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Применить Всего найдено 12520. Отображено 200.
16-03-2023 дата публикации

СИСТЕМА, МАШИНОЧИТАЕМЫЙ НОСИТЕЛЬ И СПОСОБ КОМПЬЮТЕРНОЙ ОБРАБОТКИ ДАННЫХ CCE-ТЕСТА ПЛАСТОВОЙ НЕФТИ ТИПА "BLACK OIL"

Номер: RU2792084C2

Изобретение относится исследованию и компьютерной обработке данных пластовых углеводородных флюидов с ярко выраженными признаками образования паровой фазы. Предложен способ компьютерной обработки данных ССЕ-теста пластовой нефти типа «black oil», который включает следующие шаги: получают данные, включающие по крайней мере массивы однофазной и двухфазной областей экспериментальных PV-изотерм; производят оценку корректности данных и сглаживание экспериментальных данных путем построения аппроксимирующей данные полиномиальной кривой, причем оценка корректности данных включает по крайней мере следующие проверки: отсутствия экстремумов и перегибов на графике аппроксимирующей функции, невыпуклости графика аппроксимирующей функции, превышения коэффициентом достоверности аппроксимации заданного критического значения непревышения максимальных расхождений между расчетными значениями и значениями, определенными экспериментально, допустимых величин; в случае некорректности данных осуществляют исключение ...

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10-08-2016 дата публикации

ПЛОТНОМЕР ФЛЮИДА, СОДЕРЖАЩИЙ ОДИНОЧНЫЙ МАГНИТ

Номер: RU2593440C2

Изобретение относится к измерению свойств флюида, более конкретно к определению плотности флюида с применением плотномера, содержащего одиночный магнит. Прибор (300) для определения свойств флюида содержит трубку (304) для приема флюида, одиночный магнит (302), прикрепленный к трубке, и единственную обмотку (306), намотанную вокруг одиночного магнита. Единственная обмотка подсоединена к импульсному источнику (312) тока и принимает импульсный ток, который создает в единственной обмотке магнитное поле, взаимодействующее с одиночным магнитом с приведением трубки в состояние вибрации. Прибор содержит также детектор (306), который связан с трубкой, а также с измерительным блоком (310) и детектирует свойства трубки в процессе ее вибрации. Измерительный блок, основываясь на детектированных свойствах трубки, определяет свойства флюида. У прибора имеется корпус (314), в котором размещены трубка, одиночный магнит и намотанная на него единственная обмотка. Техническим результатом является повышение ...

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18-12-2020 дата публикации

ЗАТРУБНЫЙ БАРЬЕР ДЛЯ ОСНАЩЕНИЯ СКВАЖИН С ИНДУКТИВНОЙ СИСТЕМОЙ

Номер: RU2738918C2

Изобретение относится к внутрискважинной системе для оснащения скважины внутрискважинной беспроводной передачей энергии и сигналов, содержащей: первую скважинную трубчатую конструкцию, вторую скважинную трубчатую конструкцию, расположенную частично внутри первой скважинной трубчатой конструкции, первый электрический блок, содержащий первую часть индуктивного элемента связи, расположенный на наружной поверхности первой скважинной трубчатой конструкции и электрически соединенный с электрическим проводником, затрубный барьер, выполненный с возможностью расширения в затрубном пространстве между первой скважинной трубчатой конструкцией и стенкой ствола скважины или другой внутрискважинной трубчатой конструкцией внутри скважины для обеспечения зонной изоляции между первой зоной, имеющей первое давление, и второй зоной. Причем затрубный барьер содержит: трубчатую металлическую часть для установки в качестве части первой скважинной трубчатой конструкции, причем трубчатая металлическая часть имеет ...

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27-12-2015 дата публикации

УЗЕЛ КВАРЦЕВОГО ИЗМЕРИТЕЛЬНОГО ПРЕОБРАЗОВАТЕЛЯ ДАВЛЕНИЯ И ТЕМПЕРАТУРЫ С ДИНАМИЧЕСКОЙ КОРРЕКЦИЕЙ

Номер: RU2572053C2

Изобретение относится, в общем, к устройству измерения давления и, в частности, к узлу кварцевого измерительного преобразователя давления и температуры, характеризующегося улучшенной коррекцией ошибок при воздействии градиентов давления и температуры. Заявленный узел измерительного преобразователя содержит первый, второй, третий и четвертый генераторы (19, 20, 21, 22) с кварцевой стабилизацией частоты и первый, второй, третий и четвертый кварцевые резонаторы (2, 3, 4, 5) с колебаниями сдвига по толщине, где первый, второй, третий и четвертый генератор управляется соответственно первым, вторым, третьим и четвертым кварцевым резонатором, при этом первый и второй кварцевые резонаторы образуют соответственно резонатор (2) давления и опорный резонатор (3), которые вместе конструктивно исполнены как датчик давления, обеспечивающий частотный выходной сигнал (8); третий кварцевый резонатор (4) образует первый резонатор температуры, конструктивно исполненный как датчик температуры, обеспечивающий ...

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08-09-2020 дата публикации

Способ регулирования режима работы скважины, оборудованной установкой электроцентробежного насоса

Номер: RU2731727C2

Изобретение относится к нефтегазодобывающей промышленности, в частности к технике добычи нефти, и может быть использовано в нефтяной промышленности для поддержания стационарного режима работы скважины в процессе добычи нефти. Технический результат - расширение потребительских свойств, повышение надежности и эффективности эксплуатации скважины, увеличение срока эксплуатации оборудования. Способ включает измерение давления в скважине на приеме электронасоса, поддержание заданной величины давления в колонне труб осуществляют изменением буферного давления на устье скважины посредством автоматического изменения местного гидравлического сопротивления регулируемого дросселя пропорционально-интегрально-дифференцирующим (ПИД) регулятором на основании данных термоманометрической системы о давлении столба добываемой жидкости на приеме УЭЦН, при этом алгоритм ПИД-регулятора встроен в программное обеспечение станции управления установкой электроцентробежного насоса, регулируемый дроссель установлен ...

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20-07-2012 дата публикации

УСТРОЙСТВО И СПОСОБ ДЛЯ ОПРЕДЕЛЕНИЯ ГЛУБИНЫ, НА КОТОРОЙ ВОЗНИКАЕТ УСЛОВИЕ В СТВОЛЕ СКВАЖИНЫ, И КАНИСТРА, ИСПОЛЬЗУЕМАЯ В УКАЗАННОМ УСТРОЙСТВЕ

Номер: RU2456447C2

Группа изобретений относится к горному делу и может быть применена для определения глубины, на которой возникает условие в стволе скважины. Глубину рассчитывают на основе разницы времени прибытия на поверхность первой трубной волны, распространяющейся прямо вверх в стволе скважины, и второй трубной волны, первоначально проходящей вниз и затем отражающейся вверх. Трубные волны создают посредством канистры, выполненной с возможностью имплозии при некотором давлении. После ввода в напорный трубопровод на наземном устройстве канистра перемещается на забой скважины силой тяжести и прокачиваемой текучей средой. Когда канистра достигает глубины, на которой превышено допустимое давление, происходит ее имплозия и создание трубных волн. Анализатор на поверхности земли обнаруживает трубные волны посредством датчиков и создает профиль давления относительно глубины скважины. Канистры можно акустически маркировать с регулированием объема и размера отверстия для создания трубных волн, имеющих конкретные ...

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17-09-2019 дата публикации

Система и способ контроля состояния погружной электрической насосной системы в реальном времени

Номер: RU2700426C2

Группа изобретений относится к горному делу и может быть применена для насосной системы в скважине. Система включает двигательный узел, насос, приводимый в движение двигательным узлом, а также один или более датчиков, сконфигурированных для измерения рабочего параметра в насосной системе и для выдачи сигнала, являющегося представлением измеренного параметра. Насосная система включает также беспроводную телеметрическую систему, которая сконфигурирована для передачи данных, являющихся представлением измеренного параметра, из насосной системы на поверхность. Один или более датчиков могут включать акустически активные датчики, работа которых основана на принципах распространения поверхностных акустических волн. Система также включает модуль массива датчиков, который накапливает данные, собранные при помощи одного или более датчиков. Кроме того, система содержит передатчик, функционально связанный с модулем массива датчиков, и приемник, подключенный над насосным узлом. При этом передатчик сконфигурирован ...

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07-05-2018 дата публикации

СПОСОБ ТЕРМИЧЕСКОЙ ДОБЫЧИ ПЛАСТОВОЙ НЕФТИ В ГОРИЗОНТАЛЬНЫХ СКВАЖИНАХ ПОСРЕДСТВОМ ЭЛЕКТРОНАГРЕВАНИЯ ПЛАСТА С КОНТУРНОЙ И ПОДОШВЕННОЙ ВОДОЙ И ЭЛЕКТРОНАГРЕВАТЕЛЬ ДЛЯ СПОСОБА

Номер: RU2653203C2
Принадлежит: Чжу Веньчжинг (CN)

Группа изобретений относится к способу и устройству для разработки залежей высоковязкой нефти с контурной и подошвенной водой, а также залежей нефти с высокой температурой застывания в нефтяной промышленности. Способ термической добычи пластовой нефти в горизонтальных скважинах посредством электронагревания пласта, в котором электронагреватель располагают, в том числе, в горизонтальных скважинах. Производят электронагревание пласта и повышают температуру залежи до переведения пластовой нефти в передвижное состояние. При этом производят частичное нагревание нефтяного пласта. Причем пласт содержит контурную и подошвенную воду. При этом в указанном пласте бурят несколько горизонтальных скважин. Техническим результатом является повышение эффективности добычи нефти за счет нагрева залежи до высокой температуры, а также исключение перегрева электронагревателя и нефтяного пласта. 2 н. и 10 з.п. ф-лы, 1 ил.

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13-09-2018 дата публикации

УСТРОЙСТВО ДЛЯ ПРИВЕДЕНИЯ В ДЕЙСТВИЕ СКВАЖИННОГО ИНСТРУМЕНТА И СООТВЕТСТВУЮЩИЙ СПОСОБ

Номер: RU2666931C2
Принадлежит: ЭДВАНСТЕК АПС (DK)

Изобретение относится к средствам приведения в действие скважинных устройств. Техническим результатом является обеспечение быстрого и точного приведения в действие многочисленных скважинных инструментов без использования дополнительных средств, таких как, шары или радиочастотные метки. В частности, предложен способ приведения в действие и устройство для его осуществления, в которых датчик (2, 3) давления или расхода принимает сигнал давления или расхода текучей среды для обработки, закачиваемой по бурильной колонне. Контроллер (4), снабжаемый энергией от источника (5) питания, выполняет мониторинг измеряемого давления (2) или расхода (3) в первом временном окне и посредством подвижного элемента (7) приводит в действие первый скважинный инструмент (8) или режим работы его, если измеряемое давление (2) или расход (3) является стабильным в этом временном окне. Кроме того, контроллер (4) выполняет мониторинг измеряемого давления (2) или расхода (3) во втором временном окне и приводит в действие ...

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24-04-2018 дата публикации

Способ выявления аномальных скачков порового давления на границах разделов в непробуренных геологических формациях и система для осуществления этого способа

Номер: RU2651830C2
Принадлежит: Эни С.п.А. (IT)

Настоящее изобретение относится к системе и способу выявления аномальных скачков порового давления на границах разделов в непробуренных геологических формациях и к системе для осуществления этого способа. Техническим результатом является прогнозирование аномального давления в формациях, которые еще только должны быть пробурены, на расстоянии несколько метров перед буром. Система характеризуется тем, что она содержит бур для бурения формации, электроакустический преобразователь, содержащий передатчик и приемник, интегрированный в указанный бур, при этом указанный электроакустический преобразователь связан с электронным обрабатывающим блоком, предназначенным для: питания указанного электроакустического преобразователя, генерирования посредством электроакустического преобразователя первых звуковых волн давления в направлении оси (А) указанного электроакустического преобразователя и приема отраженного сигнала в виде отраженных первых звуковых волн давления, создаваемых по меньшей мере на одной ...

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08-02-2018 дата публикации

ОБНАРУЖЕНИЕ ПОЛОЖЕНИЯ ПЛУНЖЕРА В СКВАЖИНЕ

Номер: RU2644184C2
Принадлежит: РОУЗМАУНТ ИНК. (US)

Группа изобретений относится к системе и способу обнаружения момента достижения плунжером забоя скважины. Система включает датчик давления, выполненный с возможностью измерения давления в скважине и представления измеренного давления на выходе; электронную схему вычисления производных, выполненную с возможностью вычисления производной измеренного давления на выходе; электронную схему обнаружения, которая обнаруживает момент достижения плунжером забоя скважины на основе производной на выходе. Причем производная содержит вторую производную. Способ содержит измерение давления скважины и предоставление данных измеренного давления на выходе, вычисление производной измеренного давления на выходе. Обнаружение момента достижения плунжером забоя скважины на основе вычисленной производной, причем производная представляет собой вторую производную. В другом варианте система содержит датчик давления, выполненный с возможностью измерения давления в скважине и представления измеренного давления на выходе ...

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07-04-2022 дата публикации

Способ реагентно-волновой гидроударной обработки прискважинной зоны коллекторов с трудноизвлекаемыми запасами нефти

Номер: RU2769862C1

Изобретение относится к способам для интенсификации добычи нефти и закачки воды. Технический результат - возможность установления гидродинамической связи в условиях низкопроницаемого пласта, высокой вязкости и неоднородности, плотной кольматации пласта в прискважинной зоне. Способ реагентно-волновой гидроударной обработки прискважинной зоны коллекторов с трудноизвлекаемыми запасами нефти включает выбор скважин с низкопроницаемыми экранированными или неэкранированными продуктивными коллекторами с толщиной пласта не менее 5 м и с приемистостью 0,1-0,5 м3/ч. В экранированных коллекторах определяют допустимое давление на межпластовую перемычку Рдоп, в скважину спускают гидроударное устройство с аккумуляцией давления в колонне труб в виде запорного клапана многоциклового действия. Осуществляют циклическую закачку химреагента в следующей последовательности: аккумулируют давление в колонне труб до значения Ргрп и выше закачкой жидкости в колонну труб при закрытом запорном клапане, открывают запорный ...

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28-04-2018 дата публикации

Номер: RU2016142515A3
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11-07-2018 дата публикации

Номер: RU2016140234A3
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19-07-2021 дата публикации

Номер: RU2019131554A3
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23-03-2020 дата публикации

Номер: RU2018120187A3
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10-06-2020 дата публикации

Номер: RU2018141341A3
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05-02-2019 дата публикации

Номер: RU2017100408A3
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16-09-2019 дата публикации

СКВАЖИННАЯ КЛАПАННАЯ СИСТЕМА

Номер: RU2700352C2

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 ...

