении текучей среды по бурильной колонне ...

ВТУЛКА ПОШАГОВОГО ПЕРЕМЕЩЕНИЯ ДЛЯ МНОГОСТУПЕНЧАТОГО ГИДРОРАЗРЫВА ЗА ОДНУ СПУСКОПОДЪЕМНУЮ ОПЕРАЦИЮ

Группа изобретений относится к горному делу, в частности к способу и устройству для проведения гидроразрыва пластов. Устройство подачи текучей среды имеет датчик, обнаруживающий пробки (дротики, шары, и т.д.), проходящие через инструмент. Исполнительный механизм перемещает вставку в инструменте после прохода заданного числа пробок через инструмент. Перемещение данной вставки открывает ловитель на втулке в инструменте. После сброса следующей пробки ловитель соединяется с пробкой на втулке так, что давление текучей среды, приложенное к пробке, установленной в колонне насосно-компрессорных труб, может перемещать втулку. После перемещения втулка открывает окна в инструменте, осуществляя сообщение канала инструмента с окружающим кольцевым пространством, что обеспечивает обработку примыкающего к стволу скважины интервала пласта для интенсификации притока. Исполнительный механизм может использовать датчик, обнаруживающий проход пробок через инструмент. Пружина, размещенная в инструменте, может ...

СИСТЕМЫ И СПОСОБЫ ЗАКАНЧИВАНИЯ СКВАЖИН С МНОЖЕСТВОМ ЗОН

... 1. Система, предназначенная для использования в стволе скважины, имеющем множество зон скважины, содержащая колонну труб, расположенную в стволе скважины, и множество клапанов, соединенных с колонной труб и содержащих, каждый, по меньшей мере, одно отверстие для сообщения между колонной труб и одной из множества зон скважины и втулку, перемещаемую приводящим в действие устройством между открытым положением, в котором, по меньшей мере, одно отверстие открыто, и закрытым положением, в котором, по меньшей мере, одно отверстие закрыто, причем приводящее в действие устройство содержит головную часть и хвостовую часть, головная часть имеет дискообразную или частично сферическую конструкцию, имеющую диаметр, немного меньший, чем внутренний диаметр колонны труб, а хвостовая часть имеет, по меньшей мере, одно ребро или полость, расположенную, по существу, перпендикулярно дискообразной или частично сферической конструкции.2. Система по п.1, в которой колонна труб является обсадной колонной.3. Система ...

КОМПОНОВКА ЦЕМЕНТИРОВАНИЯ ХВОСТОВИКА И УСТАНОВКИ ГРАВИЙНОГО ФИЛЬТРА ОТ НОСКА К ПЯТКЕ В ОДНОМ РЕЙСЕ

... 1. Устройство гравийного фильтра и цементирования для ствола скважины, содержащее:корпус, развертывающийся в стволе скважины и имеющий корпусной канал, носок и пятку, причем корпус образует по меньшей мере одно окно заполнения гравийного фильтра на носке, окно для возвращающейся из скважины текучей среды на пятке, и окно цементирования между по меньшей мере одним окном заполнения гравийного фильтра и окном для возвращающейся из скважины текучей среды, причем корпус имеет по меньшей мере один фильтр, расположенный между по меньшей мере одним окном заполнения гравийного фильтра и окном цементирования; ивнутреннюю колонну, развертывающуюся с возможностью перемещения в корпусном канале и образующую канал колонны с выпускным окном,причем внутренняя колонна, перемещенная в первое селективное положение в корпусном канале, уплотняет выпускное окно вместе с по меньшей мере одним окном заполнения гравийного фильтра и осуществляет передачу суспензии гравийного фильтра из канала колонны в ствол скважины ...

МУФТА ДЛЯ МНОГОСТАДИЙНОГО ГИДРАВЛИЧЕСКОГО РАЗРЫВА ПЛАСТА

Изобретение относится к нефтегазовому оборудованию, в частности к оборудованию для заканчивания скважин, и может быть использовано для проведения гидроразрыва пласта и других операций по обработке скважин, а также для селективной добычи нефти и газа. Муфта для гидроразрыва пласта содержит корпус, выполненный из соединенных между собой верхнего и нижнего патрубков, внутреннюю втулку с отверстиями, стопорное кольцо для фиксации внутренней втулки в открытом или закрытом положении, уплотнители для герметизации, защищенные от прямого контакта с потоком. Нижний патрубок выполнен с отверстиями, совпадающими с отверстиями во внутренней втулке, позволяющими переход потока из внутреннего пространства во внешнее. В нижнем патрубке установлен центрирующий штифт. На внутренней втулке вырезан профиль, в котором установлен центрирующий штифт для защиты от вращения внутренней втулки и обеспечения полного совпадения отверстий в нижнем патрубке и во внутренней втулке относительно друг друга. Стопорное кольцо ...

СПОСОБ ГИДРАВЛИЧЕСКОГО РАЗРЫВА ПЛАСТА С ОДНОТОЧЕЧНЫМ ВВОДОМ

СКВАЖИННОЕ УСТРОЙСТВО ОТВОДА ПОТОКА С ОСЦИЛЛИРУЮЩИМ ДЕМПФЕРОМ

ПРИВОДИМЫЕ В ДВИЖЕНИЕ СКВАЖИННЫЕ ИНСТРУМЕНТЫ ДЛЯ ПРИКРЕПЛЕНИЯ К ТРУБЧАТЫМ КОЛОННАМ

СКВАЖИННАЯ СИСТЕМА ДЛЯ ОТКАЧИВАНИЯ ЖИДКОСТИ

ЗАХВАТНОЕ УСТРОЙСТВО

СКОЛЬЗЯЩАЯ МУФТА, ИМЕЮЩАЯ СУЖАЮЩЕЕСЯ СЕГМЕНТИРОВАННОЕ ШАРОВОЕ СЕДЛО

КЛАПАННОЕ УСТРОЙСТВО

... 1. Клапанное устройство для скважины, содержащий корпус клапана и клапанный элемент; причемкорпус клапана включает первый проход, который проходит через корпус клапана и выполнен с возможностью проведения через него колонны труб, и по меньшей мере один второй проход, который проходит через корпус клапана и вбок от первого прохода;корпус клапана выполнен с возможностью его присоединения к выходу скважины с обеспечением возможности протекания текучей среды, текущей из выхода скважины, внутрь первого прохода и внутрь каждого второго прохода из первого прохода;клапанный элемент выполнен с возможностью его введения внутрь первого прохода и с возможностью перемещения относительно корпуса клапана, чтобы тем самым управлять протеканием текучей среды из первого прохода внутрь каждого второго прохода.2. Клапанное устройство по п.1, в котором второй проход наклонен относительно первого прохода.3. Клапанное устройство по одному из пп.1 и 2, в котором корпус клапана также включает клапанное седло для ...

СИСТЕМА И СПОСОБ РЕГУЛИРОВАНИЯ ПОТОКА ФЛЮИДА

МНОГОСТУПЕНЧАТОЕ ИЗОЛИРОВАНИЕ СКВАЖИНЫ И ГИДРАВЛИЧЕСКИЙ РАЗРЫВ ПЛАСТА

СКОЛЬЗЯЩАЯ МУФТА, ИМЕЮЩАЯ СКОШЕННОЕ, СУЖАЮЩЕЕСЯ, СЕГМЕНТИРОВАННОЕ ШАРОВОЕ СЕДЛО

МЕХАНИЗМ ДЛЯ АКТИВИРОВАНИЯ МНОЖЕСТВА СКВАЖИННЫХ УСТРОЙСТВ

... 1. Механизм для избирательного активирования множества путей прохода в забойной зоне ствола скважины, содержащий клапан, включающий в себя втулку, приспособленную для перемещения между открытым и в нормально закрытым положением, и группу магнитов клапана, установленных на втулке, и дротик, предназначенный для подачи насосом в ствол скважины и включающий в себя группу магнитов дротика, согласованных с группой магнитов клапана так, что дротик соединяется с клапаном при расположении вблизи него, и втулка перемещается из закрытого положения в открытое положение.2. Механизм по п.1, в котором втулка имеет углубление, в котором установлена группа магнитов клапана, и дротик включает в себя подвижно установленные рычаги, причем группа магнитов дротика установлена на рычагах так, что при магнитном соединении рычаги перемещаются в углубление и закрепляют дротик во втулке.3. Механизм по п.2, в котором углубление имеет скос, и рычаги образуют участок закрепления, соединяющийся с углублением и имеющий ...

УСТРОЙСТВО, СИСТЕМЫ И СПОСОБЫ МНОГОСТУПЕНЧАТОЙ СТИМУЛЯЦИИ

СКВАЖИННАЯ КОНСТРУКЦИЯ

ТРУБНАЯ ИСПОЛНИТЕЛЬНАЯ СИСТЕМА И СПОСОБ

... 1. Трубная исполнительная система, содержащая:множество последовательностей исполнительных механизмов, установленных в трубном изделии, при этом, по меньшей мере, одна из последовательностей имеет несколько исполнительных механизмов, причем каждый из множества исполнительных механизмов, по меньшей мере, в одной из последовательностей можно изменить, переведя из первого положения, обеспечивающего проход пробок меньше выбранного габарита, во второе положение, обеспечивающее приведение в действие пробками выбранных диаметров, причем множество исполнительных механизмов, по меньшей мере, в одной из последовательностей распределено в трубном изделии так, что расположенный выше по потоку из любых двух из множества исполнительных механизмов может входить в контакт для срабатывания большей одной из пробок, чем расположенный ниже по потоку из двух из множества исполнительных механизмов, когда переведен во второе положение, и множество последовательностей распределены так, что для любых двух последовательностей ...

СКВАЖИННЫЕ РАЗДВИЖНЫЕ РАСШИРИТЕЛИ

... 1. Устройство (100) раздвижного расширителя для увеличения ствола скважины в подземной формации, содержащее ! трубчатый корпус (108), имеющий продольную ось (L8), внутренний канал (151), наружную поверхность (183) и по меньшей мере одну направляющую (148) в трубчатом корпусе (108), проходящую между внутренним каналом (151) и наружной поверхностью (183) с наклоном вверх и наружу под острым углом к продольной оси (L8), ! проход для потока бурового раствора через внутренний канал (151), ! одну или более лопасти (101, 102, 103), каждая из которых снабжена по меньшей мере одним режущим элементом (104), приспособленным для удаления материала подземной породы при расширении ствола скважины, причем по меньшей мере одна лопасть (101) соединена с возможностью скольжения с по меньшей мере одной направляющей (148) трубчатого корпуса (108), ! толкающую гильзу (115), размещенную во внутреннем канале (151) трубчатого корпуса (108) и соединенную с по меньшей мере одной лопастью (101) с возможностью перемещения ...

ВНУТРИСКВАЖИННЫЙ ИНСТРУМЕНТ СБРОСА ПРОБКИ

... 1. Инструмент сброса пробки, содержащий:корпус, образующий камеру;пробку, изначально установленную в камере; иэлемент, установленный с корпусом и приводимый в действие для выборочного обеспечения связи между камерой и кольцевым пространством, по меньшей мере частично образованным корпусом, причем пробка выполнена с возможностью перемещения в кольцевое пространство, когда обеспечивается связь.2. Инструмент по п. 1, в котором пробка является шаром.3. Инструмент по п. 1, в котором корпус включает в себя окно, выборочно блокирующееся элементом.4. Инструмент по п. 1, в котором элемент является стержнем, размещенным в корпусе с возможностью скольжения.5. Инструмент по п. 1, в котором элемент включен в состав по меньшей мере с одной трубной головкой, причем трубная головка выполнена с возможностью предотвращения выхода пробки из камеры.6. Инструмент по п. 5, в котором трубная головка и элемент расположены на аксиально противоположных сторонах пробки и соединены по меньшей мере одной стойкой для ...

ЗАБОЙНАЯ СИСТЕМА КЛАПАНОВ С ГИЛЬЗОВЫМ ЗАТВОРОМ И СПОСОБ ЕЕ ПРИМЕНЕНИЯ

... 1. Забойный инструмент, содержащий:трубное изделие, включающее в себя окно;первый управляемый шаром механизм, включающий в себя первый затвор, аксиально перемещающийся в трубном изделии из первого положения, закрывающего окно, во второе положение, открывающее окно, первое шаровое гнездо, перемещающееся с первым затвором, и опору первого шарового гнезда, несущую первое шаровое гнездо и соединенную в первом состоянии с возможностью отсоединения с первым затвором; ивторой управляемый шаром механизм, включающий в себя второй затвор, аксиально перемещающийся в трубном изделии из первого положения, открывающего окно, во второе положение, закрывающее окно, и второе шаровое гнездо, перемещающееся со вторым затвором, при этом отверстие первого шарового гнезда меньше отверстия второго шарового гнезда.2. Забойный инструмент по п. 1, в котором первый затвор в продольном направлении отделен от второго затвора, и первый затвор установлен ближе к дну забоя, чем второй затвор.3. Забойный инструмент по ...

Клапан сливной скважинный

Изобретение относится к оборудованию для эксплуатации нефтедобывающих скважин, в частности к устройствам сливных клапанов для погружных нефтяных насосов, и может быть использовано в составе компоновки установки электроцентробежного насоса. Клапан сливной скважинный содержит корпус в виде ниппеля с осевым отверстием и соединительными резьбами на концах. В стенке корпуса выполнены ступенчатые радиальные отверстия. В одном из радиальных отверстий установлен рабочий элемент в виде мембраны из пластичного материала, неподвижно закрепленной гайкой. Между мембраной и гайкой установлена шайба, диаметр отверстия которой соответствует величине заданного давления разрушения мембраны, чем обеспечивается возможность гидравлического способа активации путем повышения давления в колонне. В другом радиальном отверстии неподвижно установлен рабочий элемент в виде втулки с глухим сливным отверстием, герметичность взаимодействия которой с радиальным отверстием обеспечивается уплотнением. Втулка с уплотнением ...

WERKZEUG ZUM ABDICHTEN EINES STEIGROHRES.

DOPPELPACKER FÜR AUFBLASBAREN PACKER

Rohrschieber bzw. Drehschieber zur Steuerung eines Fluidflusses

Selbst-füllende Zementierschleuse und Verfahren

SICHERHEITSVENTIL

A well tool with a sliding sleeve which opens or closes a bypass passage

A tool or sub 11 includes a sleeve 33 with a bypass port 49 in a central bore 15 defined by a tubular body 13. The sleeve is selectively moveable from an upper position to a lower position. A seal 38 on the sleeve seals the sleeve to the bore while a retainer 47 holds the sleeve in the upper position. A bypass passage 27 in the body is in fluid communication with the bypass port. A drop member 55 lands on the sleeve, blocking downward flow through the sleeve so that pressure builds up until retainer or shear pin 47 shears, thus enabling fluid to flow from above the bore through the bypass passage and via the port. Other inventions relate to a running tool with a hydraulically actuated function and a bypass passage with a cross sectional flow area that is at least equal to a flow area through a central passage. Other inventions include other methods and apparatus related to downhole tools.

Multi-interval wellbore treatment method

Ball operated by-pass tool for use in drilling

Methods and apparatus related to an expandable port collar

Method and apparatus for sealing an annulus around a drill-pipe when drilling down-hole

Hydraulic control and actuation system for downhole tools

Downhole valve apparatus

Riser pressure relief apparatus

Riser pressure relief apparatus

A riser pressure relief apparatus comprising a tubular riser having a main passage and a side port to connect the main passage with the exterior of the riser, a pressure relief valve including a valve member which is movable between a first position in which the valve member substantially prevents flow of fluid through the side port and a second position in which flow of fluid through the side port is permitted, a hydraulic actuator (10) which is operable to move the valve member, a source of pressurised fluid (12), and a pilot valve assembly controlling the flow of pressurized fluid to the actuator, wherein the pilot valve assembly includes a valve part (14) which is fluidly connected to the main passage of the riser and moves from a first position to a second position when the fluid pressure in the main passage of the riser exceeds a predetermined amount.

Advanced fluidics gate valve with active flow control for subsea applications

Multi-zone gravel pack system with pipe coupling and integrated valve

Positive shut-off ported casing apparatus for well cementing

... 688,727. Well packers. BAKER OIL TOOLS, Inc. Dec. 4, 1950, No. 29655/50. Class 85. A valve-controlled ported casing apparatus for cementing a well bore, Fig. 1, comprises a tubular member 10 forming part of a conduit string B, C and having a side port 14, a lower inner sleeve valve member 15 disposed initially across the port to close it, and an outer sleeve valve member 31 on the exterior of the tubular member which is disposed initially to allow fluid passage through the port but which is hydraulically shiftable to the port-closing position by fluid fed under pressure through an opening 37, normally closed by a releasably secured upper inner sleeve valve member 45. In operation, with both sets of ports 14, 37 closed as in Fig. 1, cement slurry is pumped directly into the casing string and passes through the-central bores of the inner valve members 15, 45 to be discharged, e.g. from a casing shoe, into the annulus around the casing string. A weighted plug member 51, Fig. 5, is then dropped ...

Ball and dart launcher with parallel axis release

A junk catcher and a method of operation of same

Closure device for surge pressure rduction tool

DISASTER VALVE

... 1321801 Wells &c BAKER OIL TOOLS Inc 19 Jan 1971 2513/71 Heading E1F The subject matter of this specification is substantially the same as that described in Specification 1222496 but the claims differ.

APPARATUS FOR COMPLETION OF A SUBTERRANEAN WELL

Downhole-adjustable flow control device for controlling flow of a fluid into a wellbore

System and method for controlling flow in a wellbore

Subterranean well shifting tool for positive equalization movement.