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29-11-2017 дата публикации

ВОЛОКОННО-ОПТИЧЕСКОЕ ЗОНДИРОВАНИЕ ФОРМЫ ОБОРУДОВАНИЯ НИЗА БУРИЛЬНОЙ КОЛОННЫ

Номер: RU2636989C1

Изобретение относится к сооружению скважины и, в частности, к контролю свойств скважинных инструментов во время сооружения скважины. Техническим результатом является поддерживание скважинных инструментов в безопасных рабочих пределах. Система контроля оборудования низа бурильной колонны содержит оборудование низа бурильной колонны, содержащее одну или больше бурильных труб и буровое долото, соединенное с одной или больше бурильных труб, и систему датчиков для контроля BHA, содержащую: один или больше отрезков оптического волокна, навитых по спирали и проходящих вдоль одной или больше бурильных труб, модуль источника сигнала, содержащий источник оптического сигнала, расположенный так, чтобы излучать оптический сигнал в один или больше отрезков оптического волокна, модуль обнаружения сигнала, содержащий приемник оптического сигнала, расположенный так, чтобы обнаруживать оптический сигнал, направленный от модуля источника сигнала по одному или больше отрезков оптического волокна, модуль обработки ...

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31-05-2019 дата публикации

СТАНЦИЯ ТЕМПЕРАТУРНОГО МОНИТОРИНГА

Номер: RU189722U1

Полезная модель относится к области геотермического мониторинга, метеорологии, строительства, устройство обеспечивает сбор, хранение как в автономном режиме, так и передачу температурных данных по каналам GPRS в режиме реального времени. Заявлено устройство для проведения температурного мониторинга, которое содержит определенное количество цифровых температурных датчиков, соединенных в температурную косу и корпус с разъемами, для подключения внешний устройств, в котором размещены контроллер 1-Ware шины, микропроцессор, энергонезависимая память, модем радиосвязи, элемент питания. При этом устройство конструктивно снабжено дополнительной температурной косой из аналоговых температурных датчиков, подключенной посредством аналого-цифрового преобразователя через 8-канальный коммутатор, который расположен внутри влагозащитного корпуса. Устройство содержит также часы реального времени, элемент питания и контроллер его заряда, каждый из которых соединен с микропроцессором заданным образом. При этом ...

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16-04-2024 дата публикации

Способ определения градиента температуры вдоль скважин

Номер: RU2817433C1

Изобретение относится к методам определения градиента температуры горных пород в целевых интервалах глубин. Техническим результатом изобретения является повышение точности определения градиента температуры вдоль скважины. Градиент температуры определяют с точной привязкой результата к целевым интервалам глубин, что делает возможным исследование вариаций градиента температуры в малых интервалах глубин и необходимо для определения вариаций теплового потока вдоль скважины. Способ определения градиента температуры включает в себя определение максимального значения времени стабилизации температуры термозонда. После этого регистрируют температуру вдоль скважины при спуске термозонда в скважину с остановками термозонда до стабилизации регистрируемой термозондом температуры перед его входом в каждый целевой интервал глубин. По достижении термозондом заранее заданной глубины изменяют направление его движения. Затем регистрируют температуру вдоль скважины при подъеме термозонда с остановками термозонда ...

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13-03-2023 дата публикации

Способ добычи высоковязкой нефти с использованием пары скважин

Номер: RU2791828C1

Изобретение относится к нефтяной промышленности. Технический результат – снижение риска парогазопроявлений во время проведения подземных ремонтов в нагнетательных скважинах, сокращение временных и транспортных затрат на мероприятия по глушению и охлаждению нагнетательных скважин. Способ добычи высоковязкой нефти включает строительство добывающей скважины 2 и нагнетательной скважины 3, расположенной параллельно добывающей скважине 2, со спуском эксплуатационных колонн 4, 5 и фильтров-хвостовиков 6, проведение в горизонтальном стволе нагнетательной скважины 3 геофизических исследований по определению нефтенасыщенности вдоль горизонтального ствола, размещение в нагнетательной скважине 3 двух колонн насосно-компрессорных труб НКТ, причем конец колонны НКТ меньшего диаметра размещают в начале горизонтального ствола, а конец колонны НКТ большего диаметра - в зоне с нефтенасыщенностью более 60%. При этом строительство нагнетательной скважины 3 осуществляют выше добывающей скважины 2 и производят ...

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20-03-2016 дата публикации

СПОСОБ ИНТЕРПРЕТАЦИИ ИЗМЕРЕНИЙ СКВАЖИННОГО ДЕБИТА ВО ВРЕМЯ СКВАЖИННОЙ ОБРАБОТКИ

Номер: RU2577568C1

Изобретение относится к обработке скважин и разработке месторождений и, в частности, системе и способу интерпретации дебита потока во время скважинной обработки. Технический результат заключается в эффективности стимуляционной обработки за счет получения знаний о распределении потока на рабочем интервале в режиме реального времени. Способ включает этапы, на которых размещают комплект нижней части буровой колонны (КНБК) в стволе скважины. Причем КНБК содержит нагнетательный порт для выдачи текучей среды в скважины, первый датчик, расположенный над нагнетательным портом, и второй датчик, расположенный под нагнетательным портом. Каждый из первого датчика и второго датчика генерирует сигнал обратной связи, представляющий собой скорость потока текучей среды на участке ствола скважины. Определяют приблизительную глубину участка КНБК в стволе. Формируют модель данных, основанную на наборе инструкций, причем модель данных представляет по меньшей мере характеристики потока текучей среды в стволе ...

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27-05-2016 дата публикации

СПОСОБ ОПРЕДЕЛЕНИЯ ЗАКОЛОННОГО ПЕРЕТОКА ЖИДКОСТИ МЕТОДОМ АКТИВНОЙ ТЕРМОМЕТРИИ В СКВАЖИНАХ, ПЕРЕКРЫТЫХ НАСОСНО-КОМПРЕССОРНЫМИ ТРУБАМИ

Номер: RU2585301C1

Изобретение относится к нефтедобывающей промышленности и может быть использовано для определения интервалов заколонного перетока жидкости из пластов, перекрытых насосно-компрессорными трубами. Техническим результатом является повышение достоверности определения интервалов заколонного перетока жидкости в скважинах перекрытых НКТ. Способ включает регистрацию термограмм до и после кратковременного локального нагрева обсадной колонны в предполагаемом интервале движения флюида путем регистрации температуры по стволу скважины с последующим их анализом. При этом опускают насосно-копрессорную трубу из стеклопластика с размещенными снаружи датчиками температуры в выбранный интервал исследования, далее осуществляют индукционный нагрев обсадной колонны через стеклопластиковую насосно-компрессорную трубу в течение времени, определяемого по математическому выражению, и проводят регистрацию температуры во времени в процессе локального кратковременного нагрева колонны и по стволу скважины в исследуемом ...

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03-12-2021 дата публикации

УСТРОЙСТВО И СПОСОБ ДЛЯ ВЫПОЛНЕНИЯ ИСПЫТАНИЙ ДЛЯ ОПРЕДЕЛЕНИЯ ПЛАСТОВОГО НАПРЯЖЕНИЯ НА НЕОБСАЖЕННОМ УЧАСТКЕ СТВОЛА СКВАЖИНЫ

Номер: RU2761075C1
Принадлежит: КьюВЕЙВ АС (NO)

Изобретение относится к инструментальному узлу для выполнения испытаний для определения пластового напряжения на необсаженном участке ствола скважины. Инструментальный узел содержит по меньшей мере два средства изоляции ствола скважины, расположенных с осевым расстоянием между ними для создания изолированного участка на необсаженном участке ствола скважины. Насосное устройство выполнено с возможностью сообщения по текучей среде с изолированным участком и с возможностью изменения давления внутри изолированного участка. Датчик давления выполнен с возможностью измерения давления внутри изолированного участка. Блок управления предназначен для управления последовательностью испытаний. Акустическое ударно-волновое устройство выполнено с возможностью генерирования серии электрически индуцированных акустических ударных волн и фокусировки указанных электрически индуцированных акустических ударных волн на область стенки ствола скважины для постепенной пробивки перфорационного туннеля из ствола скважины ...

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23-12-2019 дата публикации

СИСТЕМА ВНУТРИСКВАЖИННОГО ОБОРУДОВАНИЯ ДЛЯ ГИДРАВЛИЧЕСКОГО РАЗРЫВА ПЛАСТА И ОСУЩЕСТВЛЯЕМЫЙ С ЕЁ ПОМОЩЬЮ СПОСОБ ПРОВЕДЕНИЯ ГИДРАВЛИЧЕСКОГО РАЗРЫВА ПЛАСТА (ВАРИАНТЫ)

Номер: RU2709892C1

Группа изобретений относится к внутрискважинному оборудованию для проведения гидравлического разрыва пласта (ГРП). Система внутрискважинного оборудования содержит нижний пакер, промывочный порт над нижним пакером, порт ГРП над промывочным портом, верхний пакер над портом ГРП, клапанную муфту над верхним пакером и струйный насос над клапанной муфтой. Для осуществления способа гидравлического разрыва пласта размещают продольную компоновку для ГРП на колонне насосно-компрессорных труб (НКТ) в скважине. Активируют верхний и нижний пакер с герметизацией секции скважины между пакерами. Открывают промывочный порт. Открывают порт ГРП и подают жидкость гидроразрыва с проппантом под давлением по компоновке через порт ГРП, производя разрыв пород, окружающих скважину. Производят разгерметизацию верхнего пакера. Создают давление в скважине и проталкивают чистящую жидкость снаружи верхнего пакера. Удаляют оставшуюся жидкость гидроразрыва с проппантом из области, расположенной между пакерами. Используют ...

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20-02-2014 дата публикации

СПОСОБ ЭЛЕКТРОМАГНИТНОЙ ДЕФЕКТОСКОПИИ В МНОГОКОЛОННЫХ СКВАЖИНАХ И ЭЛЕКТРОМАГНИТНЫЙ СКВАЖИННЫЙ ДЕФЕКТОСКОП

Номер: RU2507393C1

Изобретение относится к области контроля технического состояния обсадных колонн, насосно-компрессорных труб и других колонн нефтяных и газовых скважин. Техническим результатом является повышение точности и достоверности выявления наличия и местоположения поперечных и продольных дефектов конструкции скважины и подземного оборудования как в магнитных, так и в немагнитных первом, втором и последующих металлических барьерах. Способ электромагнитной дефектоскопии в многоколонных скважинах включает измерение ЭДС самоиндукции, наведенной в катушке вихревыми токами, возбуждаемыми в исследуемых металлических барьерах процессом спада электромагнитного поля, вызванного импульсами тока намагничивания катушки. На каждую из приемно-генераторных катушек в отдельности подают серию импульсов фиксированной длительности из диапазона 0,1-1000 мс, намагничивая последовательно все металлические барьеры, начиная с ближайшего, причем длительность импульсов возрастает для каждого последующего металлического барьера ...

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14-11-2019 дата публикации

Способ разработки залежи высоковязкой нефти или битума

Номер: RU2706154C1

Изобретение относится к нефтедобывающей промышленности. Технический результат - увеличение коэффициента извлечения нефти как на ранней стадии разработки, так и на выработанных месторождениях за счет повышения эффективности теплового воздействия на пласт с одновременным снижением материальных затрат и экономией энергоресурсов, расширение технологических методов теплового воздействия на продуктивный пласт. Способ разработки залежи высоковязкой нефти или битума включает определение нефтенасыщенной толщины пласта, проницаемости пласта, начальных пластовых давления и температуры, строительство горизонтальной добывающей и как минимум двух вертикальных нагнетательных скважин, размещенных над горизонтальной добывающей скважиной на одной плоскости выше ствола горизонтальной добывающей скважины на 5-10 м по сетке с расстоянием от 50 до 200 м друг от друга. Осуществляют изоляцию забоя вертикальных нагнетательных скважин, затем производят перфорацию вертикальных нагнетательных скважин по всему интервалу ...

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07-05-2024 дата публикации

СПОСОБ КОНТРОЛЯ ЗА РАЗРАБОТКОЙ МНОГОПЛАСТОВОЙ ГАЗОВОЙ ЗАЛЕЖИ

Номер: RU2818962C1

Изобретение относится к области исследования эксплуатационных скважин. Способ контроля за разработкой многопластовой газовой залежи включает спуск в затрубное пространство эксплуатационных скважин месторождения датчиков давления и температуры и подключение их с помощью кабелей к измерительным входам индивидуальной телеметрической системы измерения термобарических параметров вдоль ствола насосно-компрессорных труб, которой снабжены скважины месторождения. С помощью телеметрической системы осуществляют непрерывное измерение давления и температуры в трубном и затрубном пространстве. С помощью GSM-модема осуществляют передачу полученных данных удаленной информационно-управляющей системе. Далее осуществляют их автоматизированную обработку, интерпретацию, трехмерное геолого-гидродинамическое и термическое моделирование состояния скважин месторождения для определения газонасыщенной толщины вовлекаемого в дренирование пласта по изменению давления и температуры в реагирующих скважинах, определения ...

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23-04-2020 дата публикации

Способ разработки залежи сверхвязкой нефти на поздней стадии

Номер: RU2719882C1

Изобретение относится к нефтедобывающей промышленности, в частности к способам увеличения добычи сверхвязкой нефти на месторождении. Техническим результатом является создание безаварийного способа разработки залежи сверхвязкой нефти на поздней стадии позволяющего с наименьшими затратами времени произвести строительство нового горизонтального ствола из добывающей скважины. Способ включает строительство пар расположенных друг над другом горизонтальных добывающих и нагнетательных скважин, оснащенных в горизонтальной части соответствующими фильтрами-хвостовиками, прогрев залежи закачкой теплоносителя - пара в обе скважины с прогревом продуктивного пласта и созданием паровой камеры, закачку пара через нагнетательные скважины, отбор продукции за счет парогравитационного дренажа через добывающие скважины и контроль состояния паровой камеры. После выработки участка залежи в одной из пар скважин останавливают закачку пара и отбор жидкости. После снижения температуры в добывающей скважине ниже пороговой ...

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10-03-2008 дата публикации

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Номер: RU2006131692A
Принадлежит:

... 1. Система обнаружения закупоривания наружного межтрубного пространства в газлифтной нефтяной скважине, содержащая датчик давления, функционально соединенный с наружным межтрубным пространством газлифтной нефтяной скважины и выполненный с возможностью подачи сигнала давления в наружном межтрубном пространстве, и контроллер, предназначенный для приема сигнала и получения множества данных измерений давления относительно наружного межтрубного пространства с разнесением измерений во времени, при этом контроллер предназначен для вычисления параметра, указывающего на закупоривание межтрубного пространства, на основе множества измерений. 2. Система по п.1, отличающаяся тем, что контроллер является элементом датчика давления. 3. Система по п.1, отличающаяся тем, что датчик давления выполнен с возможностью подачи первого сигнала, указывающего на давление в наружном межтрубном пространстве, и второго сигнала, указывающего на закупоривание. 4. Система по п.3, отличающаяся тем, что датчик давления ...

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Номер: RU2009122593A
Принадлежит:

... 1. Система для анализа многофазного потока в стволе скважины, содержащая систему ввода данных, предназначенную для приема данных о давлении и температуре, считанных с пары датчиков, расположенных в стволе скважины, вычислительную систему, которая использует модель анализа потока для создания набора свойств скважинных текучих сред, исходя из указанных данных о давлении и температуре, при этом набор свойств скважинных текучих сред содержит, по меньшей мере, одну из следующих характеристик: количество смеси текучих сред, значение скорости фазы, дебит, плотность смеси, вязкость смеси, объемное содержание текучих сред в многофазном потоке и скорость проскальзывания и систему вывода данных о свойствах скважинных текучих сред. ! 2. Система по п.1, в которой пара датчиков постоянно установлена в стволе скважины. !3. Система по п.1, дополнительно содержащая систему анализа анализа данных о давлении и температуре, полученных из множества пар датчиков, для предоставления данных о свойствах скважинных ...

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Изобретение относится к нефтедобывающей промышленности. Технический результат - снижение энергетических и эксплуатационных затрат на подготовку и закачку теплоносителя в нагнетательную скважину, предотвращение срывов и отказов в работе насоса за счет поддержания насоса в рабочей температурной зоне. Способ эксплуатации скважин для добычи высоковязкой нефти с остановкой закачки включает строительство горизонтальной нагнетательной скважины и горизонтальной добывающей скважины, расположенной ниже и параллельно нагнетательной скважине, проведение в горизонтальном стволе нагнетательной скважины геофизических исследований по определению нефтенасыщенности вдоль горизонтального ствола, размещение в нагнетательной скважине двух колонн насосно-компрессорных труб - НКТ с размещением конца колонны меньшего диаметра - в начале горизонтального ствола, а конца колонны большего диаметра - в зоне с нефтенасыщенностью более 60%, размещение в добывающей скважине оптоволоконного кабеля и НКТ с насосом и датчиками ...

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Номер: RU2726723C1

Изобретение относится к нефтяной и газовой промышленности, и в частности к измерению параметров бурения скважин. Технический результат - создание надежного и точного устройства для контроля непосредственно в процессе бурения давления бурового раствора в скважине. Устройство содержит корпус с установленным в нем преобразователем давления, узлы привода и съема колебаний, источник питания, линию связи забоя с устьем скважины, преобразователь давления выполнен в виде механического резонатора-камертона, одна ветвь камертона выполнена полой в сечении в виде эллипса, при этом малая ось эллипса параллельна направлению колебаний второй ветви, а полость первой ветви посредством патрубка через мембрану соединена с затрубным пространством скважины и частота колебаний этой ветви равна частоте колебаний второй ветви, устройство снабжено микропроцессором, жестко закрепленным в корпусе, выход которого соединен с линией связи забоя с устьем скважины. 1 ил.

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Изобретение относится к разработке нефтяных месторождений. Технический результат – эффективный прогрев призабойных зон скважин, увеличение охвата прогревом пласта на 80-90%. В способе разработки залежи сверхвязкой нефти, включающем бурение рядов скважин с параллельными в горизонтальной плоскости стволами, пробуренными навстречу друг другу в шахматном порядке, производят двухэтапную циклическую закачку теплоносителя и добычу нефти скважинами. На первом этапе цикла закачивают теплоноситель в нечетные скважины ряда и добывают нефть из четных скважин ряда, после чего останавливают скважины на период пропитки коллектора. На втором этапе цикла закачивают теплоноситель в четные скважины ряда и добывают нефть из нечетных скважин ряда, после чего останавливают скважины на период пропитки коллектора. Повторяют цикл несколько раз. Указанные скважины с горизонтальными стволами бурят в нижней части залежи с перекрытием забойной части соответствующих пробуренных навстречу скважин на 15-35 м и с расстоянием ...

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Номер: RU2723769C1

Настоящее изобретение относится к области разработки нефтяных и газовых месторождений, и, в частности, оно относится к способу расчета объема обратного потока жидкости для гидроразрыва пласта при гидроразрыве в горизонтальных скважинах в залежах газа трещиноватых песчаников. Способ включает этапы, на которых на основании данных о трещинах на месте рассчитывают фрактальную размерность распределения трещин в участке целевого коллектора, фрактальную размерность длины трещин, коэффициент плотности расположения трещини постоянную Фишера. Затем на основании полученных параметров трещин создают модель фрактальной дискретной сети трещин для коллектора. После рассчитывают эквивалентный тензор проницаемости модели фрактальной дискретной сети трещин. Далее эквивалентный тензор проницаемости подставляют в уравнение неразрывности двухфазного, газожидкостного, фильтрационного потока с созданием модели обратного потока жидкости для гидроразрыва пласта. Решают математическую модель обратного потока жидкости ...

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Группа изобретений относится к узлам сопряжения многоствольных скважин высокого давления. Технический результат – поддержание соосности секций главной и боковой скважин. Система скважины содержит главный ствол скважины и боковой ствол скважины, проходящий от главного ствола скважины в узле сопряжения, дефлектор, расположенный в главном стволе скважины в или рядом с узлом сопряжения, узел многоствольного сопряжения, способный проходить внутри главного ствола скважины по меньшей мере один механический элемент жесткости, проходящий в продольном направлении между корпусом коннектора и D-образным округлым коннектором, установленный на одной из секций: на секции главной скважины или на секции боковой скважины. При этом узел многоствольного сопряжения содержит корпус коннектора, секцию главной скважины, прикрепленную к корпусу коннектора в приемном гнезде секции главной скважины, и секцию боковой скважины, прикрепленную к корпусу коннектора в приемном гнезде секции боковой скважины. Секция главной ...

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Номер: RU2661502C1

Изобретение относится к нефтегазовой промышленности и может быть использовано для оптимизации периодичности газодинамических исследований (ГДИ) скважин на нефтегазоконденсатных месторождениях Крайнего Севера. Автоматизированная система управления технологическими процессами (АСУ ТП) выдает команду системе телемеханики кустов скважин (СТКС) на проведение испытаний. Получив команду, ее контролируемый пункт (КП) фиксирует на выбранной скважине значения забойного, устьевого и затрубного (если датчик установлен) давления, температуру газа на устье и дебит. Значение забойного давления КП определяют расчетным путем по соответствующей формуле. Затем КП останавливает работу выбранной скважины и заданным шагом дискретизации контролирует давление на устье и/или за колонной до полной его стабилизации. Далее КП во время сеансов связи эту информацию, сформированную в виде пакета, передает через ДП в АСУ ТП, которая на основе этой полученной информации от СТКС формирует кривую восстановления давления ...

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Изобретение относится к нефтедобывающей промышленности. Технический результат - снижение паронефтяного отношения в 1,3 раза, увеличение добычи и охвата вытеснением за счет включения в разработку незатронутых зон и обеспечение равномерной выработкой запасов нефти с поддержанием оптимальной температуры для отбора продукции в дополнительной скважине. Способ разработки высоковязкой нефти включает строительство пар расположенных друг над другом горизонтальных добывающих и нагнетательных скважин, а также вертикальных наблюдательных скважин, закачку теплоносителя через нагнетательные скважины с прогревом продуктивного пласта и созданием паровой камеры, отбор продукции за счет парогравитационного дренажа через добывающие скважины и контроль за состоянием паровой камеры. При этом разработку ведут с регулированием текущего размера паровой камеры путем изменения объемов закачки теплоносителя в нагнетательные скважины и отбора жидкости из добывающих скважин с контролем объема паровой камеры. Осуществляют ...

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Изобретение относится к области добычи метана из угольных пластов и может найти применение при опытной эксплуатации разведочных скважин на многопластовых залежах метаноугольных месторождений. Технический результат заключается в сокращении затрат на проведение гидроразрыва при эксплуатации скважин на многопластовых залежах метаноугольных месторождений. Предложен способ проведения исследований метаноугольных скважин с использованием оптоволоконного кабеля, включающий спуск геофизического оборудования - датчика давления и кабеля-датчика распределенной температуры, соединенного с наземным оборудованием для регистрации давления и температуры, и постоянный мониторинг температуры вдоль всего ствола скважины одновременно с регистрацией забойного давления. Измерения производят при откачке пластовой жидкости и при восстановлении уровня пластовой жидкости. Затем по полученным значениям давления определяют величины депрессии, при которых начинают работать те или иные интервалы, а по графикам зависимости ...

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Изобретение предназначено для непрерывного нагнетания высокой концентрации окислителя в подземный угольный пласт в процессе подземной газификации угля. Нагнетательное устройство содержит газонепроницаемо последовательно соединенные друг с другом гибкую трубу, механическое резальное устройство и форсунку. Гибкая труба используется для перемещения нагнетательного устройства через хвостовик скважины в предварительно определенное положение в подземном угольном пласте. Механическое резальное устройство используется для отрезания форсунки, при необходимости, для отведения оставшейся части нагнетательного устройства. Форсунка предназначена для нагнетания охладителя и окислителя в угольный пласт для газификации. Форсунка содержит концентрически расположенные центральную трубку для потока окислителя и наружный корпус, проходящие от соединительного конца в нагнетательный конец форсунки. Центральная трубка и наружный корпус соединены посредством неуплотненной спирали и образуют спиральный проход для ...

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Изобретение относится к нефтедобывающей промышленности. Технический результат - ускорение выхода на промышленную эксплуатацию залежи, сокращение энергетических затрат, эффективная добыча продукции. Способ разработки залежи высоковязкой нефти с использованием парных горизонтальных скважин включает строительство в продуктивном пласте горизонтальной нагнетательной скважины и добывающей скважины, расположенной ниже и параллельно нагнетательной скважине, спуск в нагнетательную скважину двух колонн насосно-компрессорных труб НКТ разного диаметра с размещением концов в различных интервалах горизонтального ствола, спуск в добывающую скважину одной или двух колонн НКТ со смещением конца или концов по горизонтали относительно концов НКТ нагнетательной скважины не менее чем на 10 м, первоначальный прогрев продуктивного пласта закачкой необходимого для прогрева межскважинного пространства залежи с созданием гидродинамической связи объема пара, выдержку для термокапиллярной пропитки и остывания ствола ...

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Изобретение относится к нефтедобывающей промышленности и предназначено для одновременного измерения давления вне и внутри НКТ и может быть использовано для установки на оборудовании нефтяных скважин с целью получения информации для систем регулирования добычи продукции на нефтяных месторождениях страны. Техническим результатом предлагаемого изобретения является исключение указанных недостатков прототипа и получение дополнительных преимуществ при автоматическом управлении режимом работы скважины. Технический результат достигается тем, что предлагаемое устройство для одновременного измерения давления вне и внутри НКТ в действующих механизированных нефтяных скважинах содержит скважинную камеру в виде стандартной НКТ с резьбовыми соединениями на концах и дистанционный глубинный двухдатчиковый манометр, стационарно закрепленный на НКТ так, что один датчик манометра гидравлически соединен с внутренним пространством НКТ, а другой датчик с внешним пространством НКТ, с возможностью дублирования ...

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СПОСОБ ПОСТРОЕНИЯ КАРТЫ ИЗОБАР ДЛЯ НЕФТЕГАЗОКОНДЕНСАТНЫХ МЕСТОРОЖДЕНИЙ

Номер: RU2722331C1

Изобретение относится к нефтегазовой промышленности и может быть использовано при построении карты изобар для разрабатываемых нефтегазоконденсатных месторождений (НГКМ). Техническим результатом является повышение точности оперативного построения в автоматическом режиме карты изобар месторождения с использованием информационно-управляющей системы (ИУС НГКМ) на любую заданную дату по требованию обслуживающего персонала. Способ включает использование паспортных данных скважин, которые занесены в базу данных (БД) ИУС НГКМ. Одновременно ИУС НГКМ контролирует средствами системы телеметрии кустов газовых скважин устьевое давление Р, устьевую температуру Т, расхода газа Q, и записывает их в свою БД. По результатам этих измерений ИУС НГКМ осуществляет проверку каждой эксплуатируемой скважины на отсутствие нештатных ситуаций в ее работе. В случае выявления нештатной ситуации в работе скважины ИУС НГКМ исключает результаты сделанных измерений для построения карты изобар на эту дату и использует среднесуточное ...

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31-01-2020 дата публикации

СПОСОБ РАЗРАБОТКИ ЗАЛЕЖИ СВЕРХВЯЗКОЙ НЕФТИ С ГАЗОВОЙ ШАПКОЙ

Номер: RU2712904C1

Изобретение относится к нефтедобывающей промышленности. Технический результат – повышение эффективности извлечения нефти, исключение прорыва теплоносителя в газовые шапки, повышение эффективности закачки пара, повышение качества добываемой продукции, снижение паронефтяного отношения. В способе разработки залежи сверхвязкой нефти с газовой шапкой бурят горизонтальные добывающие скважины, определяют радиус внешнего контура газонефтяного контакта ГНК по данным бурения горизонтальных добывающих скважин, при радиусе внешнего контура ГНК от 750 м и более бурят горизонтальные нагнетательную и газодобывающую скважины в газовой шапке, горизонтальные газодобывающую и нагнетательную скважины оборудуют фильтрами, при радиусе внешнего контура ГНК менее 750 м бурят вертикальные нагнетательную и газодобывающую скважины в газовой шапке, перфорируют вертикальные скважины у кровли пласта, устанавливают устройства контроля температуры и давления в горизонтальных добывающих и газодобывающей скважинах, регулируют ...

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10-06-2020 дата публикации

ПОДЗЕМНАЯ СИСТЕМА ИЗВЛЕЧЕНИЯ ГЕОТЕРМАЛЬНОЙ ЭНЕРГИИ

Номер: RU2018141341A
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30-07-2018 дата публикации

ВНУТРИСКВАЖИННАЯ СИСТЕМА

Номер: RU2017100408A
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10-11-2015 дата публикации

МОНИТОРИНГ СКВАЖИННЫХ ПОКАЗАТЕЛЕЙ ПРИ ПОМОЩИ ИЗМЕРИТЕЛЬНОЙ СИСТЕМЫ, РАСПРЕДЕЛЕННОЙ ПО БУРИЛЬНОЙ КОЛОННЕ

Номер: RU2015105531A
Принадлежит:

... 1. Способ мониторинга скважинных показателей в буровой скважине, проходящей через формацию, согласно которомуразмещают в буровой скважине колонну соединенных труб, формирующую скважинную электромагнитную цепь, обеспечивающую создание электромагнитного сигнального канала между множеством датчиков в колонне соединенных труб,получают через скважинную электромагнитную цепь данные от первого датчика указанного множества датчиков;получают через скважинную электромагнитную цепь данные от второго датчика указанного множества датчиков, который расположен на расстоянии в продольном направлении от первого датчика в колонне соединенных труб;сопоставляют данные первого датчика и данные второго датчика;делают вывод о скважинном показателе на основе данных от датчиков иуправляют скважинным показателем на основе указанного сопоставления путем выборочной регулировки с учетом указанного вывода по меньшей мере одного параметра, влияющего на указанный скважинный показатель, причемвыборочную регулировку указанного ...