A subterranean well tool is provided and method of its use described wherein a shiftable sleeve (SM) covering a fluid flow communication port P may be moved from a first sealingly closed position to an intermediate pressure equalizing position without the sleeve (SM) inadvertently being shifted to a third fully open position. The tool is moved into the well until it engages the sleeve SM. The tool then shifts the sleeve downwardly to the intermediate pressure equalizing piston. Further downward movement of the tool causes its release from the sleeve so that the sleeve will remain in the equalizing position. The sleeve is moved to its fully open position by a second tool after the first tool has been removed from the well. ...

Downhole circulation valve operated by dropping balls

A downhole tool (10) for selectively circulating fluid in a borehole is disclosed. The tool operates via the use of a combination of deformable drop balls (36) and smaller hard drop balls (40). In use a deformable drop ball (36) moves a sleeve (20) exposing a radial port (30,32) to provide fluid circulation radially from the tool. The smaller drop ball (40) can then obstruct the radial port (32,30) and by the increased pressure the deformable drop ball (36) is extruded through the tool. The resulting pressure differential as the drop ball (36) moves causes the sleeve (20) to rise, releasing the smaller drop (40) ball and closing the radial port (32,30). The process can be repeated to selectively circulate fluid through the tool.

Flow control device

Flow control device

A flow control device / sleeve valve for controlling the flow of fluid into a production tubing comprises an outer 13 and an inner sleeve 15 defining an annular chamber 20, and apertures 14 are provided on the outer sleeve 13, and apertures 16, 24 are provided on the inner sleeve 15. Seals 17, 18 and 19 are provided for isolating the apertures 14, 16 and 24. The seal 18 is seated on an annular insert 21 which forms a small annular passage 22 with the inner sleeve 15, and grooves 23 are also provided on the inner sleeve 15. Together the grooves 23 and the small annular passage 22 allows a small rate of fluid to bypass the seal 18 and enter the apertures 16, 24, thus reducing fluid pressure acting on the seal 18, and reducing erosion of the seal 18 and the apertures 16, 24. The aperture 24 is tapered around its edges as an extra safeguard against erosion.

Method for catching drop balls

A method for selectively retaining drop balls in a tool string is disclosed, the method comprising the steps: (a) inserting in a tool string 12 a ball catcher 10 including a first bore 26 having retaining means and a second bore 28b passing therethrough, the bores including an overlapping portion to provide a channel therebetween; (b) dropping a first ball 50 of a first diameter through the tool string; (c) directing the first ball 50 into the first bore 26; and (d) retaining the first ball 50 in the first bore 26. The method may also include the steps (a) dropping a second ball of a second diameter, the second diameter being smaller than the first diameter through the tool string; (b) directing the second ball into the first bore 26; (c) passing the second ball through the channel into the second bore 28; and (d) releasing the second ball from the ball catcher 10 into the tool string.

Erosion resistent aperture for a downhole valve or ported flow control tool

An aperture design minimizes erosion on the surrounding casing and to the aperture itself and is particularly effective in fluid injection wells where large volumes of fluids over a long period of time with entrained solids are expected to be pumped through. The preferred design is an elongated shape with a flaring wider in the downhole direction. The downhole end of the opening features an exit that flares in the downhole direction with multiple slopes with an arc transition. Other options for the opening configuration are envisioned.

Shear activated safety valve system

METHOD AND APPARATUS FOR STOPPING WELL PRODUCTION

METHOD FOR COMPLETION OF A SUBTERRANEAN WELL

A method is provided for completion of a subterranean well. The method includes inserting a casing conduit section member (10) within the well, one end of member 10 being secured to a casing conduit string (C). A valve member (11) is carried by the conduit section (10) and is selectively shiftable in at least one direction from a first position to a second position. A cylindrical wall is defined on the casing conduit section and has inner and outer surfaces, with the wall, upon perforation within the well, providing fluid flow passageways PF therethrough for transmission of the well fluids from the exterior of the casing conduit section to the interior. Means are provided on the valve member (11) for cooperation with an auxiliary shifting means (ST) for movement of the valve member (11) from one of the first and the second positions to either close or open the fluid flow passageways.

Down hole installations

In use a motor 9 drives a pump 11 to force oil and gas up the tube 7. The motor and pump can be raised partially within the liner 2 or removed from the liner 2. A packer 8 remains in the liner when the motor and pump are raised and kill fluid may be added to isolate the region below the packer from the region above. The packer 8 may incorporate a valve to isolate the producing zone when the pump is removed. ...

Downhole lubricator for installation of extended assemblies

Downhole lubricator for installation of extended assemblies

The wellbore is adapted for use as a lubricator for assembly of lengthy installations. The subsurface safety valve is used in conjunction with a nipple inserted into the wellbore and held in position by a packer. A plug is part of the nipple assembly. Upon setting of the packer, two barriers downhole are created to facilitate assembly of tools such as a perforating gun in the wellbore behind two barriers. The tool, such as a perforating gun, has a running tool below it which engages the plug. When the assembly is made up in the wellbore, the plug is engaged by the running tool and released from the nipple. The plug can then be advanced through the open subsurface safety valve to the proper location for deployment of a perforating gun, for example. Upon completion of the downhole procedures, such as perforating, the tools are brought uphole and the plug is sealingly relatched in the nipple, thus recreating the necessary two barriers to permit opening the wellbore at the surface to remove ...

Choke valve with rotatable sleeve

A choke valve 100 is disclosed for controlling the flow of fluid through a production tubing (10, fig 1A). The valve includes a housing 20 having axially aligned apertures 25 and a ported sleeve 30 disposed within the housing. The ported sleeve has rows of fluid ports 35. Each row of ports has at least one port in selective fluid communication with a respective aperture. In the full open position, each aperture is in fluid communication with a port from each row. To choke the flow, the ported sleeve is rotated relative to the housing to reduce the number of ports in fluid communication with the housing. To close the valve, axial force is applied to move the ported sleeve axially relative to the housing. An actuator for rotating a sleeve disposed within a housing is also disclosed.

Apparatus and methods for isolating a sand screen assembly and testing the seal within a wellbore

An isolation apparatus (and method of use) which comprises a sand screen assembly 28 and a tubular string (22, fig. 2) disposed in a wellbore, an isolation assembly 56 movable within the sand screen assembly between an open configuration and a closed configuration, where when the isolation assembly is in the closed configuration fluid communication through the sand screen assembly is prevented. Further a test assembly attached to the tubular string which is capable of being positioned in an open and a closed configuration, where when the test assembly is in the open configuration hydraulic communication between the interior of the isolation assembly and the annulus between the tubular string and the wellbore above the test assembly is achieved. Further disclosed are a method of gravel packing, isolating and testing a sand screen completion in a single trip which comprises placing an isolation pipe in sealing contact with a sand screen assembly and a method of completing a well by isolating ...

Gravel packing method

Infinitely variable control valve apparatus and method

Methods and systems for optical endpoint detection of a sliding sleeve valve

Downhole tool with catcher

An apparatus that is usable with a well includes a string and a plurality of tools 14 that are mounted in the string. The string includes a passageway. The tools are mounted in the string and are adapted to transition to a state to catch objects. The objects may be free-falling objects and/or pumped-down objects and they may be of substantially the same size. The tools may comprise valves utilising sliding sleeves and the tool may comprise a sealing surface adapted to prevent a seal from forming between a falling object and the surface.

One trip cemented expandable monobore liner system and method

An apparatus for diverting fluid flow out of a work string

A downhole apparatus for diverting fluid flow out of a work string comprising a top sub 10 connected to a piston housing 20 and an upper piston 70, a middle piston 80 and a lower piston 90 are positioned within the housing as is a locating sleeve 110 which has a j-track 115. A locating pin 45 connected to the piston housing is located within the j-track. A spring housing 40 containing spring 55 is connected to a lower end of the piston housing. A ported housing 50, having a plurality of ports 130 is connected to the lower end of the spring housing and a lower sub 60 is connected to a lower end of the ported housing. A flow tube 100 having a restriction 105 is located within the central bores of the ported, spring and piston housings and is connected to the locating sleeve. Fluid flow through the restriction creates an increase in fluid pressure causing the movement of the pistons. The pistons move the flow tube between various locations within the apparatus. In one location, the flow tube ...

Retractable ball seat having a time delay material

Removable injection or production flow equalization valve

Hydraulic shifting tool for sliding sleeves

Drill pipe

Stage tool with lower tubing isolator

WELL TEST TOOL

PLUGS FOR WELL LOGGING OPERATIONS

DUAL FLAPPER VALVE ASSEMBLY

WELL APPARATUS

DUAL FLAPPER VALVE ASSEMBLY.

A dual flapper valve assembly (10A, 10B) permits a well logging operation to be carried out after a gravel pack has been deposited without losing a large amount of completion fluid into the formation. The dual flapper valves (10A, 10B) can be closed and have frangible closure plates 70A and 70B which can be fracture independently of each other and selectively to accommodate a gravel pack operation, a well logging operation and a completion fluid recovery operation. The closure plate (70B) of the lower flapper valve (10B) is propped open by a wash pipe (46T) during the gravel pack operation. The lower closure plate (70B) is fractured to accommodate a well logging operation, while the closure plate (70A) of the upper flapper valve (10A) is held open by a prop sleeve (100). Upon completion of the well logging operation, the prop sleeve (100) is retracted out of engagement with the closure plate (70A) of the upper flapper valve (10A), thereby permitting the upper flapper valve to close. The ...

Dedicated perforated nipple with integral isolation sleeve

A production nipple (22) is suspended within an uncased bore hole in a slimhole/monobore completion. A deposit of cement 42 is conveyed through the nipple and is spotted in the annulus across the face of the uncased well bore, with the nipple and cement deposit thereafter being perforated by a small diameter perforating gun (44). The production nipple has a thin walled section (58A) which is characterised by reduced resistance to perforation by a shaped explosive charge. The perforating gun is accurately positioned in registration with the dedicated nipple section by an annular locator slot (74) formed on a coupling sub, which is engageable by a resilient latch arm (76) carried by the perforating gun. An isolation sleeve 64 can be raised to cover the perforations and thus prevent inward flow of unwanted fluids. ...

Downhole tool

Flow control device

Liner hanger fluid diverter tool and related methods

A downhole fluid diverter tool includes a tool body having a central bore therethrough and a bypass port formed in an outer diameter thereof, a spring-biased piston disposed within the tool body, a piston port in the spring-biased piston configured to axially align with the bypass port to control fluid flow outward from the central bore, and a rotatable ball valve aligned within the central bore of the tool body and configured to control fluid flow through the central bore, wherein the bypass port and the ball valve are configured to be cycled multiple times between open and closed positions while in a wellbore.

Arrangement of Isolation Sleeve and Cluster Sleeves Having Pressure Chambers

For wellbore fluid treatment, sliding sleeves deploy on tubing in a wellbore annulus. Operators deploy a plug down the tubing to a first sleeve. The plug seats in this first sleeve, and pumped fluid pressure opens the first sleeve and communicates from the tubing to the wellbore annulus. In the annulus, the fluid pressure creates a pressure differential between the wellbore annulus pressure and a pressure chamber on second sleeves on the tubing. The resulting pressure differential opens the second sleeves so that fluid pressure from the tubing can communicate through the second open sleeves. Using this arrangement, one sleeve can be opened in a cluster of sleeves without opening all of them at the same time. The deployed plug is only required to open the fluid pressure to the annulus by opening the first sleeve. The pressure chambers actuate the second sleeves to open up the tubing to the annulus.

Apparatus and Methods for Allowing Fluid Flow Inside at Least One Screen and Outside a Pipe Disposed in an Well Bore

In some embodiments, apparatus for allowing fluid flow inside at least one screen and outside a span of pipe disposed in a well bore includes at least one flow path for fluid entering at least one screen. The flow path extends from the screen(s) along the outside of the pipe to at least one desired entry inlet into the pipe without at least substantial entry at any point therebetween.

Fracturing System and Method

A system and method for fracturing a stage of a multiple stage hydrocarbon production well. One embodiment of the system comprises at least one ported sleeve assembly and a flapper assembly positioned downwell of the ported sleeve assembly. Each ported sleeve assembly comprises a ported housing having a plurality of ports disposed radially therethrough; a first sleeve at least partially within the ported housing and moveable between a first position and a second position, wherein in the first position the first sleeve is radially positioned between the plurality of ports and the flowpath. The first sleeve has an exterior surface, a first slot formed in the first exterior surface, and a first engagement surface having a first inner diameter. A first guiding member is fixed relative to the ported housing and positionable within the first slot. A first compression spring positioned between the a upper end of the first sleeve and the ported housing, the first compression spring being under compression when the first sleeve is in the first position. The flapper assembly comprises a flapper seal; a flapper plate rotatable between an opened position and a closed position, wherein in the opened position fluid flow in the downwell direction through the flapper seal is at least substantially unimpeded, and wherein in the closed position the flapper plate is engaged against the flapper seal to at least substantially prevent fluid flow through the flapper seal in the downwell direction; a second sleeve moveable between a first position and a second position, wherein in the first position at least a portion of the second sleeve is radially positioned between the flapper plate and the flowpath, the second sleeve having a second exterior surface, a second slot formed in the second exterior surface, and a second engagement surface having a second inner diameter; a second guiding member fixed relative to the flapper seal and positionable within the second walking jay slot; and a ...

Formation treatment system and method

A formation treatment system includes an annulus spanning member having one or more openings therein, the one or more openings incorporating a degradable material. A tubular having one or more ports therein in fluid communication with the one or more openings. A sleeve capable of isolating or communicating the one or more ports with an ID of the tubular. A method for effecting precision formation treatment is included.

Selective dart system for actuating downhole tools and methods of using same

Plug element systems comprise a tubular member having at least two seats. An eccentrically-shaped plug member comprises an upper end portion and a lower end portion. The upper end portion comprises an upper end diameter can be less than, greater than, or equal to a lower end portion diameter of the lower end portion. The eccentric shape of the plug member permits it to pass through a first seat and land on a second seat comprising a second seat length where both the first seat and the second seat comprise substantially equal inner seat diameters.

Tubular actuating system and method

A tubular actuating system includes a plurality of series of actuators disposed within a tubular with at least one of the series having a plurality of actuators. Each of the plurality of actuators in the at least one of the series is alterable from a first position allowing passage of plugs below a selected size to a second position allowing actuation by plugs of selected sizes. The plurality of actuators of the series are distributed within the tubular such that the more upstream of any two of the plurality of actuators is actuatingly engagable with a larger one of the plugs than the more downstream of the two of the plurality of actuators when in the second position, and the plurality of series is distributed such that for any two of the series the more upstream of the two series requires a larger plug to alter the actuators therewithin.

Method of reducing deflection through a rod piston in a subsurface safety valve

An actuation assembly including a sleeve member having a radially outwardly extending projection and a piston having an axis, the piston operatively coupled to the projection of the sleeve member and arranged to exert an actuation force on the projection of the sleeve member for actuating the sleeve member, the actuation force positioned about radially aligned with the axis or radially outwardly from the axis.

Well-based fluid communication control assembly

An apparatus includes a base pipe, a screen and a first assembly. The screen at least partially circumscribes the base pipe to create a flow path between a first region that is outside of the screen and a second region that is inside the base pipe. The flow path includes at least one radial port of the base pipe and a third region between the screen and the exterior of the base pipe. The first assembly regulates fluid communication through the flow path. The first assembly includes a second assembly that is disposed in and mounted to the base pipe and a flow control device that is slidably connected to the second assembly. The flow control device is adapted to translate between at least two positions to regulate the fluid communication through the flow path.

Multi-Zone Screened Frac System

A multi-zone screened frac system combines screens with integrated check valves, frac valves, and optional shunt tubes for slurry dehydration. The system can also include fiber optic technology. In particular, the system uses sliding sleeves and flow devices for each section. The sliding sleeves open with dropped balls or a service tool, and the flow devices have screens and act as check valves. Dehydration tubes can also be used. The system does not require a crossover tool, and in some implementations, the system does not even require a complete service tool.

Downhole Actuating Apparatus

A mechanical counting device for actuating a plurality of output devices, the device comprising: linear indexing means adapted to count a plurality of actuating signals and to cause actuation of the output devices when a predetermined number of actuating signals for each output device has been received, wherein the mechanical counting device is adapted to cause actuation of a particular output device when a different predetermined number of actuating signals has been received such that the output devices are sequentially actuable.

Sliding Sleeve Valve with Feature to Block Flow Through the Tool

Sliding sleeve valves that include a housing with an axial flowbore defined along its length and at least one lateral fluid port disposed through the housing. One or more sliding sleeve members are disposed within the flowbore and carry first and second ball seats. Landing a first ball onto the first ball seat will move the valve from a first position wherein lateral flow is blocked to a second position wherein lateral flow is permitted. Landing a second ball onto the second ball seat will move the valve to a third position wherein lateral flow is again blocked and axial flow is permitted.

Multiple Shift Sliding Sleeve

A system of sliding valves wherein the inserts of multiple sliding valves may be shifted to an open position using a single shifting ball. Each individual sliding valve has a movable insert that, depending upon the position of the insert within the sliding valve, may either block or permit fluid to radially flow between the interior and exterior of the sliding valve. The insert has a profile about the interior of the movable insert allowing a shifting tool to connect to and move the insert so that fluid may be prevented from entering the interior portion of the sliding sleeve.

System and method for servicing a wellbore

A wellbore servicing apparatus, comprising a housing defining an axial flowbore and comprising ports, a first sleeve, a second sleeve movable relative to the housing from (a) a first position in which the second sleeve obstructs fluid communication via the ports of the housing to (b) a second position in which the second sleeve allows fluid communication via the ports of the housing, and wherein the first sleeve is movable relative to the housing from (a) a first position in which the first sleeve does not allow a fluid pressure applied to the axial flowbore to move the second sleeve from the first position to the second position to (b) a second position in which the first sleeve allows a fluid pressure applied to the axial flowbore to move the second sleeve from the first position to the second position, and an expandable seat.

Minimal travel flow control device

A technique facilitates controlling flow in a wellbore with a simplified valve. The design of the valve also enables reduction in the overall length of the valve to improve spatial considerations. The valve comprises a valve component, e.g. a flapper, movable between a closed position and an open position. A flow tube is designed to selectively open the valve component with reduced travel, thus enabling a shortened flow tube. The short flow tube enables use of valve housings, springs, and other valve components having a reduced length.

Tools and Methods for Use in Completion of a Wellbore

A ported tubular is provided for use in casing a wellbore, to permit selective access to the adjacent formation during completion operations. A system and method for completing a wellbore using the ported tubular are also provided. Ports within the wellbore casing may be opened, isolated, or otherwise accessed to deliver treatment to the formation through the ports, using a tool assembly deployed on tubing or wireline. 1. A method for shifting a sliding sleeve in a wellbore , comprising:providing a valve continuous with a wellbore tubular, the valve comprising a ported housing and a port closure sleeve slidably disposed within the ported housing;providing a tool assembly comprising: a locating device and a resettable sealing member;deploying the tool assembly within the wellbore on wireline;locating the resettable sealing assembly within the port closure sleeve;setting the sealing member across the sliding sleeve; andapplying a downward force to the sealing member to slide the sleeve with respect to the ported housing.2. The method as in claim 1 , wherein the step of setting the sealing member comprises application of a radially outward force with the sealing member to the sleeve so as to frictionally engage the sleeve with the sealing member.3. The method as in claim 2 , wherein the sleeve comprises an inner surface of uniform diameter along its length claim 2 , free of any profile.4. The method as in claim 2 , wherein the sleeve has an inner diameter consistent with the inner diameter of the wellbore tubular.5. The method as in claim 1 , wherein the step of applying a downward force to the sealing member comprises delivering fluid to the wellbore to increase the hydraulic pressure above the sealing member.6. The method as in claim 5 , wherein the port closure sleeve is initially retained in a closed position with respect to the ported housing by a hydraulic pressure above the sealing member generated by the fluid delivery is sufficient to exceed a threshold force ...

Method and apparatus for wellbore fluid treatment

A tubing string assembly for fluid treatment of a wellbore includes substantially pressure holding closures spaced along the tubing string, which each close at least one port through the tubing string wall. The closures are openable by a sleeve drivable through the tubing string inner bore.

BARRIER VALVE SYSTEM AND METHOD OF CLOSING SAME BY WITHDRAWING UPPER COMPLETION

A completion system, including a barrier valve transitionable between an open position and a closed position. An upper completion is operatively coupled with the barrier valve for mechanically transitioning the barrier valve to the closed position when the upper completion is withdrawn. A method of operating a completion system is also included. 1. A completion system , comprising:a barrier valve transitionable between an open position and a closed position; andan upper completion operatively coupled with the barrier valve for mechanically transitioning the barrier valve to the closed position when the upper completion is withdrawn.2. The completion system of claim 1 , wherein mechanical movement of the upper completion also enables the upper completion to transition the barrier valve to the open position.3. The completion system of claim 1 , wherein the upper completion comprises a production string.4. The completion system of claim 1 , wherein the upper completion includes a stroker that is actuatable by fluid pressure for mechanically moving the barrier valve between the open and closed positions.5. The completion system of claim 1 , wherein the barrier valve is part of an intermediate assembly located between a lower completion and the upper completion.6. The completion system of claim 5 , wherein the lower completion includes at least one assembly for enabling stimulation claim 5 , hydraulic fracturing claim 5 , frac packing claim 5 , gravel packing claim 5 , or a combination including at least one of the foregoing.7. The completion system of claim 5 , wherein the intermediate assembly includes a packer device for isolating the borehole claim 5 , anchoring the intermediate assembly claim 5 , or a combination including at least one of the foregoing.8. The completion system of claim 7 , wherein the upper completion is a production string run in with a removable plug for enabling the packer device of the intermediate assembly to be set by pressurizing fluid ...

DOWNHOLE VALVE ASSEMBLY

A downhole valve assembly operable to control production fluid flow around an obstruction in a production tubing string. The obstruction may be caused by another valve or valve assembly located in the production tubing string, where the valve is closed and blocks flow through the production tubing. The downhole valve assembly comprises a tubular body that includes an axial passage extending through the body and one or more ports extending substantially radially through the body. The downhole valve assembly also includes one or more actuating members operable to move relative to the body. Movement of the actuating members selectively opens the ports such that a fluid flow path through the ports is defined between an annulus region outside of the valve assembly and the axial passage such that the blockage can be bypassed. 1. A downhole valve assembly operable to control production fluid flow around an obstruction in a production tubing string , the downhole valve comprising:a tubular body comprising an axial passage extending therethrough;one or more ports extending substantially radially through the tubular body; andone or more actuating members operable to move relative to the tubular body to selectively open the ports such that a fluid flow path through the ports is defined between an annulus region outside of the valve assembly and the axial passage.2. The downhole valve assembly according to claim 1 , comprising a mechanically actuated actuating member.3. The downhole valve assembly according to claim 2 , wherein the mechanically actuated actuating member is adapted for mechanical engagement with a removable downhole tool such that upon removal of the downhole tool the actuating member may be moved from a first position to a second position claim 2 , wherein when the mechanically actuated actuating member is in the second position the valve assembly is in a primed state.4. The downhole valve assembly according to claim 3 , wherein the mechanically actuated ...

Expandable apparatus and related methods

An expandable reamer apparatus and methods for reaming a borehole, wherein a laterally movable blade carried by a tubular body may be selectively positioned at an inward position and an expanded position. The laterally movable blade, held inwardly by blade-biasing elements, may be forced outwardly by drilling fluid selectively allowed to communicate therewith by way of an actuation sleeve disposed within the tubular body. Alternatively, a separation element may transmit force or pressure from the drilling fluid to the movable blade. Further, a chamber in communication with the movable blade may be pressurized by way of a downhole turbine or pump. A ridged seal wiper, compensator, movable bearing pad, fixed bearing pad preceding the movable blade, or adjustable spacer element to alter expanded blade position may be included within the expandable reamer. In addition, a drilling fluid pressure response indicating an operational characteristic of the expandable reamer may be generated.

Completion Method for Stimulation of Multiple Intervals

A technique provides for stimulating or otherwise treating multiple intervals/zones of a well by controlling flow of treatment fluid via a plurality of flow control devices. The flow control devices are provided with internal profiles and flow through passages. Mechanical darts are designed for engagement with the internal profiles of specific flow control devices, and each mechanical dart may be moved downhole for engagement with and activation of the specific flow control device associated with that mechanical dart.

Differential Shifting Tool and Method of Shifting

A shifting tool and method of shifting a downhole device that requires only a minimal profile or no profile to engage and move the movable portion of the tool. The invention comprises a ported housing assembly and at least one friction pad alignable with said at least one port and radially movable through the port between a first pad position and a second pad position. In the second pad position, the friction pad extends outside said outer diameter of said housing assembly to engage the targeted downhole device. A mandrel positioned through the ported housing has a first section with a first outer diameter and a second section with a second outer diameter, said second outer diameter being greater than said first outer diameter. The mandrel is movable between a first mandrel position and a second mandrel position. In the second mandrel position, the second outer diameter supports the friction pads in the second pad position.

APPARATUS AND METHOD FOR FRACTURING A WELL

Apparatus and methods are provided for fracturing a well in a hydrocarbon bearing formation. The apparatus can include one or more valve sub-assemblies assembled into a tubing string inserted into an unlined well. The valve sub-assembly can include a sliding piston initially pinned in place to seal off ports that provide communication between the interior of the tubing string and a production zone of the formation. A ball can be inserted into a tubing string and moved along the tubing string by injected pressurized fracturing fluid until the ball sits on a valve seat of a valve sub-assembly coupled to the sliding piston to close off the tubing string below the valve. The force of the fluid forces the piston downwards to shear off the pins and open the ports. Fracturing fluid can then exit the ports to fracture the production zone of the formation. 1. An apparatus for fracturing a well in a formation , comprising:(a) a tubular valve body comprising an upper end and a lower end, and a valve passageway extending therethrough, the valve body further comprising at least one valve port extending through a sidewall thereof, the at least one valve port located nearer the upper end;(b) a tubular piston valve slidably disposed in the valve passageway and configured to provide communication therethrough, the piston valve configured to move from a raised position where the at least one valve port is closed to a lowered position where the at least one valve port is open;(c) a ball seat sub-assembly slidably disposed in the valve passageway between the piston valve and the lower end, the ball seat sub-assembly comprising a ball seat passageway extending therethrough; and(d) an inner piston sub-assembly releasably coupled to the piston valve and configured to disengage from the piston valve when pulled away from the ball seat;wherein the ball seat sub-assembly is configured to move the piston valve from the raised position to the lowered position when downward force is applied to ...

APPARATUS AND METHOD FOR FLUID TREATMENT OF A WELL

A wellbore fluid treatment apparatus includes a tubing string including a first port with a first closure disposed thereover to close the first port to fluid flow and a second port spaced axially uphole from the first port and having a second closure disposed thereover to close the second port to fluid flow; and an actuator tool configured to move through the tubing string and (i) to set a seal in the tubing string downhole of the first port; (ii) to actuate the first closure to open the first port; and (iii) to actuate the second closure to open the second port. A method for treating a well may employ the tool. 1. A wellbore fluid treatment apparatus comprising:a tubing string including a first port with a first closure disposed thereover to close the first port to fluid flow and a second port spaced axially uphole from the first port and having a second closure disposed thereover to close the second port to fluid flow; andan actuator tool configured to move through the tubing string and (i) to set a seal in the tubing string downhole of the first port; (ii) to actuate the first closure to open the first port; and (iii) to actuate the second closure to open the second port.2. The wellbore of wherein the tubing string includes a seal device installed axially downhole from the first port and the actuator tool is configured to set the seal by actuating the seal device.3. The wellbore of wherein the seal device includes a ball seat claim 2 , a valve or an expandable plug.4. The wellbore of wherein the tubing string includes a seal device installed axially downhole from the first port claim 1 , the seal device being positionable between a stored position and a set position and the tool is configured to set the seal by actuating the seal device between the stored position and the set position.5. The wellbore of wherein the seal device includes is a ball seat claim 4 , a valve or an expandable plug.6. The wellbore of wherein the ball seat is formed by a plurality of ball ...

Apparatus and Method for Fracturing a Well

An apparatus and method is provided for fracturing a well in a a hydrocarbon bearing formation. The apparatus can include a valve subassembly that is assembled with sections of casing pipe to form a well casing for the well. The valve subassembly includes a sliding piston that is pinned in place to seal off ports that provide communication between the interior of the well casing and a production zone of the formation. A dart can be inserted into the well casing and propelled by pressurized fracturing fluid until the dart reaches the valve subassembly to plug off the well casing below the valve subassembly. The force of the fracturing fluid against the dart forces the piston downwards to shear off the pins and open the ports. The fracturing fluid can then exit the ports to fracture the production zone of the formation. 1. An apparatus for fracturing a well , comprising:a) a tubular valve body comprising upper and lower ends defining communication therebetween, the valve body further comprising at least one port extending through a sidewall thereof nearer the upper end;b) a tubular piston slidably disposed in the valve body and configured to provide communication therethrough, the piston closing the at least one port in a closed position, the piston opening the at least one port in an open position;c) means for moving the piston from the closed position to the open position when a downward force is placed on the piston; andd) a tubular end cap disposed on the lower end of the valve body, the end cap configured to stop the piston when the piston moves from the closed position to the open position.2. The apparatus as set forth in where the moving means comprises a tubular sleeve disposed in the piston and configured to provide communication therethrough claim 1 , the sleeve further comprising at least two grooves disposed on an interior sidewall thereof extending from an upper end to a lower end thereof claim 1 , the sleeve and piston configured whereby the piston will ...

Integrated opening subsystem for well closure system

Certain aspects and embodiments of the present invention are directed to a subsurface safety valve that can be disposed in a wellbore that is through a fluid-producing formation. The subsurface safety valve can include a closure mechanism, a sleeve, and a control line. The closure mechanism can be positioned in a passageway defined by a tubing string. The closure mechanism can be configured to prevent a flow of fluid to a portion of the passageway that is closer to a surface of the wellbore than the closure mechanism. The sleeve can be positioned in the passageway adjacent to the closure mechanism. The control line can communicate pressure to a piston from a pressure source within an inner diameter of the tubing string, causing the piston to apply a force to the sleeve. The sleeve can open the closure mechanism in response to the force being applied to the sleeve.

METHOD AND APPARATUS FOR WELLBORE FLUID TREATMENT

A tubing string assembly is disclosed for fluid treatment of a wellbore. The tubing string can be used for staged wellbore fluid treatment where a selected segment of the wellbore is treated, while other segments are sealed off. The tubing string can also be used where a ported tubing string is required to be run in in a pressure tight condition and later is needed to be in an open-port condition. 116-. (canceled)17. A wellbore fluid treatment assembly comprising:a tubing string including an inner bore and a tubular housing with a wall, an outer wall surface and an inner wall surface defining the inner bore through the tubular housing, the tubing string further including an uphole drift diameter uphole of the tubular housing;a port through the wall of the tubular housing, the port providing access between the outer wall surface and the inner wall surface through the port;a sliding sleeve installed in the tubular housing inner bore and slidable between (i) a closed-port position covering the port, wherein fluid cannot pass through the port, and (ii) a open-port position exposing the port to the inner bore and wherein fluid can pass through the port, the sliding sleeve including an outer diameter, an inner diameter defining an axial bore and a constriction along the inner diameter forming a seat; anda plug moved by fluid pressure through the tubing string and sized to seal against the seat to drive the sliding sleeve from the closed-port position to the open-port position by fluid pressure;wherein the seat is retrievable up through the tubular housing and axially moved up through the inner bore to remove the constriction from the tubing string.18. The wellbore fluid treatment of wherein after removing the constriction from the tubing string claim 17 , the inner bore has a diameter substantially the same or greater than the uphole drift diameter.19. The wellbore fluid treatment of further comprising a plurality of tubular housings spaced apart in the tubing string and ...

Downhole Fluid Treatment Tool

A treatment device and method for use in delivering fluid treatment to a wellbore is described. The device includes a first treatment housing and a second treatment housing, mounted along a tubing string, each of the first and second housing defining a fluid pathway which is continuous with the tubing string and each of the first and second treatment housing defining a port for fluid communication between the tubing string and the wellbore. Fluid flow through the first housing may be selectively blocked by delivery of a deformable ball to the tubing string to seal against a ball seat disposed between the first and second housing. While the first pathway is blocked, fluid may be selectively delivered to the wellbore through the port on the second treatment housing. The ball may be removed from the ball seat by application of hydraulic pressure in excess of the deformation threshold of the ball, forcing the ball to deform and pass through the seat, re-opening the fluid flow through the first treatment housing and allowing for treatment through port defined in the first housing.

WIRELINE CONVEYED APPARATUS FOR WELLBORE FLUID TREATMENT

A wellbore treatment apparatus includes: a tubing string including a wall defining an inner diameter and a port extending through the wall, the port closed by a closure including a plug-actuated sliding sleeve; and a port opening apparatus including a wireline deployable through the inner diameter of the tubing string to extend to a position adjacent the plug-actuated sliding sleeve and an actuator plug carried on and axially slideable along the wireline, the actuator plug sized to land in the plug-actuated sliding sleeve to actuate the plug-actuated sliding sleeve, while remaining on the wireline. The apparatus can be employed in a method by running the tubing string into a well, placing the slickline in the string and running the actuator plug along the wireline to land on and actuate a sleeve in the string. 1. A wellbore treatment apparatus comprising: a tubing string including a wall defining an inner diameter and a port extending through the wall , the port closed by a closure including a plug-actuated sliding sleeve; and a port opening apparatus including a wireline deployable through the inner diameter of the tubing string to extend to a position adjacent the plug-actuated sliding sleeve and an actuator plug carried on and axially slideable along the wireline , the actuator plug sized to land in the plug-actuated sliding sleeve to actuate the plug-actuated sliding sleeve , while remaining on the wireline.2. The wellbore treatment apparatus of wherein the actuator plug includes a hole therethrough through which the wireline passes to retain the actuator plug on the wireline claim 1 , and the wireline passes through the hole as the actuator plug slides along the wireline.3. The wellbore treatment apparatus of further comprising a seal positioned in the hole between the wireline and the actuator plug to resist fluid flow through the hole.4. The wellbore treatment apparatus of wherein the tubing string has a long axis claim 1 , a distal end claim 1 , a second ...

Exercising a Well Tool

An exercise tool assembly for operating a downhole tool auxiliary to a primary actuator system of the downhole tool includes a cylinder mandrel configured to be received in the central bore of the downhole tool. A piston mandrel is in and sealed with the cylinder mandrel. The exercise tool assembly is configured to couple to an actuator sleeve of the downhole tool and to couple to the downhole tool at a location apart from the actuator sleeve. The piston mandrel is responsive to a change in pressure in the central bore to translate relative to the cylinder mandrel and translate the coupling with the actuator sleeve relative to the coupling at the location apart from the actuator sleeve. 1. An exercise tool assembly for operating a downhole tool auxiliary to a primary actuator system of the downhole tool , the exercise tool assembly comprising:a cylinder mandrel configured to be received in a central bore of the downhole tool; anda piston mandrel in and sealed with the cylinder mandrel, the exercise tool assembly configured to couple to an actuator sleeve of the downhole tool and to couple to the downhole tool at a location apart from the actuator sleeve, the piston mandrel responsive to a change in pressure in the central bore to translate relative to the cylinder mandrel and translate the coupling with the actuator sleeve relative to the coupling at the location apart from the actuator sleeve, where the piston mandrel is responsive to an increase in pressure to translate from a first position to a second position, and the exercise tool assembly comprises a return spring configured to return the piston mandrel to the first position in response to a decrease in pressure.2. The exercise tool assembly of claim 1 , where the cylinder mandrel comprises an inlet that claim 1 , when the exercise tool assembly is residing in the central bore claim 1 , is in hydraulic communication with the central bore and that hydraulically communicates pressure from the central bore to ...