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28-07-2020 дата публикации

СКВАЖИННАЯ БУРОВАЯ СИСТЕМА

Номер: RU2019100629A
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10-04-2012 дата публикации

СПОСОБ ОПРЕДЕЛЕНИЯ ПРОФИЛЯ ПРИТОКА ФЛЮИДОВ И ПАРАМЕТРОВ ОКОЛОСКВАЖИННОГО ПРОСТРАНСТВА

Номер: RU2010139992A
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Способ определения профиля притока флюидов и параметров околоскважинного пространства посредством температурных измерений вдоль ствола скважины, отличающийся тем, что после длительной работы скважины с постоянным дебитом в течение времени, достаточного для обеспечения минимального влияния продолжительности добычи на скорость последующего изменения температуры флюидов, поступающих из продуктивных пластов в скважину, изменяют дебит скважины, измеряют давление на забое в скважине до и после изменения дебита, для каждого пласта измеряют температуру притока флюидов, поступающих в скважину, и строят графики зависимости от времени температуры притока флюидов и производной температуры притока по логарифму времени, прошедшего после изменения дебита, определяют моменты времени, при которых производные температуры выходят на постоянные значения, определяют изменения температур притока к этим моментам времени и по найденным величинам рассчитывают относительные дебиты и скин-факторы пластов.

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05-12-2019 дата публикации

ХАРАКТЕРИЗУЮЩИЕ ОТКЛИКИ В БУРОВОЙ СИСТЕМЕ

Номер: RU2018120147A
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27-06-2015 дата публикации

СПОСОБ ОПРЕДЕЛЕНИЯ ПРАВИЛЬНОСТИ ВЫПОЛНЕНИЯ ОПЕРАЦИИ ИЗОЛЯЦИИ В СКВАЖИНЕ

Номер: RU2013154738A
Принадлежит:

... 1. Способ определения того, правильно ли была выполнена операция изоляции в скважине, причем указанный способ содержит следующие шаги:располагают в стволе скважины трубную обсадку, содержащую по меньшей мере один датчик давления;выполняют в скважине операцию изоляции в кольцевой области, заключенной между наружной поверхностью указанной трубной обсадки и внутренней поверхностью стенки ствола скважины или между наружной поверхностью указанной трубной обсадки и внутренней поверхностью другой трубной обсадки, в которой находится указанная трубная обсадка, для изоляции указанной трубной обсадки в стволе скважины;контролируют давление флюида в кольцевой области посредством по меньшей мере одного датчика давления; ипередают из скважины на поверхность данные о давлении флюида, контролируемые датчиком и указывающие на то, правильно ли была выполнена операция изоляции в скважине.2. Способ по п. 1, причем указанный способ представляет собой способ определения того, правильно ли была выполнена операция ...

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10-11-2011 дата публикации

СПОСОБ И СИСТЕМА ДЛЯ ИНТЕРПРЕТАЦИИ ИСПЫТАНИЙ СВАБИРОВАНИЕМ С ИСПОЛЬЗОВАНИЕМ НЕЛИНЕЙНОЙ РЕГРЕССИИ

Номер: RU2010116746A
Принадлежит:

... 1. Способ увеличения добычи в пласте-коллекторе, содержащий этапы, на которых: ! выполняют испытание свабированием на глубине в трубе, при этом трубу располагают в стволе скважины, и при этом часть ствола скважины располагают внутри пласта-коллектора; ! периодически измеряют во время испытания свабированием давление в нижней части трубы с использованием манометра для получения множества измерений давления, при этом манометр прикрепляют к внутренней стенке нижней части трубы; и ! определяют множество скоростей потока флюида, текущего из пласта-коллектора через перфорации в стволе скважины в трубу с использованием уравнения скорости потока и множества измерений давления. ! 2. Способ по п.1, дополнительно содержащий этапы, на которых: ! генерируют после определения множества скоростей потока флюида модель пласта-коллектора с использованием множества скоростей потока флюида, при этом модель используют для определения потенциала добычи пласта-коллектора. ! 3. Способ по п.2, в котором генерация ...

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27-05-2008 дата публикации

СИСТЕМА И СПОСОБ ИЗМЕРЕНИЯ ПАРАМЕТРОВ В СТВОЛЕ СКВАЖИНЫ

Номер: RU2006141181A
Принадлежит:

... 1. Система для измерения параметров ствола скважины, содержащая электрическую погружную насосную систему, имеющую множество узлов ступеней, содержащих по меньшей мере погружной двигатель, защитный кожух двигателя и скважинный насос, и переводник датчика, соединенный между концами пары узлов ступеней, при этом переводник датчика содержит датчик для измерения требуемого параметра. 2. Система по п.1, отличающаяся тем, чтоуказанный датчик содержит множество датчиков, предназначенных для измерения внутреннего параметра электрической погружной насосной системы и наружного параметра. 3. Система по п.1, отличающаяся тем, чтотребуемый параметр содержит температуру. 4. Система по п.1, отличающаяся тем, чтотребуемый параметр содержит давление. 5. Система по п.2, отличающаяся тем, чтовнутренний параметр содержит давление. 6. Система по п.2, отличающаяся тем, чтовнутренний параметр содержит температуру. 7. Система по п.2, отличающаяся тем, чтовнутренний параметр содержит крутящий момент. 8. Система ...

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20-07-2016 дата публикации

КОНТРОЛЬ ОПЕРАЦИЙ БУРЕНИЯ С ИСПОЛЬЗОВАНИЕМ ГРУППЫ СОГЛАСОВАННО ДЕЙСТВУЮЩИХ ГИДРАВЛИЧЕСКИХ МОДЕЛЕЙ

Номер: RU2014148526A
Принадлежит:

... 1. Система контроля для бурения подземных скважин, содержащая:группу гидравлических моделей, причем каждая из гидравлических моделей выполнена с возможностью в процессе операции бурения выдавать установочное значение давления в режиме реального времени.2. Система по п. 1, дополнительно содержащая контроллер и селектор, причем контроллер выполнен с возможностью управлять работой по меньшей мере одного устройства, а селектор выполнен с возможностью выбирать, какое значение из группы установочных значений давления подавать на вход контроллера.3. Система по п. 2, отличающаяся тем, что устройство содержит регулятор потока.4. Система по п. 3, отличающаяся тем, что регулятор потока содержит дроссель, выполненный с возможностью регулируемым образом ограничивать поток из скважины.5. Система по п. 3, отличающаяся тем, что регулятор потока выполнен с возможностью регулировать поток через стояк.6. Система по п. 3, отличающаяся тем, что регулятор потока выполнен с возможностью регулировать поток между ...

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03-03-2025 дата публикации

Скважинное устройство для измерения давления, температуры и влагосодержания

Номер: RU2835642C1

Изобретение относится к устройствам, предназначенным для измерения параметров потока флюида (нефть, вода, газ и их смеси), таких как температура, давление, влагосодержание (скважинным датчикам), и может быть использовано для анализа параметров в горизонтальных скважинах, в том числе скважинах с многостадийным гидроразрывом пласта (ГРП). Техническим результатом является упрощение конструкции устройства одновременно с повышением надежности работы датчиков и возможности использования устройства в загрязненных скважинах. Заявлено скважинное устройство для измерения давления, температуры и влагосодержания потока флюида, которое включает две секции, последовательно соединенные между собой. При этом геометрические размеры поперечного сечения второй секции не превышают диаметр первой секции. Первая секция представляет собой герметичную емкость, выполненную в форме трубы, внутри которой расположен блок связи и управления, и на внешней поверхности которой установлены по меньшей мере один датчик давления ...

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10-05-2017 дата публикации

Assessment of flow networks

Номер: GB0002544098A
Принадлежит:

A method for assessment of an oil and gas flow network comprises: (1) gathering historical data and/or live data relating to the status of multiple control points at different branches within the flow network and to one or more flow parameter(s) in one or more flow path(s) of the flow network in which flows of more than one of the different branches have been combined: (2) identifying time intervals in the data during which all of the control points and all of the flow parameters are in a steady state: and (3) extracting statistical data representative of some or all steady state intervals identified in step (2) to thereby represent the original data from step (1) in a compact form. In an alternative embodiment there is a method of assessing and oil and gas flow network which involves identifying adjustments that have been made in one or more of the control points that result in changes to one of more of the flow parameters and determining relationships between the status of the control ...

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11-07-2018 дата публикации

A downhole monitoring method

Номер: GB0002558309A
Принадлежит:

A downhole monitoring method comprising: setting a barrier 120 in a cased borehole 114, the barrier including a column of flowable sealing material, such as cement, so that pressure and fluid communication is resisted across the borehole thus separating the borehole into a lower section114a below the barrier and an upper section 114b above; bonding said column of flowable sealing material to a portion of formation 168 which defines a portion of the borehole; at least a portion of the lower section being cased with casing 118, thus defining an annulus between the surrounding formation and the casing; wherein an assembly 150 in the lower section, including: a perforating device 154; a control mechanism to control the perforating device, and comprising a wireless communication device configured to receive a wireless control signal for activating the perforating device; a pressure sensor 151; at any time, sending the wireless control signal to the wireless communication device to activate the ...

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30-01-2013 дата публикации

Reservoir pressure monitoring

Номер: GB0201222718D0
Автор:
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23-10-2013 дата публикации

Fiberoptic systems and methods detecting EM signals via resistive heating

Номер: GB0201315987D0
Автор:
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26-03-2014 дата публикации

System and method for performing an operation

Номер: GB0201402086D0
Автор:
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10-01-2018 дата публикации

Channel estimation in mud pulse telemetry

Номер: GB0201719785D0
Автор:
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19-07-2017 дата публикации

Blade-mounted sensor apparatus, systems, and methods

Номер: GB0201708936D0
Автор:
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02-08-2017 дата публикации

Method and apparatus for permanent measurement of wellbore formation pressure from an in-situ cemented location

Номер: GB0201709674D0
Автор:
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27-06-2012 дата публикации

Dual stripper rubber cartridge with leak detection

Номер: GB0201208459D0
Автор:
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31-07-2013 дата публикации

Mud sensing hole finder (MSHF)

Номер: GB0201310750D0
Автор:
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30-03-2016 дата публикации

Quatifying a reservoir volume and pump pressure limit

Номер: GB0201602565D0
Автор:
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29-08-2018 дата публикации

Riser surge protection system

Номер: GB0201811556D0
Автор:
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11-08-2021 дата публикации

Communication system for sequential liner hanger setting, release from a running tool and setting a liner top packer

Номер: GB2591956A
Принадлежит:

A communication system for sequential operation of subterranean tools involves flow based signals that are picked up with a receiver at a master controller 16, the receiver can be acoustic or a ball can be dropped on to seat 40 and a pressure signal sent to the master controller which then signals one or more slave controllers 32, that operate tools and communicate back to the master controller that the subject tool has been operated. Sensors associated with the control system gather data downloaded when the master controller is pulled out of the hole. The system can be used to set a liner hanger and release a running tool 28 and communicate that they have been activated. The liner top packer can be set with a flow-based signal to the master controller which is then removed with the running string 18.

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06-10-2010 дата публикации

In-line composition and volumetric analysis of vent gases and flooding of the annular space of flexible pipe

Номер: GB0201014015D0
Автор:
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05-02-2014 дата публикации

Apparatus and method for determining inclination and orientation of a downhole tool using pressure measurements

Номер: GB0201322495D0
Автор:
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03-08-2011 дата публикации

Method and apparatus for use in determining pressure

Номер: GB0201110455D0
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16-11-2016 дата публикации

Assement and control of centrifuge operation

Номер: GB0201616810D0
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24-10-1990 дата публикации

METHOD OF INSTALLING A WELL TOOL

Номер: GB0002206627B
Принадлежит: OTIS ENG CO, * OTIS ENGINEERING CORPORATION

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23-08-1995 дата публикации

Inductive pressure transducer

Номер: GB2286682A
Принадлежит:

An inductive pressure transducer 17 senses fluid pressure within a tubular member 13 by passing an alternating current within an inductor coil 23 to generate a magnetic field. The magnetic field passes through a gap 27 between the tubular member and the inductor coil, and into an exterior portion of the tubular member. Stress induced in the tubular member due to the pressure of the fluid therein causes variations in the electromagnetic properties of the material from which the member is made, the magnetic field passing through the member being affected by these variations in such a way that detection of the effect on the magnetic field gives a measure of the fluid pressure within the member. ...

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19-04-2000 дата публикации

Dual purpose borehole sub assembly for pressure measurement and chemical injection

Номер: GB0002342669A
Принадлежит:

Bottom hole pressure of a wellbore is monitored using a control line hydraulic tube 23, a pressure entry sub 20 and a floating isolation piston 21 having bottom hole well pressure on its lower side. The control line tube 23 leads to the surface clamped to tubing 13 and is connected to a pressure indicating gauge and pressure recording equipment. When it is required to inject chemicals downhole, the piston 21 is displaced to the bottom of sub 20 where an injection valve will be pushed open to allow the chemicals to be injected via injection point 27.

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27-02-2002 дата публикации

An underwater vehicle and sea floor station for servicing wells

Номер: GB0002365895A
Принадлежит:

At least one underwater vehicle 100 is used to service subsea wells and is housed in a sea floor station (figure 2) that may also provide power and a communications link. The vehicle may be autonomous, able to navigate between its base station and docking stations 40 adjacent the well heads 20 via a sonar or laser system or via rails (figure 7b) on the seabed. Once connected to the wellhead docking station, it may move around on a cable (101, figure 4) that supplies power and communications whilst interventions are performed in the well. Equipment for these operations may be stored in the base station and assembled by the vehicle (figures 10-17), or collected from designated drop zones (figure 6). Faulty or used equipment is returned to the surface by buoyant carriers (205, figure 4). Independent movement of the vehicle is by rechargeable battery powered thrusters 128, 130 and power and communications are supplied to the stations by cable from a surface vessel.