DUAL CLOSURE SYSTEM FOR WELL SYSTEM

Certain aspects and embodiments of the present invention are directed to a dual closure system disposed within a wellbore and capable of preventing the production of fluids from a fluid-producing formation to the surface. The dual closure system can include a passive closure mechanism and a subsurface safety valve coupled to an electric submersible pump positioned within a passageway defined by the tubing string. The passive closure mechanism and the subsurface safety valve can prevent production of fluid in the absence of the subsurface safety valve. The subsurface safety valve can be positioned within a passageway defined by a tubing string such that the subsurface safety valve can apply force to the passive closure mechanism. The force applied to the passive closure mechanism can maintain the passive closure mechanism in an open position, allowing movement of fluid to the surface in the presence of the active closure mechanism. 1. A dual closure system configured for being disposed in a wellbore through a fluid-producing formation , the dual closure system comprising:a subsurface safety valve configured to be coupled to an electric submersible pump, the subsurface safety valve comprising an active closure mechanism configured to be positioned in a passageway defined by a tubing string; anda passive closure mechanism coupled to the tubing string, wherein the passive closure mechanism is configured to be in a closed position that prevents a flow of fluid to a portion of the passageway that is closer to a surface of the wellbore than the passive closure mechanism in the absence of the subsurface safety valve in the passageway;wherein the subsurface safety valve is configured to be positioned in the passageway of the tubing string such that the subsurface safety valve causes the passive closure mechanism to be in an open position that allows the flow of fluid to a second portion of the passageway that is closer to the surface of the wellbore than the passive closure ...

Selectively Corrodible Downhole Article And Method Of Use

A selectively corrodible downhole article includes a movable cylindrical member comprising a first section and an axially separated second section, the first section comprising a first material having a first galvanic activity, the second section comprising a second material having a second galvanic activity, the first galvanic activity being greater than the second, the first section being electrically isolated from the second section; and a fixed member disposed on the cylindrical member and configured for electrical contact with the first or second section, the fixed member comprising an intermediate material having an intermediate galvanic activity, the intermediate galvanic activity being intermediate the first and second galvanic activity, the movable cylindrical member configured for movement from a first position where the first section is disposed and in electrical contact with the fixed member and a second position where the second section is disposed and in electrical contact with the fixed member.

Indexing Sleeve for Single-Trip, Multi-Stage Fracing

A flow tool has a sensor that detects plugs (darts, balls, etc.) passing through the tool. An actuator moves an insert in the tool once a preset number of plugs have passed through the tool. Movement of this insert reveals a catch on a sleeve in the tool. Once the next plug is deployed, the catch engages the plug on the sleeve so that fluid pressure applied against the seated plug through the tubing string can move the sleeve. Once moved, the sleeve reveals ports in the tool communicating the tool's bore with the surrounding annulus so an adjacent wellbore interval can be stimulated. The actuator can use a sensor detecting passage of the plugs through the tool. A spring disposed in the tool can flex near the sensor when a plug passes through the tool, and a counter can count the number of plugs that have passed.

SYSTEM, APPARATUS AND PROCESS FOR COLLECTING BALLS FROM WELLBORE FLUIDS CONTAINING SAND

A ball catcher for recovering balls from wellbore fluids containing sand during flow back operations. The ball catcher has a receiving chamber for receiving the wellbore fluids containing sand, a first flow outlet for discharging a portion of the wellbore fluids and sand contained therein, and a diverter for redirecting balls entrained within the wellbore fluids. The redirected balls and a balance of the wellbore fluids also containing sand are received in a ball-retaining chamber. A blocker fit to the ball-retaining chamber retains the recovered balls therein while the balance of the wellbore fluids and sand contained therein is discharged from a second flow outlet and directed to downstream equipment through an auxiliary flow line. The retaining chamber can be isolated allowing the balls to be removed from the ball catcher without disrupting the flow back operation. 1. A process for recovering balls carried in wellbore fluids returning from a wellhead , the wellbore fluids containing sand , comprising:receiving the wellbore fluids and sand contained therein in a receiving chamber;discharging a portion of the wellbore fluids and sand contained therein free of the balls, through a first flow outlet, while discharging a balance of the wellbore fluids and sand contained therein to a ball-retaining chamber;redirecting the balls to the ball-retaining chamber;blocking balls within the ball-retaining chamber from discharging therefrom; anddischarging the balance of the wellbore fluids and sand contained therein, free of the balls, from the ball-retaining chamber,wherein the portion of the wellbore fluids and sand contained therein discharged through the first flow outlet and the balance of the wellbore fluids and sand contained therein discharged from the ball-retaining chamber are directed separately to distinct downstream equipment.2. The process of claim 1 , further comprising:collecting the blocked ball in a ball-recovery chamber fluidly connected to the ball- ...

ACTUATION LOCKOUT SYSTEM

An actuation system, including a first member having a first profile engagable with a tool operatively arranged for actuating the member from an initial configuration to an actuated configuration. A second member is included that is movable relative to the first member. The second member has a lockout feature configured to prevent engagement of the first member with the tool while the second member is located proximate to the first member. A method of selectively actuating a system is also included. 1. An actuation system , comprising:a first member having a first profile engagable with a tool operatively arranged for actuating the member from an initial configuration to an actuated configuration; anda second member movable relative to the first member, the second member having a lockout feature configured to prevent engagement of the first member with the tool while the second member is located proximate to the first member.2. The system of claim 1 , wherein the second member has a second profile engagable with the tool or another tool for enabling the second member to be moved away from first member.3. The system of claim 1 , wherein the lockout feature includes a radial protrusion operatively arranged to cause one or more fingers of the tool to flex radially away from an engagement surface of the profile for preventing engagement of the tool with the first member.4. The system of claim 1 , wherein the second member is initially held proximate to the first member by a release member.5. The system of claim 4 , wherein the release member is a shear screw.6. The system of claim 1 , further comprising a locking mechanism for holding the second member in a position away from the first member.7. The system of claim 6 , wherein the locking mechanism is a lock ring.86. The system of claim 6 , wherein the locking mechanism forms a ratchet engagement with the second member.9. The system of claim 1 , wherein the first and second members are sleeves.10. The system of claim 1 ...

Remotely Activated Down Hole Systems and Methods

Systems and methods for remotely setting a down hole device. The system includes a base pipe having inner and outer radial surfaces and defining one or more pressure ports extending between the inner and outer radial surfaces. An internal sleeve is arranged against the inner radial surface and slidable between a closed position, where the internal sleeve covers the one or more pressure ports, and an open position, where the one or more pressure ports are exposed to an interior of the base pipe. A trigger housing is disposed about the base pipe and defines an atmospheric chamber in fluid communication with the one or more pressure ports. A piston port cover is disposed within the atmospheric chamber and moveable between blocking and exposed positions. A wellbore device is used to engage and move the internal sleeve into the open position by applying predetermined axial force to the internal sleeve.

Disposable downhole tool

A disposable downhole tool is disclosed. The tool is suitable for use as a frac tool. The tool includes a housing having an inner wall surface defining a bore. The tool also includes a valve structure disposed within the bore, the valve structure comprising a disposable plug seat, the disposable plug seat comprising a first natural rock material. The disposable tool may also include a disposable plug in fluid sealing engagement with the seat, the plug comprising a second natural rock material, the plug and the plug seat comprising a plug valve. The first and second natural rock materials may include sedimentary rock, such as various forms of limestone, including Carrara marble or Indiana limestone.

DOWNHOLE COMPLETION

The present invention relates to a downhole completion comprising a production casing () and a sliding sleeve assembly () connected as part of a production casing, comprising a tubular part () and a tubular sleeve (). 1100. A downhole completion () , comprising{'b': '4', 'a production casing (), and'}{'b': 1', '4, 'a sliding sleeve assembly () connected as part of a production casing (), comprising{'b': 2', '27', '3', '5', '28, 'a tubular part () forming part of the production casing and having a recess (), an inner face (), an opening () and an axial extension (),'}{'b': 26', '8, 'a tubular sleeve () slidable within the recess and having an outer face () and being slidable in the axial extension along the inner face between a first position, wherein fluid is allowed to flow through the opening, and a second position, wherein the fluid is hindered from flowing through the opening, and'}{'b': '9', 'a sealing element () is arranged in connection with the sleeve at its outer face,'}{'b': '13', 'wherein the opening comprises a valve (), such as an inflow control valve.'}2. A downhole completion according to claim 1 , wherein the opening has a width (w) in the axial extension and the sealing element has a width (w) which is larger than the width (w) of the opening.310. A downhole completion according to claim 1 , wherein the tubular sleeve has at least one circumferential groove () arranged at its outer face.4. A downhole completion according to claim 3 , wherein the sealing element is arranged in the groove.5. A downhole completion according to claim 1 , wherein the sleeve has at least two circumferential grooves claim 1 , each groove comprising a sealing element.6. A downhole completion according to claim 5 , wherein the opening has a width (w) in the axial extension and the sealing elements are arranged with an axial distance which is larger than the width of the opening.7. A downhole completion according to claim 1 , wherein the sealing element is a chevron seal or ...

INFLOW ASSEMBLY

The present invention relates to a an inflow assembly () for controlling fluid flow between a hydrocarbon reservoir () and a production casing in a well, comprising a first tubular () having an axial extension and at least one inlet () and a first wall () with at least a first axial channel () extending in the first wall from the inlet, a second tubular () having a first () and a second end () and at least one outlet (), the second tubular being rotatable within the first tubular and having a second wall () with at least a second axial channel extending in the second wall from the first end to the outlet. The invention further relates to an assembly for controlling fluid flow between a hydrocarbon reservoir and a production casing in a well. Finally, the present invention relates to a downhole completion comprising a casing string and one or more of the inflow assembly/assemblies according the invention. 11. An inflow assembly () for controlling fluid flow between a hydrocarbon reservoir and a production casing in a well , comprising{'b': 4', '5', '6', '7', '6', '5, 'a first tubular () having an axial extension and at least one inlet () and a first wall () with at least a first axial channel () extending in the first wall () from the inlet (),'}{'b': 8', '9', '10', '11', '8', '4', '12', '12', '9', '11, 'a second tubular () having a first () and a second end () and at least one outlet (), the second tubular () being rotatable within the first tubular () and having a second wall () with at least a second axial channel extending in the second wall () from the first end () to the outlet (),'}{'b': 8', '4', '7', '9', '8', '7, 'wherein the second tubular () is rotatable in relation to the first tubular () at least between a first position, in which the first () and second channels are in alignment for allowing fluid to flow from the reservoir into the casing via the first end () of the second tubular () and a second position, in which the first () and second channels are ...

Apparatus, Systems and Methods for Bypassing a Flow Control Device

A bypass assembly for use in a downhole tool comprises a chamber, a first fluid port in fluid communication with the chamber, a second fluid port in fluid communication with the chamber, a flow restrictor disposed in a first flow path between the first fluid port and the second fluid port, a piston moveable in a first direction by the application of a first fluid pressure, a biasing member, and a restraining member disposed adjacent to the piston. The biasing member biases the piston to move in a second direction opposite the first direction, and the restraining member is actuated by movement of the piston in the first direction in response to a predetermined fluid pressure. Movement of the piston in the second direction to a predetermined position configures the bypass assembly to divert fluid flow around the flow restrictor along a second flow path. 1. A bypass assembly for use in a downhole tool comprising:a chamber;a first fluid port in fluid communication with the chamber;a second fluid port in fluid communication with the chamber;a flow restrictor disposed in a first flow path between the first fluid port and the second fluid port;a piston moveable in a first direction by the application of a first fluid pressure;a biasing member, wherein the biasing member biases the piston to move in a second direction opposite the first direction; anda restraining member disposed adjacent to the piston, wherein the restraining member is actuated by movement of the piston in the first direction in response to a predetermined fluid pressure;wherein movement of the piston in the second direction to a predetermined position configures the bypass assembly to divert fluid flow around the flow restrictor along a second flow path.2. The bypass assembly of claim 1 , wherein the flow restrictor creates a first pressure drop in fluid flowing through the flow restrictor between the first port and the second port.3. The bypass assembly of claim 2 , wherein the flow restrictor and the ...

Wellbore Flow Control Devices Comprising Coupled Flow Regulating Assemblies and Methods for Use Thereof

Wellbore flow control devices can be used in various subterranean operations to regulate access of formation fluids to the interior of a wellbore pipe and/or to limit the access of unwanted fluids thereto. Coupling of flow regulating assemblies to one another in the wellbore flow control devices can result in improved operational performance in regulating formation fluid flow to the interior of the wellbore pipe compared to using the flow regulating assemblies in an uncoupled state. Wellbore flow control devices can comprise a gate valve assembly that is in fluid flow communication with a flow restricting assembly, where each assembly is located on the exterior of a wellbore pipe and the flow restricting assembly is in fluid flow communication with the interior of the wellbore pipe. 122.-. (canceled)23. A wellbore flow control device comprising: 'wherein the flow restricting assembly is in fluid flow communication with the interior of the wellbore pipe; and', 'a gate valve assembly that is in fluid flow communication with a flow restricting assembly, each assembly being located on the exterior of a wellbore pipe;'}a housing for the gate valve assembly and the flow restricting assembly that is operatively coupled to the wellbore pipe.24. A wellbore flow control device comprising: 'wherein the flow restricting assembly is in fluid flow communication with the interior of the wellbore pipe; and', 'a gate valve assembly that is in fluid flow communication with a flow restricting assembly, each assembly being located on the exterior of a wellbore pipe;'} wherein the gate valve assembly and the flow restricting assembly are in fluid flow communication with one another via a second flow pathway; and', 'wherein the gate valve assembly, when open, bridges between the first flow pathway and the second flow pathway., 'a well screen that is in fluid flow communication with the gate valve assembly via a first flow pathway that is upstream of the gate valve assembly;'}25. A ...

Downhole Circulating Valve Having a Seal Plug and Method for Operating Same

A downhole circulating valve includes a generally tubular outer housing having a generally axially extending internal passageway. At least one generally longitudinally extending circulating passageway is formed through at least a portion of the housing. At least one exterior port and at least one interior port are in fluid communication with the circulating passageway. At least one seal plug is disposed within the circulating passageway. The seal plug has a first position relative to the housing wherein the seal plug is remote from the exterior port and the interior port, thereby allowing fluid flow between the exterior port and the interior port through the circulating passageway. The seal plug has a second position relative to the housing wherein the seal plug is between the exterior port and the interior port and wherein the seal plug forms at least one metal-to-metal seal with the circulating passageway, thereby preventing fluid flow between the exterior port and the interior port.

VALVE SEAT ASSEMBLY, DOWNHOLE TOOL AND METHODS

A circulation tool includes a tubular outer body having a main bore and at least one flow port in a wall thereof, and a valve seat assembly including a valve body, a valve member, and locking elements are movably mounted within the outer body main bore. The valve seat assembly is biased towards a first position in which flow through the outer body flow port is prevented and the locking element is in the extended position, restricting passage of the valve member along the valve body bore and out of the valve body. The valve seat assembly is movable to a second position in which the locking element is in the retracted position, permitting passage of the valve member along the body bore and out of the body. The valve seat is also movable to a third position in which flow through the outer body flow port is permitted. 163-. (canceled)64. An apparatus comprising:a circulation tool comprising a tubular outer body having a main bore and at least one flow port in a wall thereof, anda valve seat assembly comprising a valve body, a valve member, and at least one locking element movably mounted within the main bore of the tubular outer body,wherein the valve body is adapted to receive the valve member. The present invention relates to a valve seat assembly, a downhole tool/circulation tool incorporating a valve seat assembly, a method of controlling fluid flow and a fluid circulation method. In particular, but not exclusively, the present invention relates to a valve seat assembly having a valve body adapted to sealingly receive a valve member such as a ball; a downhole tool/circulation tool incorporating such a valve seat assembly; and methods of controlling fluid flow and of circulating fluid by bringing a valve member into sealing abutment with a body of a valve seat assembly. The present invention also relates to a seal assembly, a seal, an indexing arrangement and an indexing member for use with a downhole tool.In the oil and gas exploration and production industry, a ...

Downhole Tool With Expandable Seat

A downhole tool comprising a housing having at least one flow port disposed providing a communication path between the interior and exterior of the sleeve. A sleeve assembly has an expandable seat and an inner sleeve, and is moveable within the housing between a first position and a second position, wherein in the first position the sleeve assembly is radially positioned between the flow ports and the flowpath to substantially prevent fluid communication. Shearable port inserts are positioned within the flow ports, with each port insert having a shearable portion extending into the interior of the housing and engaging the sleeve assembly when the inner sleeve is in said first position. 1a housing defining a flowpath and having an exterior and at least one flow port providing a communication path between said flowpath and said exterior;a sleeve assembly having an expandable seat and an inner sleeve, said sleeve assembly being moveable within said housing between a first position and a second position, wherein in said first position of said sleeve assembly is radially positioned between said at least one flow port and said flowpath to substantially prevent fluid communication therethrough;at least one shearable port insert positioned within said at least one flow port, said at least one shearable port insert having a shearable portion extending into the interior of said housing and engaging said sleeve assembly when said inner sleeve is in said first position.. A downhole tool for use in a hydrocarbon production well, the downhole tool comprising: This is a continuation application claiming the benefit of the filing date of U.S. application Ser. No. 12/702,169, filed Feb. 8, 2010, which is incorporated by reference herein.Not applicable.1. Field of the InventionThe present invention relates to a downhole tool for oil and/or gas production. More specifically, the invention is a well stimulation tool having an expandable seat for use with a tubing string disposed in a ...

VALVE ASSEMBLY

A valve assembly () which is configured to be coupled to a tubing string comprises a housing () defining a housing flow path () for communicating with the tubing string, and a barrier member () located in the housing () and configurable between a normally-closed position in which the barrier member () restricts access through the housing flow path (), and an open position in which access is permitted through the housing flow path (). The valve assembly () also comprises a bypass arrangement reconfigurable between an open state in which the bypass arrangement defines a bypass flow path that communicates with the housing flow path () on opposite sides of the barrier member () to permit fluid to bypass the barrier member and thereby fill the tubing string, and a closed state in which fluid is prevented from bypassing the barrier member to thereby permit pressurization of the tubing string. 1. A valve assembly configured to be coupled to a tubing string , comprising:a housing defining a housing flow path for communicating with the tubing string;a barrier member located in the housing and configurable between a normally-closed position in which the barrier member restricts access through the housing flow path, and an open position in which access is permitted through the housing flow path; anda bypass arrangement reconfigurable between an open state in which the bypass arrangement defines a bypass flow path that communicates with the housing flow path on opposite sides of the barrier member to permit fluid to bypass the barrier member and thereby fill the tubing string, and a closed state in which fluid is prevented from bypassing the barrier member to thereby permit pressurization of the tubing string.2. The valve assembly according to claim 1 , wherein the bypass arrangement is biased towards an open state to be configurable between a normally-open state and the closed state against said bias.3. The valve assembly according to claim 1 , wherein the housing flow path is ...

Multi-Cycle Ball Activated Circulation Tool with Flow Blocking Capability

A valve and method of use wherein the valve includes a housing having an axial flowbore defined along its length. A lateral fluid flow port is disposed through the housing. A piston sleeve is disposed within the flowbore and is selectively moveable to block flow through the lateral flow port. The valve can be moved between operating positions wherein flow through the lateral flow port is blocked or allowed and axial flow through the flowbore is blocked or permitted. 1. A valve comprising:a housing defining an axial flowbore along its length;a lateral fluid flow port disposed through the housing that provides fluid communication between the flowbore and an area radially surrounding the housing;a piston sleeve disposed within the flowbore and moveable to selectively block fluid flow through the lateral flow port;the valve being moveable between:an initial operating position wherein fluid flow through the flowbore is permitted and flow through the lateral fluid flow port is blocked and either of:a lateral flow operating position wherein axial fluid flow through the flowbore is permitted and flow through the lateral fluid flow port is permitted; andan alternate operating position wherein axial fluid flow through the flowbore is blocked and flow through the lateral fluid flow port is permitted.2. The valve of further comprising an upper ball seat that is operably associated with the piston sleeve claim 1 , the upper ball seat adapted to capture and release a small actuation ball claim 1 , a medium-sized actuation ball or a large actuation ball.3. The valve of further comprising a lower ball seat located within the flowbore below the piston sleeve claim 1 , the lower ball seat adapted to:capture and release a large actuation ball or a medium-sized actuation ball; andallow a small actuation ball to pass through.4. The valve of wherein the valve is moved from the initial operating position to the lateral flow operating position by landing a small or medium-sized actuation ...

Seat assembly with counter for isolating fracture zones in a well

A specially designed rotary indexing system and associated operational methods are incorporated in a downhole control device, representatively a sliding sleeve valve, having an outer tubular member in which an annular plug seat is coaxially disposed. The plug seat is resiliently expandable between a first diameter and a larger second diameter and is illustratively of a circumferentially segmented construction. The rotary indexing system is operative to detect the number of plug members that pass through and diametrically expand the plug seat, and responsively preclude passage of further plug members therethrough when such number reaches a predetermined magnitude. Such predetermined magnitude is correlated to the total rotation of an indexing system counter ring portion rotationally driven by axial camming forces transmitted to the rotary indexing system by successive plug member passage-generated diametrical expansions of the plug seat.

KOBE SUB, WELLBORE TUBING STRING APPARATUS AND METHOD

To address concerns of kobe plug cap portions being inadvertently removed, for example, by abutment with strings or tools passing thereby, a shielding structure may be employed to protect the cap against inadvertent removal. The port opening tool useful with the kobe plug is selected to overcome the shielding structure to open the kobe plug. To address concerns of a portion of the kobe plug becoming loose in the tubing string inner bore, a capturing mechanism may be provided that captures the cap portion after it is removed to open the kobe plug and prevented the cap portion from becoming loose in the inner bore of the tubing string. 1. A kobe sub comprising: a tubular body connectable into a wellbore tubing string , the tubular body including a wall including an outer surface and an inner surface defining an inner bore and a port through the wall; a kobe plug installed in the port with a cap portion accessible in the inner bore , a base mounted in the port and connected to the cap portion , a channel extending through the base and closed by the cap portion; and a shielding structure in the inner bore to shield the cap portion from protruding into the inner bore.2. The kobe sub of wherein the shielding structure includes a shielding wall extending alongside the cap portion.3. The kobe sub of wherein the shielding wall is a sidewall of a slot formed in the wall inner surface.4. The kobe sub of wherein the sidewall defines a slot depth and the slot depth is greater than the height of the cap portion such that the cap portion is fully recessed in the slot.5. The kobe sub of wherein the slot includes a return overlying a portion of the cap portion.6. The kobe sub of wherein the shielding wall includes an extension of the wall inner surface overlying a portion of the cap portion.7. The kobe sub of wherein the shielding structure is a sleeve installed in the inner bore and positioned to overlie at least a portion of the cap portion.8. The kobe sub of wherein the sleeve is ...

Kobe sub, wellbore tubing string apparatus and method

To address concerns of kobe plug cap portions being inadvertently removed, for example, by abutment with strings or tools passing thereby, a shielding structure may be employed to protect the cap against inadvertent removal. The port opening tool useful with the kobe plug is selected to overcome the shielding structure to open the kobe plug. To address concerns of a portion of the kobe plug becoming loose in the tubing string inner bore, a capturing mechanism may be provided that captures the cap portion after it is removed to open the kobe plug and prevented the cap portion from becoming loose in the inner bore of the tubing string.

Wellbore isolation while placing valves on production

An internal completion string is anchored within a closed casing valve of a production liner in a wellbore. The internal completion string comprises a packer and a shifting tool. The production liner comprises a casing valve having a port and a moveable member. The annulus defined between the production liner and the internal completion string is sealed, and the shifting tool is remotely operated to move the moveable member away from the port, thereby opening the casing valve.

Downhole deployment valves

Methods and apparatus enable reliable and improved isolation between two portions of a bore extending through a casing string disposed in a borehole. A downhole deployment valve (DDV) may provide the isolation utilizing a valve member, such as a flapper, that is disposed in a housing of the DDV and is designed to close against a seat within the housing. The DDV includes an operating mechanism for opening/closing the DDV. In use, pressure in one portion of a well that is in fluid communication with a well surface may be bled off and open at well surface while maintaining pressure in another portion of the casing string beyond the DDV.

Apparatus Configuration Downhole

A method comprising moving a shifting tool in a first direction through a moveable member positioned in a casing of a wellbore, including moving the shifting tool through a shifting tool interface member (STIM) adjacent the moveable member, until the shifting tool is positioned past the moveable member and the STIM. The shifting tool is then moved in a second direction substantially opposite the first direction until the shifting tool and the STIM engage. The shifting tool is then further moved in the second direction, thereby moving the STIM and the moveable member in the second direction, until the STIM substantially simultaneously (1) engages the casing and (2) disengages the shifting tool. 1. A method , comprising:moving a shifting tool in a first direction through a moveable member positioned in a casing of a wellbore, including moving the shifting tool into a shifting tool interface member (STIM) adjacent the moveable member;engaging the shifting tool and the STIM; and engages the casing; and', 'disengages the shifting tool., 'moving the shifting tool in a second direction substantially opposite the first direction, thereby moving the STIM and the moveable member in the second direction, until the STIM substantially simultaneously2. The method of wherein engaging the shifting tool and the STIM comprises moving the shifting tool in the second direction until the shifting tool and the STIM engage.3. The method of wherein the first direction is a downhole direction towards the bottom of the wellbore claim 1 , and wherein the second direction is an uphole direction away from the bottom of the wellbore.4. The method of wherein:the STIM comprises an engaging member moveable between a first position and a second position;the engaging member protrudes from an inner profile of the STIM when in the first position;the engaging member protrudes from an outer profile of the STIM when in the second position; andthe step of moving the shifting tool in the second direction ...

Downhole isolation tool having a ported sliding sleeve

A downhole isolation tool for insertion in a wellbore, for allowing, when a ported sliding sleeve thereof is slidably positioned in a first position and when coupled to a lower end of said pump apparatus, fluids within a hydrocarbon formation to be drawn through such tool and allowed to pass to the pump apparatus for pumping uphole, and when such sliding sleeve is positioned in a second position and decoupled from said lower end of the pump assembly, for preventing said fluids from passing therethrough and uphole.

UNDERBALANCE ACTUATORS AND METHODS

An actuation method according to one or more embodiments includes axially translating an operator in a first direction in response to applying a tubing pressure to a first side in excess of an annulus pressure acting on a second side, axially translating the operator in a second direction to an actuation position in response to applying an underbalance pressure level to the operator and operating a tool element from a first position to a second position in response to translating the operator to the actuation position. 1. An actuation method , comprising:axially translating an operator in a first direction in response to applying a tubing pressure to a first side of the operator in excess of an annulus pressure acting on a second side of the operator;axially translating the operator in a second direction to an actuation position in response to bleeding the tubing pressure to an underbalance pressure level; andactuating a tool element from a first position to a second position in response to axially translating the operator to the actuation position.2. The method of claim 1 , wherein the tool element is a valve member.3. The method of claim 1 , wherein the second position is an open position.4. The method of claim 1 , wherein the underbalance pressure level is the annulus pressure greater than the tubing pressure.5. The method of claim 1 , wherein the underbalance pressure level is the annulus pressure greater than the tubing pressure plus an underbalance biasing pressure.6. The method of claim 5 , wherein the underbalance biasing pressure is applied to the operator by a spring.7. The method of claim 6 , wherein the spring is a mechanical spring.8. A downhole tool claim 6 , comprising:an operator operationally connected with a tool element to actuate the tool element in response to movement of the operator to an actuation position;the operator having a first side open to a tubing pressure when installed in a wellbore and a second side open to an annulus pressure when ...

VALVE APPARATUS

A valve apparatus () for a well comprises a valve body (), and a valve member (). The valve body () includes a first passage () that extends through the valve body (), and at least one second passage () that extends through the valve body and laterally from the first passage (). The valve body () being connectable to the well so that a fluid flowing from the well is able to flow through the first passage (). The valve member () being insertable into the first passage () and being moveable relative to the valve body () so as to thereby control the flow of the fluid from the first passage () into each second passage (). 1. A valve apparatus for a well , the apparatus comprising a valve body , and a valve member , the valve body including a first passage that extends through the valve body and that a pipe string is able to extend through , and at least one second passage that extends through the valve body and laterally from the first passage , the valve body being connectable to an outlet of the well so that a fluid flowing from the well outlet is able to flow into the first passage and into each second passage from the first passage , the valve member being insertable into the first passage and being moveable relative to the valve body so as to thereby control the flow of the fluid from the first passage into each second passage.2. The valve apparatus of claim 1 , wherein the second passage is inclined relative to the first passage.3. The valve apparatus of claim 1 , wherein the valve body also includes a valve seat for engaging with the valve member.4. The valve apparatus of claim 1 , wherein the valve apparatus also includes an O-ring seal mounted on the valve member such that the O-ring seal is able to form a seal between the valve body and the valve member.5. The valve apparatus of claim 4 , wherein the valve member includes a first shoulder claim 4 , the valve body includes a second shoulder claim 4 , and the O-ring seal is supported on the first shoulder and is ...

FORMATION TREATMENT SYSTEM

A treatment system including a first tubular having at least one port therein. A valve member is disposed with the first tubular and operatively arranged to control fluid flow through the at least one port. A second tubular is disposed radially within the first tubular and terminates at an end opening into an interior passage of the first tubular for enabling a treatment media to be supplied through the second tubular into the first tubular, and through the at least one port when the at least one port is open. A seal assembly is disposed between the first and second tubulars for fluidly sealing an annulus formed between the first and second tubulars from the end of the second tubular. A tool is disposed with the second tubular for controlling operation of the valve member. 1. A treatment system , comprising:a first tubular having at least one port therein;a valve member disposed with the first tubular and operatively arranged to control fluid flow through the at least one port;a second tubular disposed radially within the first tubular and terminating at an end opening into an interior passage of the first tubular for enabling a treatment media to be supplied through the second tubular into the first tubular, and through the at least one port when the at least one port is open;a seal assembly disposed between the first and second tubulars for fluidly sealing an annulus formed between the first and second tubulars from the end of the second tubular; anda tool disposed with the second tubular for controlling operation of the valve member.2. The system of claim 1 , wherein the seal assembly and the end are both positioned up-hole of the at least one port.3. The system of claim 2 , wherein the tool is configured such that after engaging and opening the valve member claim 2 , movement of the tool via the second tubular in solely an up-hole direction enables the valve member to be moved to a closed position.4. The system of claim 2 , wherein the seal assembly is ...

System, Method And Apparatus For Controlling Fluid Flow Through Drill String

A device for limiting the flow of drilling fluid through a section of drill string includes a body with a hole in the periphery. Flow enters the device through one axial end, at least a portion of the flow exits through the other axial end. Some of the fluid flow can be diverted through the peripheral hole. A spring-biased axial piston has an approximately constant force throughout its range of travel. The piston moves axially in response to the changing fluid flow rate to ensure that a constant amount of flow exiting the axial end of the tool is achieved while diverting away excess flow through the side.

MULTI-ZONE CEMENTED FRACTURING SYSTEM

A method of cementing a liner string into a wellbore includes deploying a liner string into a wellbore; pumping cement slurry into a workstring; and pumping a dart through the workstring, thereby driving the cement slurry into the liner string. The dart engages a first wiper plug and releases the first wiper plug from the workstring. The dart and engaged first wiper plug drive the cement slurry through the liner string and into an annulus formed between the liner string and the wellbore. The dart and engaged first wiper plug land onto a first fracture valve. The dart releases a first seat into the first wiper plug. The dart engages a second wiper plug connected to the first fracture valve and releases the second wiper plug from the first fracture valve. 1. A method of cementing a liner string into a wellbore , comprising:deploying a liner string into the wellbore to a portion of the wellbore traversing a productive formation using a workstring, the liner string comprising a first fracture valve and the workstring comprising a first wiper plug;pumping cement slurry into the workstring; and the dart engages the first wiper plug and releases the first wiper plug from the workstring,', 'the dart and engaged first wiper plug drive the cement slurry through the liner string and into an annulus formed between the liner string and the wellbore,', 'the dart and engaged first wiper plug land onto the first fracture valve,', 'the dart releases a first seat into the first wiper plug, and', 'the dart engages a second wiper plug connected to the first fracture valve and releases the second wiper plug from the first fracture valve., 'pumping a dart through the workstring, thereby driving the cement slurry into the liner string, wherein2. The method of claim 1 , wherein:the liner string further comprises a second fracture valve;the dart and engaged second wiper plug further drive the cement slurry through the liner string and into an annulus formed between the liner string and the ...

Pressure Activated Down Hole Systems and Methods

Systems and methods for activating a down hole tool in a wellbore. A piston is moveable from a first position to a second position for activating the down hole tool. The piston includes a first side exposed to an activation chamber, and a second side operatively coupled to the down hole tool. A rupture member has a first side exposed to the activation chamber and a second side exposed to the interior of a base pipe. The rupture member is configured to rupture when a pressure differential between the activation chamber and the interior reaches a predetermined threshold value, at which point the rupture member allows fluid communication between the interior and the activation chamber to pressurize the activation chamber and move the piston, thereby activating the down hole tool.

APPARATUS FOR CREATING BIDIRECTIONAL ROTARY FORCE OR MOTION IN A DOWNHOLE DEVICE AND METHOD OF USING SAME

A method for fracturing a wellbore in a formation, including positioning one or more bidirectional rotary sleeves on tubular members into the wellbore; engaging a unidirectional rotary source in a first position with a first bidirectional rotary sleeve of the one or more bidirectional rotary sleeves; operating the unidirectional rotary source to rotate the first bidirectional rotary sleeve in a first rotational direction to open at least one port in the first bidirectional rotary sleeve for providing an open fluid pathway between the first bidirectional rotary sleeve and the formation; pumping fluid through the tubular members and through the opened port to fracture the formation; engaging the unidirectional rotary source in a second position with the first bidirectional rotary sleeve; and operating the unidirectional rotary source to rotate first bidirectional rotary sleeve in a second rotational direction to close the at least one port in the first bidirectional rotary sleeve. 1. A method for fracturing a wellbore in a formation , comprising:positioning one or more bidirectional rotary sleeves on tubular members into the wellbore;engaging a unidirectional rotary source in a first position with a first bidirectional rotary sleeve of the one or more bidirectional rotary sleeves;operating the unidirectional rotary source to rotate the first bidirectional rotary sleeve in a first rotational direction to open at least one port in the first bidirectional rotary sleeve for providing an open fluid pathway between the first bidirectional rotary sleeve and the formation;pumping fluid through the tubular members and through the opened port to fracture the formation;engaging the unidirectional rotary source in a second position with the first bidirectional rotary sleeve; andoperating the unidirectional rotary source to rotate the first bidirectional rotary sleeve in a second rotational direction to close the at least one port in the first bidirectional rotary sleeve.2. The ...