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16-04-2003 дата публикации

Pore pressure monitoring

Номер: GB0002380802A
Принадлежит:

A method of monitoring pore pressure, comprises the steps of:

  • (a) providing downhole in a well a sealable container,
  • (b) sealing in the container a sample of fluid at a baseline pressure and a sample of a formation having an initial pore pressure,
  • (c) measuring the change in pressure of the fluid sample, the pressure of the fluid sample and the pore pressure of the formation sample sealed in the container tending to equalise over time, and
  • (d) estimating the initial pore pressure relative to the baseline pressure from the measured change in fluid sample pressure. ...

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  • 03-02-1988 дата публикации

    Apparatus for monitoring a parameter in a well

    Номер: GB0002193239A
    Принадлежит:

    Well monitoring apparatus includes a side pocket mandrel 30 for inclusion in a well tubing string for removably receiving an instrument 38 in its offset receptacle bore 36 for monitoring at least one parameter such as pressure, temperature or the like, at a downhole location, there being an electrical conductor wire 43 extending from equipment 55 at the surface downward to the side pocket mandrel and a plug 44 in the lower end of the receptacle for electrically connecting the instrument 38 in the receptacle with the conductor wire extending from the surface so that electrical energy may be transmitted downhole to power the instrument, that the instrument may generate electrical signals representing data sensed in the well and transmit them to the surface for processing and immediate display, printout, or storage. Suitable kickover tools and running tools are also disclosed. In addition, method and means for running and installing a well device in a receptacle in a well are also disclosed ...

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    27-03-1996 дата публикации

    Coring and drilling system

    Номер: GB0002293395A
    Принадлежит:

    A core barrel has an inner tube 40 for coring and, alternately, a center plug assembly 80 for closing the throat 30 of the core bit at the bottom of the assembly for drilling in lieu of coring. The inner tube assembly 40 and plug assembly are disposable and retrievable through the drill string on a wireline using an overshot. The core bit is of a stabilized, preferably anti-whirl, design and may be a low-invasion core bit used in cooperation with a low-invasion coring shoe. A logging tool and data transmission assembly may be incorporated in the plug assembly for logging while drilling. The inner tube and centre plug are latched 32 in an outer barrel assembly 16 and rotational bearings 44 permit rotation between segments of the inner tube above and below the latch 32. The plug has cutters 90 on its face. ...

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    15-01-2003 дата публикации

    Wireless downhole measurement and control for optimizing gas lift well and field performance

    Номер: GB0002377466A
    Принадлежит:

    A method for optimizing the production of a petroleum well is provided. The petroleum well includes a borehole, a piping structure (24) positioned within the borehole, and a tubing string (26) positioned within the borehole for conveying a production fluid. Production of the well is optimized by determining a flow rate of the production fluid within the tubing string (26) and determining a lift-gas injection rate for the gas being injected into the tubing string. The flow rate and injection rate data is communicated along the piping structure of the well to a selected location (44), where the data is collected and analyzed. After analysis of the data, an optimum operating point (152) for the well can be determined.

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    03-08-2005 дата публикации

    While drilling system and method

    Номер: GB0002410513A
    Принадлежит:

    One aspect of a while drilling system 19a and method for determining downhole parameters includes a drilling tool drill collar 18 in which is positionable a retrievable while drilling tool 101 having a retrieval connector 104, a communication coupler 106 which may be an induction coupler for communication and power signals, a sensor chassis 112 having a corresponding communication coupler 109 and, positioned in the chassis, at least one sensor 116,114 adapted to measure internal and/or external parameters of the drilling tool and operatively connected to the while drilling tool via the communication couplers 106,109. The sensors may be positioned in the while drilling tool and retrievable with the drilling tool. In other aspects, a flow restrictor is used in combination with a landing collar, and there may be wireless communication between the sensors and the while drilling tool. Preferably, the system is operable in high temperature and high pressure conditions.

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    05-01-2012 дата публикации

    Apparatus and methods for improved cement plug placement

    Номер: US20120000649A1
    Принадлежит: Schlumberger Technology Corp

    A method and apparatus for making real-time measurements of downhole properties during cement plug placement. A wired placement conduit ( 30 ) is lowered downhole releasing a sensor package ( 34 ). The sensor package is capable of measuring downhole properties in real-time in the period while cement plug sets.

    Подробнее
    10-05-2012 дата публикации

    Membrane for Oil Compensation

    Номер: US20120111437A1
    Принадлежит: Schlumberger Technology Corp

    A membrane to compensate for effects on a volume of oil, the membrane is a metal capable of an elastic deformation and having a shape selected to optimize the elastic deformation in a desired manner so as to compensate for the effects on the volume of oil.

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    07-06-2012 дата публикации

    Self Adaptive Two Dimensional Least Square Filter for Distributed Sensing Data

    Номер: US20120139746A1
    Автор: Jianfeng Chen, Xudong Yang
    Принадлежит: Baker Hughes Inc

    A method, apparatus and computer-readable medium for filtering a signal from a plurality of distributed sensors is disclosed. The signal is obtained from the plurality of distributed strain sensors. A first subspace of a measurement space of the obtained signal is selected, wherein the first subspace is characterized by a step having a selected step size. An error for a filter corresponding to the first subspace is estimated and the step size when the estimated error meets a selected criterion. A second subspace characterized by a step having the adjusted step size is selected and the signal is filtered by applying a filter corresponding to the second subspace.

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    21-06-2012 дата публикации

    Method of determining reservoir pressure

    Номер: US20120158310A1
    Принадлежит: BP Corp North America Inc

    A new approach is disclosed for measuring the pressure of tight gas reservoirs, using information obtain from continuous injection prior to hydraulic fracture stimulation. The technique can be obtained utilizing either bottom-hole or surface pressure gauges and properly instrumented surface injection pumps. The analysis is completed by plotting injection and rate data in a specialized form from terms arranged in Darcy's radial flow equation to obtain a curve or trend. The key component to proper application of this technique is to obtain both baseline and one or more calibration data sets. These calibration data sets are obtained by either increasing or decreasing the injection pressure and/or rate from the baseline data. Initial reservoir pressure is assumed, but the calibration data indicates if the guess was too high or low. Accurate estimates of reservoir pressure may be obtained in a few iterations.

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    12-07-2012 дата публикации

    System and method for completion optimization

    Номер: US20120179428A1
    Принадлежит: Halliburton Energy Services Inc

    A system for completing a wellbore ( 38 ) having multiple zones. The system includes a completion ( 42 ) having a plurality of landing points defined therein positioned within the wellbore ( 38 ). A service tool is axially movable within the completion ( 42 ). The service tool is coupled to a pipe string ( 36 ) extending from the surface and selectively supported by a movable block ( 30 ) above the surface. A subsurface model is defined in a computer operably associated with the wellbore ( 38 ). The model is operable to predict the position of the service tool relative to the landing points of the completion ( 42 ) based upon a dynamic lumped mass model of the service tool and a dynamic lumped capacitance thermal model of the wellbore environment.

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    27-09-2012 дата публикации

    Sonde with integral pressure sensor and method

    Номер: US20120241218A1
    Принадлежит: Merlin Technology Inc

    Generally, a sonde, associated components and methods are described which can be used in conjunction with an inground tool having an inground tool housing that defines an inground tool cavity such that the inground tool cavity is exposed to an ambient pressure environment which surrounds the inground tool during an inground operation. A sonde housing assembly includes an exterior configuration that is receivable within the inground tool cavity. The sonde housing assembly at least partially defines a sonde interior and is further configured for receiving the pressure sensor body of a pressure sensor in a pressure sealed engagement. A sonde electronics package is supported within the sonde interior and is at least configured to receive the pressure signal and transfer a corresponding pressure signal from the sonde.

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    29-11-2012 дата публикации

    Portable gas monitor

    Номер: US20120297868A1
    Автор: Charles Elkins
    Принадлежит: Elkins Earthworks LLC

    A portable monitor used to measure landfill gas and landfill well parameters. The portable monitor includes a control unit and a measuring unit that can communicate wirelessly with one another. The control unit and/or measuring unit can include a heating arrangement to increase the temperature of one or more components in the control unit and/or measuring unit in cold environments.

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    10-01-2013 дата публикации

    Intelligent Well System And Method

    Номер: US20130008645A1
    Принадлежит: Schlumberger Technology Corp

    An intelligent well system and method has a sand face completion and a monitoring system to monitor application of a well operation. Various equipment and services may be used. In another aspect, the invention provides a monitoring system for determining placement of a well treatment. Yet another aspect of the invention is an instrumented sand screen. Another aspect is a connector for routing control lines. It is emphasized that this abstract is provided to comply with the rules requiring an abstract which will allow a searcher or other reader to quickly ascertain the subject matter of the technical disclosure. It is submitted with the understanding that it will not be used to interpret or limit the scope or meaning of the claims.

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    10-01-2013 дата публикации

    Apparatus and Method for Well Operations

    Номер: US20130008647A1
    Принадлежит: Halliburton Energy Services Inc

    A method for modifying a return fluid in a wellbore comprising disposing at least one valve along a drill pipe section of a drill string in the wellbore. At least one parameter of interest is determined at at least one location along the wellbore. At least one valve is controllably actuated to discharge at least a portion of at least one fluid from inside the drill string to an annulus in the wellbore to modify a local property of the return fluid in the annulus based at least in part on the measured parameter of interest.

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    21-03-2013 дата публикации

    Tools and Methods for Use in Completion of a Wellbore

    Номер: US20130068451A1
    Принадлежит: NCS Oilfield Services Canada Inc.

    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 ...

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    11-04-2013 дата публикации

    Wellbore influx detection with drill string distributed measurements

    Номер: US20130087388A1
    Принадлежит: Intelliserv LLC

    A method for detecting a wellbore influx with drill string distributed measurements includes obtaining a first annular measurement from a first sensor disposed on a drill string. The method also includes obtaining a second annular measurement from a second sensor disposed on the drill string and computing a gradient of a first interval defined by the first and second sensors. Finally, the method includes detecting a wellbore influx based on the gradient and the first and second annular measurements.

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    11-04-2013 дата публикации

    METHODS FOR EVALUATING INFLOW AND OUTFLOW IN A SUBTERRAEAN WELLBORE

    Номер: US20130090855A1
    Принадлежит:

    A method for evaluating inflow or outflow in a subterranean wellbore includes acquiring first and second axially spaced pressure measurements in the wellbore. The pressure measurements may then be processed to obtain an interval density of drilling fluid between the measurement locations. A tool string including a large number of axially spaced pressure sensors (e.g., four or more or even six or more) electronically coupled with a surface processor via wired drill pipe may be used to obtain a plurality of interval densities corresponding to various wellbore intervals. The interval density may be measured during static conditions or while drilling and may be further processed to compute a density of an inflow constituent in the annulus. Changes in the computed interval density with time may be used as an indicator of either an inflow event or an outflow event. 1. A method for computing a density of an inflow constituent in a subterranean wellbore , the method comprising:(a) acquiring first and second subsurface annular pressure measurements at corresponding first and second measured depths in the wellbore;(b) causing a processor to process the first and second annular pressure measurements to compute an annular interval density between the first and second measured depths in the wellbore; and(c) causing the processor to process the annular interval density and a differential flow rate to compute the density of the inflow constituent.2. The method according to claim 1 , wherein:(a) further comprises acquiring first, second, and third annular pressure measurements at corresponding first, second, and third measured depths in the wellbore;(b) further comprises causing the processor to process the first, second, and third annular pressure measurements to compute first and second annular interval densities, the first annular interval density between the first and second measured depths and the second annular interval density between the second and third measured depths; ...

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    18-04-2013 дата публикации

    SYSTEMS AND METHODS FOR DISTRIBUTED INTERFEROMETRIC ACCOUSTIC MONITORING

    Номер: US20130092371A1
    Принадлежит: Schlumberger Technology Corpotation

    This disclosure relates in general to a method and system for acoustic monitoring using a fibre optic cable. More specifically, but not by way of limitation, embodiments of the present invention provide for using an optical fiber as a distributed interferometer that may be used to monitor a conduit, wellbore or reservoir. In certain aspects, the distributed interferometric monitoring provides for accurate detection of acoustic occurrences along the fibre optic cable and these acoustic occurrences may include fluid flow in a pipeline or wellbore, processes taking place in a wellbore or pipeline, fracturing, gravel packing, production logging and/or the like. 1. A method for distributed acoustic detection or monitoring of activity , comprising:transmitting a monitoring signal through a fiber optic cable, wherein the monitoring signal comprises a pulse of a coherent beam of electromagnetic radiation where a coherence time of the coherent beam of electromagnetic radiation is equal to or longer than a time duration of the pulse, and wherein the fiber optic cable is disposed in a subterranean section of the Earth;detecting coherent Rayleigh noise generated by the transmission of the coherent beam of radiation through the fiber optic;processing the detected coherent Rayleigh noise to identify one or more acoustic occurrences in the subterranean section of the Earth; andmonitoring or detecting the activity using the identified one or more acoustic occurrences.2. The method of claim 1 , wherein the fiber optic cable is disposed along or is disposed appurtenant to at least one of a wellbore claim 1 , a cable and a pipeline.3. The method of claim 2 , wherein the cable comprises one of a power cable and a communications cable.4. The method of claim 2 , wherein the cable comprises copper.5. The method of claim 1 , wherein the activity comprises at least one of digging in the subterranean section of the Earth claim 1 , walking on a surface of the subterranean section of the Earth ...

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    02-05-2013 дата публикации

    Completion method to allow dual reservoir saturation and pressure monitoring

    Номер: US20130105150A1
    Автор: Fahad Al-Ajmi
    Принадлежит: Saudi Arabian Oil Co

    A well completion method provides for monitoring of reservoir pressure and saturation levels for two reservoirs from a single monitoring well. The well completion extends vertically through an upper and a lower reservoir. The well is cased, cemented, and perforated across the lower reservoir. A cement free zone is formed by cementing the casing string within the wellbore above an external casing packer above the upper reservoir. The casing string is perforated to allow fluid from the upper reservoir to flow through the cement free zone. A tubing string is landed and set within the casing string. The tubing string is sealed above and below the perforation at the cement free zone to prevent communication between fluid from the upper reservoir and the lower reservoir. The upper reservoir is monitored at the cement free zone, and the lower reservoir is monitored below an end of the tubing string.

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    09-05-2013 дата публикации

    METHOD FOR EFFICIENT PRESSURE AND INFLOW TESTING OF A FLUID CONTAINMENT SYSTEM THROUGH REAL TIME LEAK DETECTION WITH QUANTIFICATION OF PVT EFFECTS

    Номер: US20130111985A1
    Принадлежит: Intelliserv, LLC

    A method for testing a well system comprising providing fluid into a chamber of the system, measuring a change in fluid pressure within the chamber and measuring a temperature change of fluid within the closeable chamber. 1. A method for pressure testing a well system comprising:providing fluid into a closeable chamber of the well system;measuring in real time a change in fluid pressure within the closeable chamber using a sensor disposed within the well system; andmeasuring in real time a temperature change of fluid within the closeable chamber using a sensor disposed within the well system.2. The method of claim 1 , wherein the closeable chamber is provided with a fluid having a higher density than water.3. The method of claim 1 , wherein the closeable chamber is provided with a fluid having a density substantially equal to water.4. The method of claim 1 , wherein the closeable chamber comprises at least a portion of a drill string.5. The method of claim 1 , wherein the closeable chamber comprises at least a portion of a choke line.6. The method of claim 1 , wherein the closeable chamber comprises at least a portion of a kill line.7. The method of claim 1 , further comprising using real time pressure and temperature measurements to calculate real time pressure decay of fluid within the closeable chamber claim 1 , the calculated pressure decay arising from changes in the volume of fluid within the closeable chamber over time.8. The method of claim 4 , further comprising stabbing into a plug of the well system with the drill string to allow for fluid communication between the drill string and a volume of fluid disposed below the plug.9. The method of claim 1 , wherein the closeable chamber comprises at least a portion of a blowout preventer.10. The method of claim 9 , further comprising sealing the blowout preventer to prevent fluid communication between a drill string of the well system and an annulus adjacent to the blowout preventer.11. The method of claim 1 , ...

    Подробнее
    09-05-2013 дата публикации

    Ported packer

    Номер: US20130112408A1
    Автор: John A Oxtoby

    Disclosed is a packer that is ported to provide fluid communication through the packer between the wellbore annulus above the packer and the wellbore annulus below the packer. Such a ported packer can be used to allow for pressure testing the casing and/or for controlling a failed well.

    Подробнее
    30-05-2013 дата публикации

    DUAL DOWNHOLE PRESSURE BARRIER WITH COMMUNICATION TO VERIFY

    Номер: US20130133883A1
    Автор: Hill, JR. Thomas G.
    Принадлежит: TEJAS RESEARCH AND ENGINEERING, LLC

    Apparatus and method are provided for placing a dual pressure barrier in a vertical or horizontal well and verifying by pressure sensors in the well that the pressure barriers are operable. Communication of data from the well may be by electromagnetic or acoustic signals, and the data may be acquired on a ship near the well. 1. A dual downhole barrier assembly having a flow conduit therethrough for placement in a well , comprising:a first and a second barrier valve in the flow conduit;a first and a second packer to seal outside the flow conduit, the first packer being deeper than the second packer; anda pressure transducer and a wireless telemetry apparatus between the first and second packer for transmitting pressure data.2. The assembly of further comprising a ported sleeve disposed between the first and second barrier valve.3. The assembly of wherein the second packer is a retrievable packer and further comprising a polished bore receptacle below the second packer to allow removal of a portion of the conduit above the first packer.4. The assembly of further comprising a polished bore receptacle above the second packer.5. The assembly of wherein the first and second barrier valves are operable by a stinger prong.6. The assembly of wherein the ported sleeve is operable by a stinger prong.7. A well suspension plug claim 2 , comprising:a body having a sealing surface thereon adapted for setting in a well casing;a probe below the body containing an acoustic receiver; anda wireless telemetry pod in the body for communicating data collected below the body or on the body.8. The plug of further comprising a sensor on or below the body and below the sealing surface.9. A method for verifying pressure barriers in a well claim 7 , comprising:{'claim-ref': {'@idref': 'CLM-00001', 'claim 1'}, 'deploying the dual barrier assembly of on a work string in a single trip into the well;'}manipulating the first and second barrier valves by movement of a stinger prong; andsending ...

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    27-06-2013 дата публикации

    Downhole Packer Assembly Having a Selective Fluid Bypass and Method for Use Thereof

    Номер: US20130160996A1
    Принадлежит: Halliburton Energy Services, Inc.

    A downhole packer assembly for steam injection and casing pressure testing. The downhole packer assembly includes a housing assembly having intake and discharge ports. A seal assembly is positioned around the housing assembly between the intake and discharge ports and is operable to provide a fluid seal with a casing string. A mandrel is positioned within the housing assembly forming a micro annulus therewith and providing an internal pathway for fluid production therethrough. A valve assembly is disposed between the housing assembly and the mandrel and is operable between closed and open positions by a piston assembly such that the intake and discharge ports and the micro annulus provide a bypass passageway for steam injection around the seal assembly when the valve assembly is open and the seal assembly provides a downhole surface for pressure testing of the casing string uphole thereof when the valve assembly is closed. 1. A downhole packer assembly for steam injection and casing pressure testing , comprising:a housing assembly having intake and discharge ports;a seal assembly positioned around the housing assembly between the intake and discharge ports, the seal assembly operable to provide a fluid seal with a casing string;a mandrel positioned within the housing assembly and forming a micro annulus therewith, the mandrel providing an internal pathway for fluid production therethrough;a valve assembly disposed between the housing assembly and the mandrel; anda piston assembly disposed between the housing assembly and the mandrel, the piston assembly operable to shift the valve assembly between closed and open positions;wherein, the intake and discharge ports and the micro annulus provide a bypass passageway for steam injection around the seal assembly when the valve assembly is in the open position, andwherein, the seal assembly provides a downhole surface for pressure testing of the casing string uphole thereof when the valve assembly is in the closed position. ...

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    27-06-2013 дата публикации

    System and method for surface steerable drilling

    Номер: US20130161097A1
    Принадлежит: Hunt Energy Enterprises LLC

    A system and method for surface steerable drilling are provided. In one example, the method includes monitoring operating parameters for drilling rig equipment and bottom hole assembly (BHA) equipment for a BHA, where the operating parameters control the drilling rig equipment and BHA equipment. The method includes receiving current inputs corresponding to performance data of the drilling rig equipment and BHA equipment during a drilling operation and determining that an amount of change between the current inputs and corresponding previously received inputs exceeds a defined threshold. The method further includes determining whether a modification to the operating parameters has occurred that would result in the amount of change exceeding the defined threshold and identifying that a problem exists in at least one of the drilling rig equipment and BHA equipment if no modification has occurred to the operating parameters. The method includes performing a defined action if a problem exists.

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    04-07-2013 дата публикации

    Determination of Stick Slip Conditions

    Номер: US20130168084A1
    Автор: Conn David
    Принадлежит: SCHLUMBERGER TECHNOLOGY CORPORATION

    A method for determining stick slip conditions. The method may include disposing an operating apparatus in fluid communication with a pressure wave transmission medium. At least one pressure measurement device may be disposed at least partially within the pressure wave transmission medium and at some distance from the operating apparatus. One or more pressure waves generated by the operating apparatus may be measured within the pressure wave transmission medium with the at least one pressure measurement device and pressure measurement data may be generated therefrom. The pressure measurement data from the at least one pressure measurement device may be transmitted to a data acquisition system. The pressure measurement data may be analyzed to detect one or more stick slip conditions from one or more variations in the pressure measurement data. 1. A method for determining stick slip conditions , comprising:disposing an operating apparatus in fluid communication with a pressure wave transmission medium;disposing at least one pressure measurement device at least partially within the pressure wave transmission medium and at some distance from the operating apparatus;measuring one or more pressure waves generated by the operating apparatus within the pressure wave transmission medium with the at least one pressure measurement device and generating pressure measurement data therefrom;transmitting the pressure measurement data from the at least one pressure measurement device to a data acquisition system; andanalyzing the pressure measurement data to detect one or more stick slip conditions from one or more variations in the pressure measurement data.2. The method of claim 1 , comprising:determining at least one resonance frequency of the apparatus;analyzing telemetry signal data from the apparatus within the at least one resonance frequency to detect the one or more stick slip conditions from one or more variations in the telemetry signal data; andcomparing the one or more ...

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    18-07-2013 дата публикации

    CARBON DIOXIDE CONTENT OF NATURAL GAS FROM OTHER PHYSICAL PROPERTIES

    Номер: US20130180710A1
    Принадлежит: BAKER HUGHES INCORPORATED

    An apparatus and method are described to estimate a fraction of carbon dioxide present in a downhole fluid. The apparatus includes a carrier configured to be conveyed through a borehole penetrating the earth. The apparatus also includes a pressure sensor disposed at the carrier and configured to measure an ambient pressure of the downhole fluid and an ambient temperature sensor disposed at the carrier and configured to measure a temperature of the downhole fluid. A processor of the apparatus receives the ambient pressure and the ambient temperature measurements and solves for the fraction of carbon dioxide in the downhole fluid using a correlation function with the ambient pressure and the ambient temperature as inputs to the correlation function. 1. An apparatus for estimating a fraction of carbon dioxide present in a downhole fluid , the apparatus comprising:a carrier configured to be conveyed through a borehole penetrating the earth;a pressure sensor disposed at the carrier and configured to measure an ambient pressure of the downhole fluid;a temperature sensor disposed at the carrier and configured to measure an ambient temperature of the downhole fluid; anda processor configured to receive the ambient pressure and the ambient temperature measurements and solve for the fraction of carbon dioxide in the downhole fluid using a correlation function with the ambient pressure and the ambient temperature as inputs to the correlation function.2. The apparatus according to claim 1 , wherein the correlation equation is derived empirically from a training data set of density values by inverting a formula that provides each of the density values based on a temperature input claim 1 , a pressure input claim 1 , and a mole fraction input for every constituent in a fluid mix.3. The apparatus according to claim 1 , wherein the processor is further configured to input density to the correlation function.4. The apparatus according to claim 3 , wherein the processor is further ...

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    25-07-2013 дата публикации

    Methods for determining formation strength of a wellbore

    Номер: US20130186688A1
    Принадлежит: Schlumberger Technology Corp

    A system and a method may determine formation strength of a well. The system and the method may use pressure measurements and temperature measurements to determine controlled fracture pressures before the uncontrolled fracture pressure is reached. The system and the method may use pressure measurements and temperature measurements to determine closure stresses while drilling and may use the closure stresses with core and log measurements to optimize a hydraulic stimulation program.

    Подробнее
    15-08-2013 дата публикации

    METHOD AND APPARATUS TO MEASURE BOREHOLE PRESSURE DURING BLASTING

    Номер: US20130205888A1
    Принадлежит: Austin Powder Company

    Pressure sensors and techniques are presented in which one or more piezoelectric discs are housed in a holder structure with a hole allowing exposure of the piezoelectric disc(s) to ambient pressure within a borehole, with wiring leads passing through the holder structure for conveying an electrical signal from the piezoelectric device to an external interface circuit or for conveying an electrical signal from an internal interface circuit to an external data acquisition system. 1. A pressure sensing apparatus for measuring borehole pressure during blasting operations , comprising:a housing defining an interior cavity with at least one aperture extending from the interior cavity outside the housing;at least one piezoelectric device within the interior cavity of the housing; anda pair of wire leads electrically coupled with the piezoelectric device and extending from the interior cavity outside the housing.2. The pressure sensing apparatus of claim 1 , wherein the at least one piezoelectric device at least partially faces the at least one aperture of the housing.3. The pressure sensing apparatus of claim 1 , further comprising a filler material to protect against moisture penetration and/or to provide mechanical coupling to transfer a pressure wave to the at least one piezoelectric device.4. The pressure sensing apparatus of claim 3 , wherein the filler material comprises silicone grease.5. The pressure sensing apparatus of claim 1 , comprising a plurality of piezoelectric devices coupled with one another into a single circuit within the interior cavity of the housing.6. The pressure sensing apparatus of claim 1 , comprising an interface circuit within the interior cavity of the housing claim 1 , the interface circuit comprising:a rectifier with an input coupled with the at least one piezoelectric device and an output, andat least one capacitor coupled with the output of the rectifier;wherein the pair of wire leads is coupled with the output of the rectifier.7. The ...

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    15-08-2013 дата публикации

    METHOD FOR PREHEATING AN OIL-SATURATED FORMATION

    Номер: US20130206399A1
    Принадлежит: SCHLUMBERGER TECHNOLOGY CORPORATION

    Method for preheating an oil reservoir comprises injecting saturated or superheated steam at an initial injection pressure into a tubing placed inside a well drilled in the oil reservoir. Steam temperature at an outlet of the tubing is measured and a heat flow from the well to the oil reservoir is calculated. An optimal steam injection rate when steam quality of the injected steam at the tubing outlet becomes greater than zero, is calculated, the optimal steam injection rate ensuring compensation of the heat flow from the well to the oil reservoir with the heat of steam condensation. A steam injection rate is decreased to the calculated optimal steam injection rate value by decreasing the initial injection pressure providing constant temperature at the outlet of the tubing. 1. A method for preheating an oil reservoir comprising:injecting saturated or superheated steam at an initial injection pressure into a tubing disposed within a well traversing the oil reservoir,measuring steam temperature at an outlet of the tubing,calculating a heat flow from the well to the oil reservoir,calculating an optimal steam injection rate when steam quality of the injected steam at the tubing outlet becomes greater than zero, wherein the optimal steam injection rate ensures compensation of the heat flow from the well to the oil reservoir with the heat of steam condensation, anddecreasing a steam injection rate to the calculated optimal steam injection rate value by decreasing the initial injection pressure and providing constant temperature at the outlet of the tubing.2. The method of claim 1 , wherein the saturated or superheated steam is water steam.3. The method of claim 1 , wherein the steam temperature at the outlet of the tubing is measured constantly and continuously.4. The method of claim 1 , wherein the steam temperature at the outlet of the tubing is measured periodically.5. The method of claim 1 , wherein a steam pressure is measured at the outlet of the tubing.7. The ...

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    15-08-2013 дата публикации

    PARAMETER SENSING AND MONITORING

    Номер: US20130208259A1
    Принадлежит: Wellstream International Limited

    Apparatus and method for monitoring at least one parameter associated with an elongate structure are disclosed. The apparatus may include at least one elongate support body element arranged along a longitudinal structure axis associated with an elongate target structure; and at least one optic fibre element arranged substantially helically along a longitudinal body element axis associated with the at least one support body element. A method of manufacturing flexible pipe body is also disclosed. 1. Apparatus for monitoring at least one parameter associated with an elongate structure , comprising:at least one elongate support body element arranged along a longitudinal structure axis associated with an elongate target structure; andat least one optic fibre element arranged substantially helically along a longitudinal body element axis associated with the at least one support body element.2. The apparatus as claimed in wherein the support body element is arranged substantially straight along said a longitudinal structure axis.3. The apparatus as claimed in wherein the support body element is arranged substantially helically along said longitudinal structure axis.4. The apparatus as claimed in claim 1 , further comprising:each optic fibre element is repeatedly or continuously bonded to said at least one body element.5. The apparatus as claimed in claim 1 , further comprising:each optic fibre element is arranged about an external surface of the at least one body element.6. The apparatus as claimed in claim 1 , further comprising:each optic fibre element is arranged in a grooved region extending substantially helically about an external surface of the at least one body element.7. The apparatus as claimed in claim 1 , further comprising:the at least one body element and the at least one fibre element are arranged to allow the target structure to be subjected to a strain around a Radius R said a strain exceeding a normal breaking strain associated with the fibre element.8. ...