Systems and Methods for Reclosing a Sliding Side Door

Disclosed are systems and methods for mechanically reclosing a hydraulically actuated sliding side door of a sleeve assembly. One sleeve assembly includes a housing defining one or more flow ports, a sliding sleeve arranged within the housing and movable between a closed position and an open position and back to the closed position, wherein, when in the closed position, the outer sleeve occludes the one or more flow ports, and, when in the open position, the one or more flow ports are exposed. A piston is movably arranged within a piston bore defined in the housing, and a locking mechanism is arranged within the piston bore and configured to engage the piston with the sliding sleeve, thereby allowing the piston to move the sliding sleeve to the open position. 1. A sleeve assembly , comprising:a housing defining one or more flow ports that provide fluid communication between a wellbore annulus and an interior of the housing;a sliding sleeve arranged within the housing and movable between a closed position and an open position, wherein, when in the closed position, the outer sleeve occludes the one or more flow ports, and, when in the open position, the one or more flow ports are exposed;a piston movably arranged within a piston bore defined in the housing; anda locking mechanism disposed in the piston bore and configured to couple the piston to the sliding sleeve, thereby allowing the piston to move the sliding sleeve to the open position.2. The sleeve assembly of claim 1 , wherein the locking mechanism comprises:a locking pin;a biasing device configured to engage the locking pin;a mechanical fastener that secures the biasing device in engagement with the locking pin, wherein, as the piston translates in the piston bore, the locking mechanism translates concurrently therewith and the locking pin locates and engages a corresponding locking orifice defined in the sliding sleeve, thereby coupling the piston to the sliding sleeve.3. The sleeve assembly of claim 1 , ...

CASING VALVES SYSTEM FOR SELECTIVE WELL STIMULATION AND CONTROL

Casing valves for selective well stimulation and control. A well system includes at least one valve interconnected in a casing string operable via at least one line external to the casing string to selectively control fluid flow between an exterior and interior of the casing string, and the casing string, valve and line being cemented in a wellbore. A method of selectively stimulating a subterranean formation includes: positioning a casing string in a wellbore, the casing string including spaced apart valves operable via a line to selectively control fluid flow between an interior and exterior of the casing string; and for each of multiple intervals of the formation in sequence, stimulating the interval by opening a corresponding one of the valves, closing the remainder of the valves, and flowing a stimulation fluid from the casing string into the interval. 126-. (canceled)27. A valve for use in a tubular string in a subterranean well , the valve comprising:a sleeve having first and second opposite ends, the sleeve being displaceable between open and closed positions to thereby selectively permit and prevent flow through a sidewall of a housing assembly; andfirst and second pistons at the respective first and second ends of the sleeve, pressure differentials applied to the first and second pistons being operative to displace the sleeve between its open and closed positions.28. The valve of claim 27 , further comprising at least one opening extending through a sidewall of the sleeve claim 27 , and wherein the opening is isolated from an exterior of the housing assembly and an internal flow passage of the housing assembly when the sleeve is in its closed position.29. The valve of claim 27 , further comprising at least one opening extending through a sidewall of the sleeve claim 27 , and wherein the opening is positioned longitudinally between the first and second pistons.30. The valve of claim 27 , wherein the first and second pistons are exposed to pressure in ...

REMOTE AND MANUAL ACTUATED WELL TOOL

A well tool having an actuator sleeve in a housing. The actuator sleeve has an internal shifting tool engaging profile. The tool has an actuator in the housing that is responsive to a remote signal to change from an unactuated state to an actuated state and shift the actuator sleeve from a first position to a second position. A collet in the housing is supported to couple the actuator sleeve to the actuator while the actuator changes from the unactuated state to the actuated state and is unsupported to allow the actuator sleeve to move relative to the actuator when the actuator is in the actuated state. 1. A well tool , comprising:a housing;an actuator sleeve in the housing, the actuator sleeve having an internal shifting tool engaging profile;an actuator in the housing, the actuator responsive to a remote signal to change from an unactuated state to an actuated state and shift the actuator sleeve from a first position to a second position; anda collet in the housing supported to couple the actuator sleeve to the actuator while the actuator changes from the unactuated state to the actuated state and unsupported to allow the actuator sleeve to move relative to the actuator when the actuator is in the actuated state, the collet supported engaged in an axially elongate profile of the actuator sleeve while the actuator changes from the unactuated state to the actuated state, and an end of the profile abuts the collet and transfer loads from the actuator, through the collet, to the actuator sleeve as the actuator changes from the unactuated state to the actuated state.2. The well tool of claim 1 , further comprising a valve closure and where the actuator sleeve is coupled to the valve closure and operates the valve closure between an open and closed state when the actuator sleeve is moved between the first position and the second position.3. The well tool of claim 1 , where claim 1 , with the actuator in the unactuated state claim 1 , the collet is supported to couple ...

Linearly indexing well bore simulation valve

Stimulation valves are provided that have a valve housing, an indexed driver, a reciprocating shifter, an actuation seat, and an isolation seat. The indexed driver is linearly actuated from an initial position through intermediate positions to a terminal position. In the driver initial and intermediate positions, the valve body shuts off fluid communication through ports provided in the housing. In the driver terminal position the valve body allows fluid communication through the ports. The reciprocating shifter indexes the indexed driver from its initial position through its intermediate positions to its terminal position. The actuation seat receives a ball for actuation of the shifter and releases the ball after actuation of the shifter. The isolation seat allows passage of the ball when the indexed driver is in its initial and intermediate positions and receives the ball when the indexed driver is in its terminal position.

Isolation valves

A valve assembly that can be deployed in a subterranean well that includes a valve adapted to selectively isolate a region of the subterranean well, and a separating apparatus. The separating apparatus may further include at least one member being formed from a functional material and at least two sleeves connected by the at least one member.

BALL VALVE

A ball valve stopper comprising a spherical contoured body comprising a substantially inelastic first material and having a flow port. A closed face of the spherical contoured body is orthogonal with respect to the flow port and includes a spherical fluid seal area. A rotation support member is aligned orthogonally to the flow port and the fluid seal area. A material discontinuity volume is disposed behind the closed face of the spherical contoured body. 1. A ball valve stopper comprising:a spherical contoured body comprising a substantially inelastic first material and having a flow port;a closed face of the spherical contoured body that is orthogonal with respect to the flow port and includes a fluid seal area;a rotation support member aligned orthogonally to the flow port and the fluid seal area; anda material discontinuity volume disposed behind the closed face of the spherical contoured body.2. The ball valve stopper of claim 1 , wherein the material discontinuity volume is at least partially disposed behind the fluid seal area.3. The ball valve stopper of claim 1 , wherein the material discontinuity volume includes a channel in the spherical contoured body that either comprises a void or contains a second material having a different modulus of elasticity than a modulus of elasticity of the first material.4. The ball valve stopper of claim 3 , wherein the first material is metallic.5. The ball valve stopper of claim 4 , wherein the second material has a lower modulus of elasticity than a modulus of elasticity of the first material.6. The ball valve stopper of claim 1 , wherein the material discontinuity volume is disposed between at least a portion of the fluid seal area and the rotation support member.7. The ball valve stopper of claim 1 , wherein the material discontinuity volume comprises a channel and wherein a cross-section area of the channel varies based on the proximity of the cross-section area to a centerline axis of the flow port.8. The ball valve ...

Multi-Function Surge Reduction Apparatus

A multi-function diverter tool is disclosed that allows positive-indication opening and closing of the tool in a downhole environment. The tool includes a first sleeve adapted to open outlet ports in the exterior surface of the tool body. The tool includes a second sleeve which is movable with respect to the first sleeve and is adapted to close the outlet ports when moved from an initial position to a second position. 1) A method for diverting fluid flow from the inside of a deployment string to the annular space above a casing string comprising: i) a tool body including an interior and exterior for use in downhole operations, the diverter tool having an initial position preventing fluid communication from the interior of the tool to the exterior of the tool, a second position permitting fluid communication from the interior of the tool to the exterior of the tool, and a third position again preventing fluid communication from the interior of the tool to the exterior of the tool, further including one or more ports extending radially outwardly of the tool body;', 'ii) a lower slider assembly axially movable within said tool body, wherein said lower slider assembly is selectively movable between said initial position and an open position, and wherein fluid communication between said interior and exterior of said tool body is precluded in said initial position and possible in said open position; and', 'iii) an upper slider assembly axially movable within said tool body, wherein said upper slider assembly is selectively movable and wherein fluid communication between said interior and exterior of said tool body is possible in said second position and precluded in said third position, said upper slider assembly remaining stationary with respect to said lower slider assembly when said lower slider assembly is moved to the open position, means for selectively moving said lower slide assembly from said closed position to said open position, and means for selectively moving ...

A fluid flow activated rotational cleaning tool

A system to clean well casing in a downhole well operation. The system comprises an inner collar having flow ports and an out collar having jet ports in fluid communication with the flow ports. The inner collar couples with a section of a tool string and the outer collar rotates about the inner collar in response to fluid flow through the tool string. The inner collar can include a sleeve. The sleeve can be moved from a first position to a second position causing the jet ports to be in fluid communication with the flow ports. The inner collar remains relatively stationary with respect to the rotation of the outer collar. In addition, the jet ports are angled in a way that a portion of force generated by the fluid flow through the jet ports induce rotation of the outer collar in the opposite direction of the fluid flow.

FLOW CONTROL DEVICE FOR A WELL

An apparatus that is usable with a well includes a housing and a body. The housing includes an inlet and an outlet, and a fluid flow is communicated between the inlet and outlet. The body disposed inside the housing to form a fluid restriction for the fluid flow. The body includes an opening therethrough to divert a first portion of the fluid flow into a first fluid flow path; and a first surface to at least partially define the first fluid flow path. The body is adapted to move to control fluid communication through the first flow path based at least in part on at least one fluid property of the flow 1. An apparatus usable with a well , comprising:a housing comprising an inlet and an outlet, wherein a fluid flow is communicated between the inlet and outlet; and an opening therethrough to divert a first portion of the fluid flow into a first fluid flow path; and,', 'a first surface to at least partially define the first fluid flow path; and, 'a body disposed inside the housing to form a fluid restriction for the fluid flow, the body comprisingwherein the body is adapted to move to control fluid communication through the first flow path based at least in part on at least one fluid property of the flow.2. The apparatus of claim 1 , wherein the first surface of the body faces away from the inlet.3. The apparatus of claim 1 , wherein the fluid flow is communicated radially outward from the opening to the outlet.4. The apparatus of claim 1 , wherein the outlet comprises a plurality of openings in the housing.5. The apparatus of claim 1 , wherein:the first surface of the body faces away from the inlet; andthe first fluid flow path extends between the first surface and the housing.6. The apparatus of claim 1 , wherein the body further comprises:a hub to circumscribe the opening and receive the first diverted portion of the fluid flow; anda first flange to extend radially away from hub, the first flange comprising the first surface and the first surface facing the housing ...

DOWNHOLE ACTUATION BALL, METHODS AND APPARATUS

An actuation ball for a downhole tool, the actuation ball includes an outer annular body encircling a bore; and a core releasably installed in the bore, such that the core can be removed to permit back flow through the bore. 1. An actuation ball for a downhole tool , the actuation ball comprising:a core;an outer body through which fluid can flow if the core is removed; anda mechanical connection between the core and the outer body, the mechanical connection configured to permit separation of the core from the outer body.2. The actuation ball of wherein the mechanical connection is configured to hold the core in the body for actuation of the downhole tool and to permit separation of the core from the outer body after actuation of the downhole tool.3. The actuation ball of wherein the actuation ball has a leading end and a trailing end and the core has a forward end exposed on the outer surface of the leading end and the core has a piston face end exposed on the trailing end and the mechanical connection is configured to hold the core in the outer body against dislodgement towards the leading end while permitting separation of the core from the outer body by movement of the core towards the trailing end.4. The actuation ball of wherein the mechanical connection is configured to permit separation of the core from the outer body in response to a force applied against the forward end that is greater than a second force applied against the piston face end.5. The actuation ball of wherein mechanical connection is a snap connection.6. The actuation ball of wherein the mechanical connection is a wedge lock connection.7. The actuation ball of wherein the outer body has a bore extending therethrough and the bore has a tapering inner diameter that tapers from a trailing end toward a leading end; the core has tapering side walls that fit within bore and define an outer diameter that substantially matches the tapering inner diameter; and a seal formed between the frustoconical ...

PRESSURE EQUALIZATION FOR DUAL SEAT BALL VALVE

A ball valve comprising a housing comprising a fluid passage, a first seat surface, a second seat surface, and a ball rotatably movable within the housing between an open position allowing flow through the fluid passage of the housing and a closed position preventing flow through the fluid passage of the housing, wherein the ball contacts the first seat surface and the second seat surface to form one or more seals within the ball valve, wherein the ball comprises a fluid passage and a fluid path, wherein the fluid path fluidly connects a space between the first seat surface and the second seat surface with the fluid passage of the housing, with the fluid passage of the ball, or both, when the ball is in the open position. 1. A ball valve comprising:a housing comprising a fluid passage;a first seat surface;a second seat surface; anda ball rotatably movable within the housing between an open position allowing flow through the fluid passage of the housing and a closed position preventing flow through the fluid passage of the housing, wherein the ball contacts the first seat surface and the second seat surface to form one or more seals within the ball valve, wherein the ball comprises a fluid passage and a fluid path, wherein the fluid path fluidly connects a space between the first seat surface and the second seat surface with the fluid passage of the housing, with the fluid passage of the ball, or both, when the ball is in the open position.2. The ball valve of claim 1 , wherein the fluid path comprises a hole formed in the ball.3. The ball valve of claim 1 , wherein the fluid path comprises a groove formed on a surface of the ball.4. The ball valve of claim 1 , further comprising:a seat member associated with the first seat surface and the second seat surface, wherein the first seat surface and the second seat surface are fixed relative to each other.5. The ball valve of claim 4 , further comprising a biasing device arranged to bias the first seat surface claim 4 , ...

TUBING PRESSURE OPERATED DOWNHOLE FLUID FLOW CONTROL SYSTEM

A downhole flow control system utilizes a tubing pressure operated valve to selectively open and close fluid flow across the system. The tubing pressure operated valve includes a piston responsive to tubing pressure, and a valve element responsive to piston movement. The valve element can be moved rotationally, longitudinally, or both, in response to the piston movement. The valve is movable between a closed and at least one open position. The piston and valve elements can be releasably attachable, such as by a one-way ratchet. The valve element can be a rotating valve operable by a J-slot mechanism to rotate to multiple positions in response to movement of the piston element. 1. A downhole fluid flow control system operable to be positioned in a wellbore extending through a subterranean formation and operable to control fluid flow between the wellbore and an internal passageway of a tubular , the system comprising:a tubing-pressure operated device positioned along a flow path between the interior passageway of the tubular and the exterior of the tubular;a piston element, biased towards a first position, slidably disposed in a piston annulus, the piston annulus having a pressure-transmitting port to the interior passageway of the tubular, the piston element movable to a second position responsive to a tubing-pressure change transmitted through the pressure-transmitting port; anda valve element attached to the piston element and movable in response to movement of the piston element between a closed position wherein fluid flow is blocked across the flow path and an open position wherein flow is allowed across the flow path.2. The system of claim 1 , wherein the flow path passes through a bypass port defined in the piston element.3. The system of claim 2 , wherein the piston element further includes a check valve positioned thereon operable to control fluid flow through the bypass port.4. The system of claim 1 , wherein the flow path passes through the piston annulus.5 ...

MULTI-ZONE FRACTURING WITH FULL WELLBORE ACCESS

A system and method for fracturing multiple zones along a length of a wellbore during a single run are provided. A single magnetic shifter device may be lowered on coiled tubing to shift open multiple sleeve assemblies set along the wellbore to expose different fracture zones for desired fracturing treatments. The sleeve assemblies may each include a magnetic sensing system designed to detect a magnetic field output from the shifter device. The magnetic sensing system may output a control signal to an electro-hydraulic lock to collapse a baffle component of the sleeve assembly. Once the baffle is collapsed, an isolation component of the shifter device may engage the collapsed baffle to form a plug through the wellbore. Pressure applied from the surface may push the baffle and a sliding sleeve of the sleeve assembly downward, thereby exposing fracturing ports through the casing of the wellbore. 1. A sleeve assembly for use in a wellbore , the sleeve assembly comprising:a magnetic sensor system for detecting a magnetic field output from a magnetic shifting device moving through the sleeve assembly;a collapsible baffle that is moveable from a radially open position to a radially collapsed position in response to the magnetic sensing system detecting the magnetic field from the magnetic shifting device, wherein the radially collapsed position is sized for receiving an isolation component moving through the sleeve assembly; anda sliding sleeve disposed adjacent the collapsible baffle and moveable to expose ports for providing access to a formation from inside the wellbore, in response to force from the isolation component engaged with the collapsible baffle.2. The sleeve assembly of claim 1 , further comprising:an oil chamber piston sleeve disposed partially in a chamber, wherein the oil chamber piston sleeve is moveable through the chamber in response to a release of hydraulic fluid into the chamber; andan electro-hydraulic lock for releasing hydraulic fluid into the ...