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    22-08-2013 дата публикации

    MULTIPLE DISTRIBUTED FORCE MEASUREMENTS

    Номер: US20130213128A1
    Автор: GLEITMAN Daniel D.
    Принадлежит:

    Methods, computer programs, and systems for detecting at least one downhole condition are disclosed. Forces are measured at a plurality of locations along the drillstring. The drillstring includes a drillpipe. At least one of the forces is measured along the drillpipe. At least one downhole condition is detected based, at least in part, on at least one measured force. 135-. (canceled)3656-. (canceled)57. A method of analyzing one or more downhole properties , comprising:receiving a plurality of measurements selected from the group consisting of force measurements, pressure measurements, acceleration measurements, and temperature measurements, wherein each of the measurements corresponds to a location along a drillstring, the drillstring comprising a drillpipe, and where at least one measurement corresponds to a location along the drillpipe;determining whether an influx has occurred, based, at least in part, on the plurality of measurements.58. The method of claim 57 , further comprising:determining the location of the influx.59. The method of claim 58 , further comprising:providing a graphical indication to an operator of the location of the influx.60. The method of claim 57 , further comprising:characterizing the influx.61. The method of claim 57 , further comprising:prompting an operator to take an action based on the influx.62. The method of claim 57 , further comprising:taking an action in response to the influx, including shutting in a borehole.63. The method of claim 57 , further comprising:taking an action in response to the influx, including adjusting a mud property.64. The method of claim 57 , further comprising:taking an action in response to the influx, including adjusting a mud flow rate.65. A measurement-while-drilling system claim 57 , comprising:a plurality of sensors to measure a plurality of measurements selected from the group consisting of forces, pressures, accelerations, and temperatures, wherein the sensors are along a drillstring, wherein at ...

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    22-08-2013 дата публикации

    METHOD FOR SIGNALLING A DOWNHOLE DEVICE IN A WELL

    Номер: US20130213644A1
    Автор: Buyers Mark, Forsyth David
    Принадлежит: OMEGA COMPLETION TECHNOLOGY LTD.

    A method and apparatus for controlling the operation of a well involves locating a pressure monitoring device downhole and arranging it to be operative: to monitor a characteristic pressure profile of a well during a certain time span controlled by a downhole clock associated with the device; to monitor the temperature downhole in the region of the clock; to calibrate a time reading of the downhole clock with reference to the monitored temperature to correct for drift between the clock time and real time resulting from the downhole elevated temperature; and to respond and generate a triggering output when a significant deviation to the pressure profile is introduced into the well as a control signal to the monitoring device, by comparing two separate pressure profiles within the time span, the device only generating the triggering output when the same pressure profile is monitored twice within the time span. 1. A method for controlling the operation of a well , the method comprising the steps of:locating a pressure monitoring device downhole; to monitor a characteristic pressure profile of the well during a certain time span; and', 'to respond and generate a triggering output when a significant deviation to the pressure profile is introduced into the well as a control signal to the monitoring device, by comparing two separate pressure profiles within the time span, the device only generating the triggering output when the same pressure profile is monitored twice within the time span;, 'arranging the pressure monitoring device so that it is operativearranging an actuator so that it is initiated into operation to control any required operation of the well when the monitoring device responds to the control signal and generates the triggering output;in which the method comprises the further steps of:arranging the pressure monitoring device to monitor the characteristic pressure profile during the specified time span controlled by a downhole clock associated with the ...

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    26-09-2013 дата публикации

    Semiconductor device and its manufacturing method thereof, mask for semiconductor manufacture, and optical proximity correction method

    Номер: US20130249597A1
    Автор: Hironobu Taoka, Yusaku Ono
    Принадлежит: Renesas Electronics Corp

    An object of the present invention is to reduce processing time and manufacturing cost for a semiconductor device including a logic circuit. To accomplish the above object, an area ( 114 ) for forming a logic circuit includes a first area ( 114 b, 170 ) which is subjected to optical proximity correction with predetermined accuracy, and a second area ( 114 a, 180 ) which is subjected to optical proximity correction with accuracy lower than said predetermined accuracy. Especially, the first area ( 114 b, 170 ) includes a gate interconnection line ( 172 ) which acts as a transistor, and the second area ( 114 a, 180 ) includes a dummy layout pattern ( 182 ) which does not act as a transistor.

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    03-10-2013 дата публикации

    MULTIPLE DISTRIBUTED PRESSURE MEASUREMENTS

    Номер: US20130256033A1
    Автор: GLEITMAN Daniel D.
    Принадлежит:

    Methods, computer programs, and systems for detecting at least one downhole condition are disclosed. Pressures are measured at a plurality of locations along the drillstring. The drillstring includes a drillpipe. At least one of the pressures is measured along the drillpipe. At least one downhole condition is detected based, at least in part, on at least one measured pressure. 1. A method of collecting and analyzing one or more pressures , comprising:measuring pressures at a plurality of locations on a drillstring, the drillstring comprising a drillpipe, and where at least one pressure is measured along the drillpipe; anddetecting at least one downhole condition based, at least in part, on at least one measured pressure.2. The method of claim 1 , where measuring pressures at a plurality of locations along a drillstring comprises:measuring at least two of the pressures substantially simultaneously.3. The method of claim 1 , where measuring pressures at a plurality of locations along a drillstring comprises:measuring at least two of the pressures in a controllable sequence.4. The method of claim 1 , further comprising:identifying at least one downhole condition.5. The method of claim 1 , further comprising:locating at least one downhole condition.6. The method of claim 1 , further comprising:characterizing at least one downhole condition.7. The method of claim 1 , where the drillstring comprises one or more drill collars claim 1 , and where measuring pressures at a plurality of locations along the drillstring comprises:measuring one or more pressures at one or more of the drill collars.8. The method of claim 1 , where the drillstring comprises an interior and an exterior claim 1 , and where measuring pressures at a plurality of locations along the drillstring comprises: the exterior of the drillstring; or', 'the interior of the drillstring., 'measuring at least one pressure along at least one of9. The method of claim 1 , where measuring pressures at a plurality of ...

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    14-11-2013 дата публикации

    SYSTEM AND METHOD FOR MONITORING STRAIN & PRESSURE

    Номер: US20130298665A1
    Принадлежит:

    A method for monitoring a well treatment, comprising the steps of installing at least one distributed acoustic strain sensor in at least one monitoring well, said monitoring well being a known distance from the treatment well, initiating a well treatment on the first well, monitoring the formation surrounding the monitoring well using the distributed acoustic strain sensor, and using the distributed acoustic strain sensor, detecting a change in strain at a first location in the monitoring well, using the change in strain to make determinations about the well treatment. The sensor may comprise a fiber optic cable. The change in strain may be used as an indicator that the effect of the well treatment has extended beyond a predetermined preferred treatment zone, the treatment may be a fracture treatment, and the well treatment may be controlled or ceased based on the determinations made in step e). 1. A method for detecting the effect of a well treatment performed in a first well , comprising the steps of:a) installing at least one distributed acoustic strain sensor in at least one monitoring well, said monitoring well being a known distance from the first well;b) initiating a well treatment on the first well;c) monitoring the formation surrounding the monitoring well using the distributed acoustic strain sensor;d) using the distributed acoustic strain sensor, detecting a change in strain or pressure at a first location in the monitoring well; ande) using the change in strain detected in step d) to make determinations about the well treatment in step b).2. The method according to wherein distributed acoustic strain sensors are installed in at least two monitoring wells.3. The method according to wherein each monitoring well is between 50 m and 5000 m from the first well.4. The method according to wherein the distributed acoustic sensor comprises a fiber optic cable.5. The method according to wherein the change in strain detected in step d) indicates that the effect of ...

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    21-11-2013 дата публикации

    TEMPERATURE SENSOR USING AN OPTICAL FIBER

    Номер: US20130308680A1
    Принадлежит: LxData Inc.

    A method for measuring a physical parameter at a plurality of spaced locations in a subterranean formation using a temperature sensor that has an elongated sensing element having a length of at least 10 m, measured at a temperature of 20° C. The elongated sensing element includes an elongated jacket and an optical fiber mounted in the jacket and having an EFL of at least 0.35%, wherein the elongated sensing element has an average temperature error of less than 2° C. 2. The method as defined in claim 1 , wherein the parameter S is at least 6.25 mmper percent of EFL.3. The method as defined in claim 2 , wherein the parameter S is at least 10 mmper percent of EFL.4. The method as defined in claim 1 , wherein temperature in the well is at least 200 degrees C.5. The method as defined in claims 1 , wherein the optical fiber has a length of at least 100 m.6. The method as defined in claim 1 , wherein the excess fiber length EFL at 20 degrees Celsius is at least 0.35%.7. The method as defined claim 1 , wherein the excess fiber length EFL at 20 degrees Celsius is at least 0.50%.8. The method as defined in claim 1 , wherein the optical path manifesting an interaction with the optical signal to produce the response claim 1 , the interaction occurring only at a plurality of discrete areas spaced apart along the optical fiber and corresponding to the plurality of spaced apart locations.9. The method as defined claim 1 , wherein the ratio CTE/CTEis at least 10. This application is a divisional application of U.S. patent application Ser. No. 13/419,966 filed Mar. 14, 2012, which is a continuation application of U.S. patent application Ser. No. 13/342,499 filed Jan. 3, 2012, which application is a continuation application of U.S. patent application Ser. No. 12/257,906 filed Oct. 24, 2008, which application claims priority to U.S. Provisional Application No. 60/986,766 filed Nov. 9, 2007, the entire contents of which are hereby incorporated by reference in their entirety.The ...

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    21-11-2013 дата публикации

    METHODS AND SYSTEMS FOR TESTING THE INTEGRITY OF COMPONENTS OF A HYDROCARBON WELL SYSTEM

    Номер: US20130311093A1
    Принадлежит: BP CORPORATION NORTH AMERICA INC.

    A component of the hydrocarbon well system and a first supply line to the component can be isolated from other components of the hydrocarbon well system. The component and the first supply line can be pressurized to a test pressure with a test fluid. Then, a pressure and a temperature of the test fluid in the component that was pressurized can be measured over a period of time. The pressure and the temperature that were measured can be analyzed and a pressure integrity of the component can be determined based on the analysis. 1. A computer-implemented method for testing components of a hydrocarbon well system , comprising:isolating a component of the hydrocarbon well system and a first supply line to the component from other components of the hydrocarbon well system;pressurizing the component and the first supply line to a test pressure with a test fluid;measuring, over a period of time, a pressure and a temperature of the test fluid in the component that was pressurized;analyzing, by a processor, the pressure and the temperature that were measured; anddetermining a pressure integrity of the component based on the analysis.2. The computer-implemented method of claim 1 , the method further comprising:testing a pressure integrity of the first supply line prior to pressurizing the first supply line.3. The computer-implemented method of claim 1 , wherein the component of the hydrocarbon well system comprises at least one of a well head and a portion of a blowout preventer.4. The computer-implemented method of claim 1 , wherein the first supply line comprises a kill line or a choke line.5. The computer-implemented method of claim 1 , wherein analyzing the pressure and the temperature comprises:determining that the pressure and the temperature has reached a steady state.6. The computer-implementing method of claim 1 , wherein isolating the component and the first supply line comprises:closing one or more valves in the hydrocarbon well system.7. The computer-implementing ...

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    12-12-2013 дата публикации

    Method For Measuring Pressure In An Underground Formation

    Номер: US20130327137A1
    Автор: VENTRE Pierre
    Принадлежит: TOTAL S.A.

    The invention relates to a method for measuring pressure in an underground formation containing a fluid, comprising the following consecutive steps: 1. A method for measuring pressure in an underground formation containing a fluid , comprising the following consecutive steps:establishing fluid communication between a test chamber arranged in a drilling well and the underground formation, via a flowline;moving a piston in the test chamber so as to suction fluid into the test chamber;ensuring fluid isolation of the test chamber relative to the flowline;measuring the pressure in the flowline; andrepeating the preceding steps.2. The method according to claim 1 , wherein the fluid isolation of the test chamber is done by closing at least one valve between the flowline and the test chamber claim 1 , and establishing the fluid communication between the test chamber and the underground formation by opening said valve.3. The method according to claim 1 , which is implemented using a downhole well tool arranged in the drilling well.4. The method according to claim 3 , wherein the downhole well tool includes a plurality of test chambers claim 3 , the method including a preliminary step for choosing a test chamber.6. The method according to claim 5 , wherein the choice of the flow rate is made in a flow rate range comprised between a minimum flow rate and a maximum flow rate claim 5 , the ratio of the maximum flow rate to the minimum flow rate being greater than or equal to 10.7. A method for determining the permeability of the underground formation or determining the mobility of the fluid of the underground formation claim 1 , comprising a pressure measurement according to the method of claim 1 , and calculating the permeability of the underground formation or the mobility of the fluid of the underground formation from the result of the pressure measurement.8. A device for measuring pressure in an underground formation containing a fluid claim 1 , comprising:at least one test ...

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    12-12-2013 дата публикации

    FLUID DISTRIBUTION DETERMINATION AND OPTIMIZATION WITH REAL TIME TEMPERATURE MEASUREMENT

    Номер: US20130327522A1
    Принадлежит: Halliburton Energy Services, Inc.

    Fluid distribution determination and optimization using real time temperature measurements. A method of determining fluid or flow rate distribution along a wellbore includes the steps of: monitoring a temperature distribution along the wellbore in real time; and determining in real time the fluid or flow rate distribution along the wellbore using the temperature distribution. A method of optimizing fluid or flow rate distribution includes the steps of: predicting in real time the fluid or flow rate distribution along the wellbore; comparing the predicted fluid or flow rate distribution to a desired fluid or flow rate distribution; and modifying aspects of a wellbore operation in real time as needed to minimize any deviations between the predicted and desired fluid or flow rate distributions. 17-. (canceled)8. A method of optimizing fluid distribution along a wellbore , the method comprising the steps of:predicting in real time the fluid distribution along the wellbore;comparing the predicted fluid distribution to a desired fluid distribution; andmodifying aspects of a wellbore operation in real time as needed to minimize any deviations between the predicted and desired fluid distributions.9. The method of claim 8 , further comprising the step of monitoring a temperature distribution along the wellbore in real time claim 8 , and wherein the predicting step further comprises predicting the fluid distribution along the wellbore using the temperature distribution.10. The method of claim 8 , further comprising the steps of monitoring a temperature distribution along the wellbore in real time claim 8 , and determining a current fluid distribution along the wellbore using the temperature distribution.11. The method of claim 8 , wherein the predicting step further comprises inputting a real time temperature distribution along the wellbore to a predictive device claim 8 , so that the predictive device predicts the fluid distribution.12. The method of claim 11 , wherein the ...