Downhole Shifting Tool

A downhole tool includes a deactivation member, a latching member, a release member, and a biasing member. The deactivation member includes an outer protrusion. The latching member is positioned radially-outward from the deactivation member. The latching member includes an inner protrusion and an outer protrusion. The release member includes a sleeve extending axially toward the outer protrusion of the latching member. The biasing member exerts an axial force on the latching member. 1. A downhole tool , comprising:a deactivation member comprising an outer protrusion;a latching member positioned radially-outward from the deactivation member, wherein the latching member comprises an inner protrusion and an outer protrusion;a release member comprising a sleeve extending axially toward the outer protrusion of the latching member; anda biasing member configured to exert an axial force on the latching member.2. The downhole tool of claim 1 , wherein the latching member is configured to move from a first position to a second position with respect to the deactivation member claim 1 , wherein the inner protrusion of the latching member is on a first side of the outer protrusion of the deactivation member when the latching member is in the first position claim 1 , and wherein the inner protrusion of the latching member is on a second side of the outer protrusion of the deactivation member when the latching member is in the second position.3. The downhole tool of claim 2 , wherein the axial force exerted on the latching member is greater when the latching member is in the second position than when the latching member is in the first position.4. The downhole tool of claim 3 , wherein the axial force pushes the latching member toward the first position.5. The downhole tool of claim 2 , wherein the outer protrusion of the deactivation member comprises a first face that faces a first face of the inner protrusion of the latching member when the latching member is in the first ...

REVERSE-CIRCULATION DRILLING ASSEMBLIES AND METHODS OF USING SAME

A reverse-circulation drilling assembly having an overshot subassembly and a head subassembly. In the event retrieval of the drilling assembly by reverse-circulation fails, the drilling assembly can be retrieved using a secondary overshot. 1. A reverse-circulation drilling assembly having a longitudinal axis and comprising:an overshot subassembly having a proximal portion, a distal portion, and a check valve assembly positioned axially between the proximal and distal portions, wherein the distal portion comprises a latch assembly; anda head subassembly having a latch assembly, a valve assembly, and a proximal portion that defines a receptacle configured to receive a portion of the distal portion of the overshot subassembly, wherein the proximal portion of the head subassembly further comprises a latch retracting case that is configured for axial movement relative to the longitudinal axis to effect movement of the latch assembly about and between a retracted position and a deployed position in which the latch assembly engages an inner surface of a drill string, wherein the latch retracting case is coupled to the valve assembly and configured to effect movement of the valve assembly about and between a closed position and an open position that permits fluid flow through the head subassembly,wherein the latch assembly of the overshot subassembly is configured for movement from a retracted position to a deployed position to engage the proximal portion of the head subassembly when the distal portion of the overshot subassembly is received within the receptacle, andwherein the check valve assembly of the overshot subassembly is biased to the closed position and configured to move from the closed position to the open position upon landing of the drilling assembly within a borehole.2. The reverse-circulation drilling assembly of claim 1 , wherein the latch retracting case of the head subassembly is configured to effect movement of the check valve assembly to the open ...

APPARATUS, SYSTEMS, AND METHODS FOR FRACTURING A GEOLOGICAL FORMATION

The present disclosure relates, according to some embodiments, to apparatus, systems, and methods of fracturing a geological structure including the application of kinetic energy (e.g., from high velocity frack fluid) to a subterranean structure. In some embodiments, the present disclosure relates to apparatus, systems, and methods for delivery of high velocity fluid to a well using a down hole valve and/or throttling system. The present disclosure relates to apparatus, systems, and methods of generating pressure using accumulators (e.g., high pressure accumulators) at the surface of a well. 119-. (canceled)20. A method of kinetically fracking a subterranean structure , the method comprising: (i) providing a fracking fluid at a pressure of about 8,000 psi to about 15,000 psi, wherein the fracking fluid is substantially free of proppant;', '(ii) adding at least one proppant to the fracking fluid; and', '(iii) injecting the fracking fluid with proppant into the interior channel;, '(a) providing a fracking string inside a perforated wellbore liner having an interior cavity, the fracking string having an interior channel and spaced-apart apertures connecting the interior string channel and the liner cavity, comprising the steps of(b) accelerating the fracking fluid in the interior channel in a downhole direction to a velocity of from about 10 to about 150 feet per second; and(c) abruptly decelerating fracking fluid flow.21. A method of kinetically fracking a subterranean structure according to claim 20 , wherein the fracking fluid is provided in an overburdened pressure zone at a pressure of about 15 claim 20 ,000 psi.22. A method of kinetically fracking a subterranean structure according to claim 20 , further comprising repeating steps (b) and (c).23. A method of kinetically fracking a subterranean structure according to claim 20 , wherein abruptly decelerating fracking fluid flow further comprises closing the string apertures claim 20 , sealing the interior liner ...

Non-electronic air chamber pressure sensor

An apparatus for use in a wellbore having a housing having at least one chamber capable of receiving a fluid, a sealed annular volume, and a non-electronic pressure sensor disposed in the sealed annular volume. The non-electronic sensor includes a sealed, compressible container. Positioned within the sealed, compressible container are first and second magnets that are separated by a first distance when a fluid within the sealed annular volume is at a first pressure. When the fluid in the sealed annular volume is at a second pressure, the first and second magnets are separated by a second distance.

SUBSURFACE SAFETY VALVE WITH ROTATING DISK

A subsurface safety valve assembly has a valve body with an axially oriented valve bore and a valve cavity that intersects the valve bore. A disk valve member is positioned within the valve cavity and has a disk bore. A piston member is moveable between a contracted position and an extended position, such that in the contracted position the disk valve member is in a valve closed position with the disk bore offset from the valve bore, and in the extended position the disk valve member is in a valve open position with the disk bore axially aligned with the valve bore. An uphole seal member circumscribes the valve bore, forming a seal between the uphole side of the disk valve member and the valve body. A downhole seal member circumscribes the valve bore, forming a seal between the downhole side of the disk valve member and the valve body. 1. A subsurface safety valve assembly for a subterranean well , the assembly having: an axially oriented valve bore extending from a downhole end of the valve body to an uphole end of the valve body; and', 'a valve cavity, the valve cavity being an open space intersecting the valve bore within the valve body;, 'a valve body, the valve body havinga disk valve member positioned within the valve cavity, the disk valve member being disk shaped and having a disk bore extending from a downhole side to an uphole side of the disk valve member;a piston member having a base end rotationally secured to the valve body and an extendable end rotationally secured to the disk valve member, where the piston member is moveable between a contracted position and an extended position, such that in the contracted position the disk valve member is oriented in a valve closed position with the disk bore offset from the valve bore, and in the extended position the disk valve member is oriented in a valve open position with the disk bore axially aligned with the valve bore;an uphole seal member circumscribing the valve bore at a downhole facing surface of the ...

APPARATUS, SYSTEMS AND METHODS FOR COMPLETION OPERATIONS

A bottomhole assembly (BHA) having a shifting tool and housing for shifting an uphole-to-open sleeve of a sleeve of a shorter length downhole sleeve assembly to an open position, and optionally to a closed position. Sleeve-engaging elements of the BHA are coordinated to direct the sleeve-engaging elements into a tool-engaging profile of the sleeve, excluding other annular variations in the casing string. The BHA has an improved dual J-Mechanism situated between the shifting tool and housing to permit new additional shifting options which results in fewer overall shifting cycles of the BHA when used with the shift uphole-to-open, shorter-length sleeve assembly. The shortened sleeve assembly is incorporated into a casing string and is relatively short in length when compared with conventional sleeve assemblies. 1. A shifting tool for sleeve valves along a wellbore , each sleeve valve having a sleeve housing having a bore fit with an axially shiftable sleeve within , the sleeve having an annular sleeve profile formed therealong , the shifting tool comprising:a first housing portion having a first shifting mechanism;a second housing portion having a second shifting mechanism, the second housing portion telescopically connected to the first housing portion and adapted for axially telescoping between a collapsed position and an extended position;a drag block connected to the second housing portion and adapted for resisting axial movement the second housing portion in the wellbore;a mandrel having a first shifting member adapted to cooperate with the first shifting mechanism, a second shifting member adapted to selectably cooperate with the second shifting mechanism, and a retaining member;one or more sleeve engagement members supported on one or more pivotable arms, the one or more arms supported by the first housing portion, each of the one or more pivotable arms being radially actuable by the retaining member between at least a radially outward position and a radially ...

SWITCHES FOR CONTROLLING DOWNHOLE TOOLS

A downhole tool for time delaying a downhole activity. The downhole tool includes a housing having a bore; a moving sleeve configured to move relative to the housing; an electronic valve configured to open and close when receiving an electrical signal; and a switch that is responsive to a fluid pressure inside the bore. The downhole tool electronically counts down a set time. 1. A downhole tool for time delaying a downhole activity , the downhole tool comprising:a housing having a bore;a moving sleeve configured to move relative to the housing;an electronic valve configured to open and close when receiving an electrical signal; anda switch that is responsive to a fluid pressure inside the bore,wherein the downhole tool electronically counts down a set time.2. The tool of claim 1 , wherein the switch is configured to close an electrical circuit to energize an electronic block.3. The tool of claim 2 , wherein the switch is electrically wired to the electronic block.4. The tool of claim 3 , wherein the electronic valve is electrically wired to the electronic block.5. The tool of claim 4 , wherein the electronic block includes a timer that counts down the set time.6. The tool of claim 5 , wherein the timer counts down the set time after being energized and sends a command to a dump valve of the electronic valve to open.7. The tool of claim 6 , wherein the electronic valve claim 6 , when opened claim 6 , allows a fluid from the bore to reach the moving sleeve and move the moving sleeve.8. The tool of claim 5 , wherein the electronic block includes a power source.9. The tool of claim 1 , wherein the switch includes a biasing mechanism that resets the switch.10. The tool of claim 1 , wherein the switch includes a first pressure responsive switch and a second claim 1 , resettable claim 1 , pressure responsive switch.11. The tool of claim 1 , wherein the switch includes a first pressure responsive switch and a second switch that includes a pressure transducer.12. The tool of ...

MULTI-ZONE HYDRAULIC STIMULATION SYSTEM

A system includes a string disposed in a wellbore, a first valve coupled to the string, the first valve including a sleeve having an engagement profile with a first coded sequence, a second valve coupled to the string, the second valve including a sleeve having an engagement profile with a second coded sequence that differs from the first coded sequence of the first valve, and a first dart flow transportable through the string, the first dart including a collet finger having a first coded sequence configured to restrict the collet finger from matingly engaging the engagement profile of the first valve while permitting the collet finger to engage the engagement profile of the second valve, wherein the first dart actuates the sleeve of the second valve between first and second positions in response to the collet finger of the first dart matingly engaging the engagement profile of the second valve. 1. A system for stimulating an earthen formation , comprising:a tubular string disposed in a wellbore extending through the formation;a first valve coupled to the tubular string, the first valve comprising a sliding sleeve having an engagement profile with a first coded sequence;a second valve coupled to the tubular string, the second valve comprising a sliding sleeve having an engagement profile with a second coded sequence that differs from the first coded sequence of the first valve; anda first dart flow transportable through the tubular string, the first dart comprising a collet finger having a first coded sequence configured to restrict the collet finger from matingly engaging the engagement profile of the first valve while permitting the collet finger to matingly engage the engagement profile of the second valve;wherein the first dart is configured to actuate the sliding sleeve of the second valve from a first position to a second position in response to the collet finger of the first dart matingly engaging the engagement profile of the second valve.2. The system of ...

RELEASE TOOL FOR DOWNHOLE OPERATIONS

A downhole tool for connecting and releasing portions of a tool string includes a housing; an electronics assembly; an activation mechanism; a valve assembly and a set of retainer dogs to connect and release a neck of another tool. The downhole tool may also include one or more measurement sensors for measuring a parameter and transferring one or more measured parameter values to the surface of the well. 1. An apparatus for connecting and releasing a downhole tool located within a wellbore comprising:a housing having an axial bore;an electronics assembly configured to communicate with the surface of the wellbore;an activation mechanism configured to receive an electrical current from the electronics assembly;a valve assembly in operative communication with the activation mechanism and having a first piston configured to open a port in the housing to wellbore fluid;a second piston slidably engaged with the housing and held in an initial downward state by a spring;plural retainer dogs each having an engagement recess disposed on an inner radial surface thereon configured for clamping a neck of a tool; andwherein said second piston further comprises a cavity configured to retain said plural retainer dogs in a clamped state until said second piston is acted upon by the wellbore fluid.2. The apparatus of wherein the housing is comprised of an upper section and a lower section connected by a main sub.3. The apparatus of claim 2 , wherein the activation mechanism is located within the main sub.4. The apparatus of claim 2 , wherein the valve assembly is located within the main sub.5. The apparatus of claim 1 , wherein the valve assembly further comprises a burst disk.6. The apparatus of claim 1 , wherein valve assembly is further configured to activate a switch to communicate a state of the valve to the electronics assembly.7. An apparatus for connecting and releasing a downhole tool located within a wellbore comprising:a housing having an axial bore;a burst disk located ...

PROVISION OF INTERNAL LINES IN A WELL TOOL

A well tool can include a closure member having open and closed positions, a seat having a flow passage blocked by the closure member in the closed position, and a line extending through the seat. A communication method can include positioning a conduit in an interior of a well tool, and conducting a signal via the conduit between annular structures surrounding a longitudinal flow passage of the well tool. A well system can include a well tool connected in a tubular string, a flow passage of the tubular string extending through the well tool, the well tool including a closure member having open and closed positions, in which the closure member respectively permits and blocks flow through the flow passage, an annular cavity surrounding the flow passage, and a line, the closure member and the line being positioned in the annular cavity in the open position. 1. A well tool , comprising:a closure member which is displaceable between open and closed positions;a seat having a flow passage extending therethrough, the flow passage being blocked by the closure member in the closed position; andat least one line extending through the seat.2. The well tool of claim 1 , in which the line extends between the seat and a housing of the well tool claim 1 , the closure member being positioned within the housing.3. The well tool of claim 2 , in which the line and the seat are positioned within the housing.4. The well tool of claim 1 , in which the closure member rotates between the open and closed positions.5. The well tool of claim 4 , in which the closure member comprises a flapper.6. The well tool of claim 1 , in which the line extends from the seat into an annular cavity that outwardly surrounds the flow passage in the open position.7. The well tool of claim 1 , in which the at least one line comprises multiple lines claim 1 , and in which the closure member is positioned between at least two of the lines in the closed position.8. A method of communicating through a well tool in ...

Packoff seals and processes for using same

Packoff seals and processes for using same. In some examples, the packoff seal can include a first end cap and a second end cap, a first insert and a second insert, a first deformable element disposed between the first end cap and the first insert, a second deformable element disposed between the second insert and the second end cap, and a third deformable element disposed between the first insert and the second insert. The first end cap, the first deformable element, the first insert, the third deformable element, the second insert, the second deformable element, and the second end cap together can form a body having a bore extending therethrough. The first deformable element, the second deformable element, and the third deformable element can have a compressive strength that is less than a compressive strength of the first and second inserts.

METHODS, SYSTEMS, AND DEVICES FOR SEALING STAGE TOOL LEAKS

Methods, systems, and devices for sealing stage tool leaks are disclosed. In one aspect a stage tool for wellbore cementing comprises an external stage tool body and a sliding sleeve within the external stage tool body configured to regulate cement flow through the stage tool. At least a portion of the sliding sleeve comprises a meltable alloy configured to seal a leak. The meltable alloy is configured to be melted by a heating source, flow into the leak, and resolidify as the melted alloy cools, thereby sealing the leak. 1. A stage tool for wellbore cementing , comprising:an external stage tool body; anda sliding sleeve within the external stage tool body configured to regulate flow through the stage tool;wherein the sliding sleeve comprises a meltable alloy configured to seal a leak; andwherein the meltable alloy is configured to be melted by a heating source, flow into the leak, and resolidify as the melted alloy cools, thereby sealing the leak.2. The stage tool of claim 1 , wherein the meltable alloy is a bismuth-containing alloy.3. The stage tool of claim 2 , wherein the bismuth-containing alloy comprises germanium.4. The stage tool of claim 3 , wherein the bismuth-containing alloy further comprises copper claim 3 , lead claim 3 , tin claim 3 , cadmium claim 3 , indium claim 3 , antimony claim 3 , gallium claim 3 , antimony claim 3 , or silver.5. The stage tool of claim 1 , wherein the meltable alloy is a solder.6. The stage tool of claim 1 , wherein the meltable alloy is a eutectic alloy.7. The stage tool of claim 1 , wherein the heating source is a thermite heater.8. The stage tool of claim 1 , wherein the heating source comprises a damping agent.9. The stage tool of claim 1 , wherein the external stage tool body comprises a body cement port; and the sliding sleeve comprises a sleeve cement port; and wherein the sliding sleeve is configured to have a closed configuration wherein the body cement port and the sleeve cement port are not aligned claim 1 , and an ...

Mechanically Adjustable Inflow Control Device

An adjustable inflow control device features a mechanically rotatable sleeve that advances or retreats axially when rotated in opposed directions to cover or uncover a labyrinth flow path from an inlet to an outlet. When used for inflow the outlet is into a tubular string to a surface location. The more the sleeve is retracted away from the labyrinth path the less resistance to flow is offered and vice versa. Another way to mechanically alter the flow resistance is to have an outer housing with a spiral groove and an axially movable inner mandrel with another spiral groove. The mandrel can be axially advanced with rotation when connected with a thread. Advancing the mandrel so that there is more overlap between the spiral patterns increases resistance to a give flow rate and vice versa. A gap between the mandrel and housing allows the mandrel to rotate and translate. 1. An adjustable flow control device between a tubular string and a surrounding annular space , comprising:a housing having a first port to the annular space and a second spaced apart port to the tubular string;a labyrinth flow path between said first and second ports;a rotatably mounted member in said housing, whereupon rotation of said member changes resistance to a predetermined flow between said ports.2. The device of claim 1 , wherein:said member translates while rotating.3. The device of claim 1 , wherein:said member comprises a sleeve.4. The device of claim 1 , wherein:said member is engaged to said housing for said rotation with a driving thread form.5. The device of claim 1 , wherein:said member is engaged to said housing with a j-slot mechanism having slots of different lengths.6. The device of claim 1 , wherein:movement of said member engages a seal between said member and said housing to selectively close flow between said ports.7. The device of claim 1 , wherein:axial movement of said member varies the length of said labyrinth passage between said ports.8. The device of claim 1 , wherein: ...

Apparatus and method for treating a reservoir using re-closeable sleeves, and actuating the sleeves with bi-directional slips

There is provided a bottomhole assembly for deployment within a wellbore string disposed within a wellbore, the wellbore string including a port and a flow control member, wherein the flow control member is displaceable relative to the port for effecting opening and closing of the port, comprising: a first mandrel; a second mandrel including a locator for becoming disposed within a locate profile of the wellbore string such that resistance to displacement of the second mandrel, relative to the locate profile, is effected, and such that locating of the bottomhole assembly within the wellbore string is thereby effected; a shifting tool including a first gripper surface and a second gripper surface; a first shifting tool actuator, translatable with the first mandrel; and a second shifting tool actuator, translatable with the first mandrel; wherein: the shifting tool is displaceable in response to urging by the first shifting tool actuator that is effected by downhole displacement of the first mandrel relative to the second mandrel, such that the first gripper surface is displaced outwardly to a first gripper surface gripping position for becoming disposed in gripping engagement with the flow control member; the shifting tool is displaceable in response to urging by the second shifting tool actuator that is effected by uphole displacement of the first mandrel relative to the second mandrel, such that the second gripper surface is displaced outwardly to a second gripper surface gripping position for becoming disposed in gripping engagement with the flow control member; and the second mandrel includes a retainer for limiting displacement of the shifting tool, relative to second mandrel, in both of downhole and uphole directions.

Pass-through tapered nose tool

A tapered nose tool having a closed position and an open position, a degradable nose component, a releasable nose component, that is configured to rotate due to fluid passing therethrough and configured for retrievability of a portion of the bull nose tool.

PRESSURE RELEAVING MEANS

A packer and method and apparatus for releasing pressure within a pressurized annulus around the packer. The apparatus comprises a central tubular member having a central bore therethrough extending between first and second ends, an outer plug slidably locatable within a first end of the tubular member and having a central bore therethrough and an inner plug slidably locatable within the central bore of the outer plug. The method comprises longitudinally retracting the inner plug from sealed engagement within the central bore of the outer plug member so as to permit fluid to flow therethrough and engaging the outer plug with a retraction body operably connected to the inner plug extending adapted to engage the inner plug after a predetermined length of travel so as to draw the outer plug out of the central tubular member thereafter. 1. An apparatus for releasing pressure within a pressurized annulus around a tool string of a well bore comprising:a central tubular member having a central bore therethrough extending between first and second ends;an outer plug slidably locatable within a first end of the tubular member and having a central bore therethrough; andan inner plug slidably locatable within the central bore of said outer plug.2. The apparatus of further comprising a first end cap operably connected to the second plug such that axial movement of the end cap retracts said second plug from said central bore of said fist plug.3. The apparatus of further comprising a retraction member operably connected to and movable with said inner plug claim 2 , said retracting member being adapted to engage said inner plug after a predetermined length of travel so as to draw said outer plug out of the central tubular member thereafter.4. The apparatus of wherein said retraction member comprises a retraction sleeve surrounding said inner plug along a parallel axis therewith.5. The apparatus of wherein said retraction sleeve includes fluid flow passages therethrough6. The ...

COMMUNICATION AND LOCK OPEN SAFETY VALVE SYSTEM AND METHOD

A downhole system includes a safety valve system. The safety valve system includes a tubular housing having a hydraulic control chamber, and a lock-open communication sleeve within the tubular housing. The sleeve is longitudinally movable with respect to the tubular housing. The sleeve has a downhole end portion configured to abut and enact downhole movement of a flow tube. The sleeve further has a radial communication sort alignable with the hydraulic control chamber. A method of communicating and locking open the safety valve includes using the sleeve. 1. A downhole system including a safety valve system , the safety valve system comprising:a tubular housing having a hydraulic control chamber; and,a lock-open communication sleeve within the tubular housing, the sleeve longitudinally movable with respect to the tubular housing, the sleeve having a downhole end portion configured to abut and enact downhole movement of a flow tube, the sleeve further having a radial communication port alignable with the hydraulic control chamber.2. The downhole system of claim 1 , wherein the sleeve is rotatable within the tubular housing.3. The downhole system of claim 2 , wherein the sleeve includes an external thread claim 2 , and the tubular housing includes an internal thread corresponding with the external thread of the sleeve.4. The downhole system of claim 3 , wherein the external thread is a left-hand thread.5. The downhole system of claim 1 , wherein rotation of the sleeve within the tubular housing converts to the downhole movement of the sleeve.6. The downhole system of claim 1 , further comprising the flow tube longitudinally movable within the housing and a flapper movable from a closed position at least substantially blocking a longitudinal flow path through the tubular housing claim 1 , to an open position claim 1 , wherein the downhole movement of the flow tube moves the flapper to the open position.7. The downhole system of claim 6 , wherein the radial communication ...

MULTISTAGE HIGH PRESSURE FRACTURING SYSTEM WITH COUNTING SYSTEM

The invention relates to a multistage high pressure fracturing system and tubular hydraulic valve (THV) system for connection to a completion string to enable isolation of a zone of interest within a well. In particular, the system enables access to a downhole formation for fracturing the zone of interest and for hydrocarbon production. The system generally includes a plug counting system, a plug capture system and a valve system wherein dropping a series of plugs down the completion string enables successive capture of individual plugs within individual THVs for subsequent fracturing operations. 1. A tubular hydraulic valve (THV) system for connection to a tubing string to enable isolation of a zone of interest within a well , to enable access to a downhole formation for fracturing the zone of interest and for hydrocarbon production , the THV having an internal bore enabling a plug to pass through the THV , the THV comprising:a plug counting system having an uphole end for connection to a tubing string and a plug engagement system for engagement with a plug passing through the internal bore, the plug engagement system for counting successive plugs passing through the plug counting system and for triggering a first hydraulic event when a pre-set number of plugs passing through the internal bore is reached;a plug capture system operatively connected to the plug counting system, the plug counting system responsive to the first hydraulic event to effect plug capture within the THV when the first hydraulic event is triggered;a valve system operatively connected to the plug counting system and plug capture system, the valve system including a valve responsive to plug capture to open the valve to enable fluid flow from the internal bore to the exterior of the THV.2. The system as in wherein the plug engagement system includes at least one pin connected to a tooth ratchet and a plug piston wherein engagement of a plug passing through the internal bore with the at least one ...

Actuator for multilateral wellbore system

A lateral wellbore access system is used for moving an isolation sleeve relative to a window of a completion sleeve to adjust access through the window. The system includes an actuator having an isolation sleeve coupling mechanism and a driving mechanism. The isolation sleeve coupling mechanism is configured to engage with an isolation sleeve. The driving mechanism is configured to longitudinally reciprocate the isolation sleeve coupling mechanism within a bore of a completion sleeve to longitudinally move an isolation sleeve coupled to the isolation sleeve coupling mechanism within the bore relative to a window of the completion sleeve. Movement of the isolation sleeve adjusts a position of the isolation sleeve relative to the completion sleeve window for permitting or blocking access through the window into the bore.

Method and apparatus for wellbore fluid treatment

A tubing string assembly for fluid treatment of a wellbore includes substantially pressure holding closures spaced along the tubing string, which each close at least one port through the tubing string wall. The closures are openable by a sleeve drivable through the tubing string inner bore.

Subterranean Valve Testing, Lubricating, and Sealing Device

A sealant gun is inserted into a limited space work area to engage a buttonhead fitting supported by a fitting assembly perpendicular to a valve stem extending from a tapered plug valve. The fitting assembly orients the buttonhead fitting on the valve stem for movement of the sealant gun in a single vertical direction to engage the buttonhead fitting. The sealant gun injects a sealant under pressure through the buttonhead fitting and the valve stem into a tapered bore of the valve body. The tapered bore receives a tapered plug on the end of the valve stem for movement into and out of a closed valve position with the tapered bore. The sealant is injected between the tapered plug and the tapered bore to provide a seal therebetween that prevents the escape of the fluid flowing through the valve from the valve through the valve stem to the atmosphere. 1. A fitting assembly for sealing a stem of a tapered plug valve having a body with a tapered bore for receiving between open and closed positions a tapered plug extending from the end of the stem comprising:a base having a lower surface with a first opening positioned therein and an upper surface having a vertical member projecting therefrom,the first opening having a preselected dimension for receiving a tubular threaded member extending from the valve stem,said vertical member having a second opening with a preselected dimension, said second opening extending perpendicular to the valve stem,a buttonhead fitting extending from said second opening on said vertical member, the buttonhead fitting including a check valve,the buttonhead fitting extending from the second opening on the vertical member in perpendicular alignment with the tubular threaded member extending from the valve stem, andthe base having an internal passageway connecting the first opening to the second opening to transmit a sealant under pressure from the buttonhead fitting into the valve body between opposing surfaces of the tapered plug and the tapered ...

Streamlined Valve Assembly for Downhole Pump of Reciprocating Pump System

A downhole pump used for a reciprocating pump system includes a barrel coupling to a tubing string and having a standing valve and includes a plunger coupling to a rod string and having a traveling valve. One or both of the valves can include an assembly comprising a housing, an insert, a ball, and a seat. The insert allowing for flow therethrough defines a ball stop at one end has a ball passage at the other end. The insert positions in flow passage of the housing, and one of the ends engages a shoulder in the passage. The insert includes sidewalls and a conical body to reduce turbulence, flow velocity, gas breakout, ball chatter, and the like.

METHOD AND APPARATUS FOR STUCK PIPE MITIGATION

Systems and methods for moving a tubular string within a subterranean well include a collar tool assembly that has a tubular body. The tubular body has an inner bore that is in fluid communication with an inner bore of the tubular string. An outer cavity is located radially outward of the inner bore. An injection port assembly extends from the outer cavity to an outer diameter surface of the tubular body and can move between an injection port closed position and an injection port open position. A hydraulic system can force a treatment fluid of the outer cavity out of the tubular body when the injection port is in the injection port open position. An injection port programmable logic controller is in signal communication with the hydraulic system and can command the injection port assembly to move between the injection port closed position and the injection port open position. 1. A system for moving a tubular string within a subterranean well , the system having: a tubular body, the tubular body being an elongated member with a central axis;', 'an inner bore extending axially through the tubular body, the inner bore of the tubular body positioned to be in fluid communication with an inner bore of the tubular string when the tubular body is connected in line with joints of the tubular string;', 'and an outer cavity located radially outward of the inner bore;', 'an injection port assembly extending from the outer cavity to an outer diameter surface of the tubular body, the injection port assembly operable to move between an injection port closed position and an injection port open position;', 'a hydraulic system, the hydraulic system operable to force a treatment fluid of the outer cavity out of the tubular body when the injection port assembly is in the injection port open position; and', 'an injection port programmable logic controller in signal communication with the hydraulic system and operable to command the injection port assembly to move between the injection ...

SEAL PROTECTION ARRANGEMENT AND SYSTEM

A slurry outlet system including a top sub, a closure sleeve movable relative to the top sub between a closed position and an open position, a seal mounted on one or the other of the top sub or the closure sleeve, a protector sleeve disposed to cover the seal until displaced by one or the other of the top sub or the closure sleeve that does not include the seal during movement to the closed position. A method for pressure sealingly closing a slurry outlet system including bringing a closure sleeve into proximity with a top sub of the slurry outlet system, displacing a protector sleeve, with the closure sleeve, off a seal disposed about the closure sleeve and simultaneously making sealing contact between the top sub and the seal. 1. A slurry outlet system comprising:a top sub;a closure sleeve movable relative to the top sub between a closed position and an open position;a seal mounted on one or the other of the top sub or the closure sleeve;a protector sleeve disposed to cover the seal until displaced by one or the other of the top sub or the closure sleeve that does not include the seal during movement to the closed position.2. The system as claimed in wherein the seal is mounted upon the closure sleeve.3. The system as claimed in wherein the protector sleeve is disposed radially outwardly of the seal.4. The system as claimed in wherein the closure sleeve includes a plurality of seals.5. The system as claimed in further including a wiper.6. The system as claimed in wherein the top sub contacts the protector sleeve.7. The system as claimed in further including a crossover tool disposed radially inwardly of the top sub in a gravel packing claim 1 , fracing or frac packing position of the system and removed therefrom after completion of a gravel packing claim 1 , fracing or frac packing operation.8. The system as claimed in further including a cementing tool disposed radially inwardly of the top sub in a cementing position of the system and removed therefrom after ...

Shiftable Covers, Completion Systems, and Methods to Shift a Downhole Cover in Two Directions

The disclosed embodiments include shiftable covers, completion systems, and methods to shift a downhole cover in two directions. A shiftable cover includes a hollow interior configured to receive a diverter flowing in a first direction. The shiftable cover also includes a diverter seat disposed in the hollow interior and configured to retain the diverter. The shiftable cover also includes a plurality of segments configured to collapse in response to shifting of the shiftable cover from a first position to a second position to retain the diverter, and un-collapse in response to shifting of the shiftable cover from the second position towards the first position. 1. A shiftable cover , comprising:a hollow interior configured to receive a diverter flowing in a first direction;a diverter seat disposed in the hollow interior and configured to retain the diverter; and collapse in response to shifting of the shiftable cover from a first position to a second position to retain the diverter; and', 'un-collapse in response to shifting of the shiftable cover from the second position towards the first position,, 'a plurality of segments configured towherein after the shiftable cover shifts from the first position to the second position, the plurality of segments prevent the diverter from flowing in a second direction uphole of the plurality of segments while the plurality of segments are collapsed.2. The shiftable cover of claim 1 , wherein the shiftable cover shifts from the second position towards the first position in response to a threshold amount of pressure applied to at least one of the shiftable cover and the diverter.3. The shiftable cover of claim 2 , wherein after the shiftable cover shifts from the first position to the second position claim 2 , the plurality of segments prevent the diverter from flowing in a second direction out of the hollow interior.4. The shiftable cover of claim 3 , wherein after the shiftable cover shifts from the second position to the first ...

SNUB FRIENDLY WELLHEAD HANGER

A method for snubbing a wellhead hanger into a wellhead is provided. In one embodiment, a snubbing method includes snubbing a tubing hanger into a wellhead housing from a snubbing unit. Snubbing the tubing hanger into the wellhead housing can include lowering the tubing hanger into a bore of the wellhead housing under pressure and allowing fluid in the bore to pass along an exterior of the tubing hanger to balance fluid pressure above and below the tubing hanger as the tubing hanger is lowered. The tubing hanger can be positioned at a location in the bore of the wellhead housing, which can be elastically deformed to grip and secure the tubing hanger at the location in the bore. Additional methods, systems, and devices are also disclosed. 1. A snubbing method comprising: lowering the tubing hanger into a bore of the wellhead housing under pressure with an obstruction installed in a bore of the tubing hanger to block fluid communication through the bore of the tubing hanger;', 'allowing fluid in the bore of the wellhead housing to pass along an exterior of the tubing hanger to balance fluid pressure above and below the tubing hanger as the tubing hanger is lowered into the bore of the wellhead housing; and', 'positioning the tubing hanger at a location in the bore of the wellhead housing; and, 'snubbing a tubing hanger into a wellhead housing from a snubbing unit, wherein snubbing the tubing hanger into the wellhead housing includeselastically deforming the wellhead housing to grip and secure the tubing hanger at the location in the bore of the wellhead housing.2. The snubbing method of claim 1 , wherein:lowering the tubing hanger into the bore of the wellhead housing under pressure includes lowering a tubing hanger having at least one seal disposed about the exterior of the tubing hanger into the bore of the wellhead housing under pressure; andallowing fluid in the bore of the wellhead housing to pass along the exterior of the tubing hanger to balance fluid pressure ...

DOWNHOLE COMPLETION ASSEMBLY FOR EXTENDED WELLBORE IMAGING

A wellbore is plugged with a downhole completion assembly configured to permit logging and/or imaging in the wellbore past the completion assembly. The completion assembly includes an annular receptacle with an upper end that is open and a lower end that is closed. The receptacle is mounted inside of a plug that blocks flow around the receptacle while flow through the receptacle is prevented by the closed lower end. The lower end projects deeper into the wellbore past the plug. A space is formed inside the receptacle by its closed lower end and sidewalls, which is accessible by an imaging/logging tool deployed from above and inserted through the open upper end. Imaging or logging from within the receptacle increases how much of the formation around the wellbore that can be imaged/logged. Examples of imaging/logging include nuclear, electro-magnetic, acoustic and for sensing characteristics such as resistivity, density, and porosity. 1. A system for imaging in a wellbore comprising: a packer in the wellbore that forms a barrier to fluid flowing in the wellbore, and', 'an annular receptacle disposed in the packer having sidewalls and a closed end that is disposed downhole of the packer; and, 'a downhole completion assembly that comprises,'}an imaging tool that is in imaging communication with formation surrounding the wellbore at a depth in the wellbore that is greater than the packer when selectively inserted into the receptacle.2. The system of claim 1 , wherein the imaging tool comprises a downhole device selected from the group consisting of a gamma ray logging tool claim 1 , a resistivity logging tool claim 1 , a sonic logging tool claim 1 , and combinations thereof.3. The system of claim 1 , wherein an end of the receptacle opposite the closed end comprises an open end claim 1 , the receptacle further comprising a scoop head mounted around the open end.4. The system of claim 1 , further comprising an actuator coupled with the packer and wherein the packer is ...