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    02-01-2014 дата публикации

    PORE PRESSURE MEASUREMENT IN LOW-PERMEABILITY AND IMPERMEABLE MATERIALS

    Номер: US20140000358A1
    Принадлежит: SCHLUMBERGER TECHNOLOGY CORPORATION

    Systems and methods are described for calculating pore pressure in a porous formation such as shale gas having substantially disconnected pore spaces. In some described examples, an NMR logging tool with at least two depths of investigation (DOIs) is used. The deeper DOI can be used to sample the shale gas that has not been perturbed by the drilling process, for example, and contains the gas at connate pressure. The shallow DOI can be used to sample shale gas that has been perturbed, and has lost at least part of its gas content. The micro cracks that have been formed in the shallow location (closer to the borehole) allow for injection of gas into the formation at known pressures while measuring the NMR response. The connate pore pressure can then be calculated for the deeper location based on the NMR response to the known pressure increase. 1. A method for determining pore pressure in a porous formation having substantially disconnected pore spaces , the method comprising:processing a first signal depending on pore pressure at a first location in the formation at which the pore spaces are not substantially interconnected;processing a second signal depending on pore pressure at a second location in the formation at which the pore spaces are substantially interconnected;inducing a known change in pressure at the second location;processing a third signal depending on pore pressure at the second location under the induced pressure change; anddetermining a pore pressure associated with the first location based at least in part on a comparison involving the first, second and third processed signals and the known pressure change.2. A method according to wherein the porous formation is a shale gas formation.3. A method according to wherein the porous formation is a tight gas formation.4. A method according to wherein the tight gas formation is a carbonate formation.5. A method according to wherein the determined pore pressure is a gas pressure.6. A method according to ...

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    09-01-2014 дата публикации

    High Temperature Downhole Gauge System

    Номер: US20140007668A1
    Автор: Shanks David Sirda
    Принадлежит:

    A gauge system and method for monitoring well pressure at temperatures in excess of 300° C. used in permanent monitoring of oil and gas wellbores. The gauge system includes an analogue output transducer and a long cable which is an extruded mineral insulated multi-core cable with a seam welded corrosion resistant metal outer sheath. The transducer is enclosed in a pressure tight corrosion resistant housing and the housing is pressure sealed to the metal outer sheath. The method includes applying signal conditioning and processing to the measurements to compensate for characteristics of the transducer, the cable and the environment and thereby provide continuous monitoring of the wellbore. 1. A gauge system for use in wellbores , the system comprising an analogue output transducer and a long cable , wherein the cable is an extruded mineral insulated multi-core with a seam welded corrosion resistant metal outer sheath; the transducer is enclosed in a pressure tight corrosion resistant housing; and the housing is pressure sealed to the metal outer sheath.2. A gauge system according to wherein the transducer is an analogue output pressure sensor.3. A gauge system according to wherein the pressure sensor is a silicon-on-insulator sensor.4. A gauge system according to wherein the pressure sensor is a strain wire type using ceramic mounting.5. A gauge system according to wherein the sensor is configured in a Wheatstone bridge arrangement.6. A gauge system according to wherein the cable comprises at least one elongate electrical conductor within a metal sheath claim 1 , the conductor being insulated from the sheath by means of a compacted mineral insulating powder.7. A gauge system according to wherein the cable includes a further sheath of corrosion resistant metal claim 5 , wrapped as a thin strip around the cable and seam welded.8. A gauge system according to wherein the cable is drawn down to a diameter of approximately 0.25 inch.9. A gauge system according to wherein ...

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    23-01-2014 дата публикации

    ADVANCED INGROUND OPERATIONS, SYSTEM AND ASSOCIATED APPARATUS

    Номер: US20140020953A1
    Принадлежит: Merlin Technology, Inc

    Systems, apparatus and methods are described for purposes of initiating a response to detection of an adverse operational condition involving a system including a drill rig and an inground tool. The response can be based on an uphole sensed parameter in combination with a downhole sensed parameter. The adverse operational condition can involve cross-bore detection, frac-out detection, excessive downhole pressure, a plugged jet indication and drill string key-holing detection. A communication system includes an inground communication link that allows bidirectional communication between a walkover detector and the drill rig via the inground tool. Monitoring of inground tool depth and/or lateral movement can be performed using techniques that approach integrated values. Bit force based auto-carving is described in the context of an automated procedure. 1. A method for use in conjunction with a horizontal directional drilling system that includes a drill string that extends from a drill rig to an inground tool such that extension and retraction of the drill string generally produces corresponding movements of the inground tool during an inground operation , said drill string defining a through passage for carrying a pressurized flow of drilling mud from the drill rig to the inground tool for emission from the inground tool , said method comprising:during the inground operation, monitoring an annular mud pressure in the ground surrounding the inground tool;detecting a change in the annular mud pressure; andinitiating a response based at least in part on detecting said change as being indicative of one of a potential cross-bore and a potential frac-out.2. The method of wherein said detecting detects a decrease in the annular mud pressure.3. The method of wherein said response includes issuing a warning to indicate one of a potential cross-bore and a potential frac-out.4. The method of wherein said warning is issued to indicate a potential cross-bore and issuing requires ...

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    23-01-2014 дата публикации

    Advanced inground operations, system, communications and associated apparatus

    Номер: US20140022088A1
    Принадлежит: Merlin Technology Inc

    Systems, apparatus and methods are described for purposes of initiating a response to detection of an adverse operational condition involving a system including a drill rig and an inground tool. The response can be based on an uphole sensed parameter in combination with a downhole sensed parameter. The adverse operational condition can involve cross-bore detection, frac-out detection, excessive downhole pressure, a plugged jet indication and drill string key-holing detection. A communication system includes an inground communication link that allows bidirectional communication between a walkover detector and the drill rig via the inground tool. Monitoring of inground tool depth and/or lateral movement can be performed using techniques that approach integrated values. Bit force based auto-carving is described in the context of an automated procedure. Loss of locator to drill rig telemetry can trigger an automated switch to a different communication path within the system.

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    30-01-2014 дата публикации

    Active seismic monitoring of fracturing operations & determining characteristics of a subterranean body using pressure data and seismic data

    Номер: US20140027111A1
    Принадлежит: WESTERNGECO LLC

    A method for managing a fracturing operation. In one implementation, the method may include positioning one or more sources and one or more receivers near a hydrocarbon reservoir; pumping a fracturing fluid into a well bore of the hydrocarbon reservoir; performing a survey with the sources and the receivers during the fracturing operation; comparing the baseline survey to the survey performed during the fracturing operation; analyzing one or more differences between the baseline survey and the survey performed during the fracturing operation; and modifying the fracturing operation based on the differences.

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    30-01-2014 дата публикации

    Systems and methods for reducing pvt effects during pressure testing of a wellbore fluid containment system

    Номер: US20140027113A1
    Принадлежит: Intelliserv LLC

    A system for pressure testing a component of a well system includes a tubular member extending into a wellbore. The tubular member has a fluid passageway and one or more nodes that are configured to measure fluid pressure. The system also includes a heat exchanger configured to cool a fluid passing therethrough.

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    30-01-2014 дата публикации

    Retrievable flow module unit

    Номер: US20140027125A1
    Принадлежит: Cameron International Corp

    A retrievable flow module (RFM) apparatus is provided. In one embodiment, the RFM apparatus is a standalone assembly configured to mate with a subsea device, such as a production tree. The RFM apparatus may include a frame within which various flow control and monitoring elements are disposed. The frame may have an alignment system that enables the RFM apparatus to horizontally mate with the tree. Because the RFM apparatus provides for the collocation of flow control and monitoring elements within a standalone assembly, deployment or retrieval of the flow control and monitoring elements may be accomplished in single operation. Additional systems, devices, and methods are also disclosed.

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    13-02-2014 дата публикации

    Hydraulic Position Indicator System

    Номер: US20140041861A1
    Принадлежит: M-I L.L.C.

    A system useful for monitoring or controlling the back pressure of fluid in a wellbore is disclosed. The system may include: a choke assembly including: a housing having an inlet, an outlet, and a bore; a choke member disposed in the bore for controlling a flow of a fluid from the inlet to the outlet, and a rod coupled to the choke member and extending through the housing; a cylinder including: a housing having an axial bore; a piston, directly or indirectly coupled to the rod, disposed in the axial bore and separating the axial bore into a first chamber and a second chamber; a position indicating device fluidly coupled to the second chamber, wherein a change in volume of fluid in the second chamber causes a corresponding change in volume of fluid in the position indicating device, thereby indicating a change in the position of the choke member. 1. A method of monitoring or controlling one or more operating pressures within a subterranean borehole that includes a choke assembly comprising a housing having an inlet , an outlet , a bore , a choke member disposed in the bore for controlling a flow of a fluid from the inlet to the outlet , and a rod coupled to the choke member and extending through the housing , the method comprising: a housing having an axial bore;', 'a first piston disposed in the axial bore and separating the axial bore into a first chamber and a second chamber;, 'providing a cylinder comprisingdirectly or indirectly coupling the rod of the choke assembly to the piston;fluidly coupling the second chamber to a position indicating device, wherein movement of the choke member causes a corresponding movement in the rod and the first piston, resulting in a change in a volume of fluid in the second chamber and a corresponding change in a volume of fluid in the position indicating device, thereby indicating a change in the position of the choke member; anddetermining a position of the choke member using the position indicating device.2. The method of claim ...

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    27-02-2014 дата публикации

    PRESSURE MEASUREMENT IN HIGHLY DEVIATED WELLS

    Номер: US20140054029A1
    Автор: SHAW Joel D.
    Принадлежит: Halliburton Energy Services, Inc.

    A pressure measurement system for use with a subterranean well can include a chamber positioned in the well, the chamber having an upper portion and a lower portion as positioned in the well, and a device which, in response to gravity acting on the device, selects the upper portion of the chamber for communication with a line extending to a remote location. A method of measuring pressure in a well can include introducing a chamber into the well, then selecting a vertically upper portion of the chamber, and establishing communication between the upper portion of the chamber and a line extending to a remote location. 1. A pressure measurement system for use with a subterranean well , the system comprising:a chamber positioned in the well, and the chamber having an upper portion and a lower portion as positioned in the well; anda device which, in response to gravity acting on the device, selects the upper portion of the chamber for communication with a line extending to a remote location.2. The system of claim 1 , wherein the device selectively blocks less than all of multiple vertically distributed communication ports.3. The system of claim 1 , wherein the device selectively prevents opening of less than all of multiple vertically distributed communication ports.4. The system of claim 1 , wherein the device selectively prevents discharge of plugs from less than all of multiple vertically distributed communication ports.5. The system of claim 1 , wherein communication between the line and the upper portion of the chamber is established in response to application of increased pressure to the line.6. The system of claim 5 , wherein less than all of multiple vertically distributed communication ports is opened in response to application of the increased pressure to the line.7. The system of claim 1 , wherein the lower portion of the chamber is selected in the well.8. The system of claim 7 , wherein communication between a wellbore and the lower portion of the chamber is ...

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    20-03-2014 дата публикации

    Downhole Heater Assembly and Power Line Communications System

    Номер: US20140076545A1
    Принадлежит: DH THERMAL LLC

    A hydrocarbon heating system comprises a surface control panel and a subsurface heating system, connected by an external power cable which also serves as the data communication link between the two parts. The subsurface heating system includes a heating element and two separate, thermally isolated temperature sensors. One thermal sensor, mounted near the heating element, monitors the temperature of the heating element. Another thermal sensor monitors the ambient temperature of fluid in the borehole. The temperature of the heating element may be varied to maintain an optimal well temperature for the production of hydrocarbons. Downhole electronics convert the thermal sensor outputs to digital data, and modulate the digital data onto a power cable that carries power from the surface to the heating element. A control system at the surface controls the heating element via nested control loops monitoring the temperatures of the borehole fluid and the heating element. 1. A downhole hydrocarbon heating system operative to heat hydrocarbon fluids in an oil or gas well comprising a borehole , the system comprising:a surface control panel; a heating element;', 'a first thermal sensor operative to sense the temperature of the heating element; and', 'a second thermal sensor operative to sense the ambient temperature of fluid in the borehole; and, 'a subsurface heating system operative to be deployed down the borehole and including'}a power cable connecting the surface control panel and the subsurface heating system, the power cable operative to selectively carry power from the surface control panel to the heating element, and further operative to carry temperature data from the first and second thermal sensors to the surface control panel.2. The system of wherein the heating element and the first thermal sensor are disposed in a lower housing operative to be deployed in the borehole at the depth of a hydrocarbon production zone.3. The system of wherein the heating element is ...

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    20-03-2014 дата публикации

    Single Trip Multi-Zone Drill Stem Test System

    Номер: US20140076546A1
    Автор: Patel Dinesh
    Принадлежит: SCHLUMBERGER TECHNOLOGY CORPORATION

    A drill stem test string may include a tubular body having an axial bore formed at least partially therethrough. An axial flow valve may be coupled to the first tubular body and allow fluid to flow axially through the first tubular body when in an open state and prevent fluid from flowing axially through the first tubular body when in a closed state. A radial flow valve may be coupled to the first tubular body and allow fluid to flow radially through the first tubular body when in an open state and prevent fluid from flowing radially through the first tubular body when in a closed state. A seal assembly may be coupled to an outer surface of the first tubular body and positioned between a lower end of the first tubular member and the first radial flow valve. 1. A drill stem test string , comprising:a first tubular body having an axial bore formed at least partially therethrough;an axial flow valve coupled to the first tubular body and adapted to allow fluid to flow axially through the first tubular body when in an open state and to prevent fluid from flowing axially through the first tubular body when in a closed state;a first radial flow valve coupled to the first tubular body and adapted to allow fluid to flow radially through the first tubular body when in an open state and to prevent fluid from flowing radially through the first tubular body when in a closed state; anda seal assembly coupled to an outer surface of the first tubular body and positioned between a lower end of the first tubular member and the first radial flow valve.2. The drill stem test string of claim 1 , further comprising:a second tubular body disposed radially outward from the first tubular body, wherein a lower end of the second tubular body is positioned above a lower end of the first tubular body; anda second radial flow valve coupled to the first tubular body and adapted to allow fluid to flow radially through the first tubular body when in an open state and to prevent fluid from flowing ...

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    20-03-2014 дата публикации

    MULTIPHASE FLOWMETER FOR SUBSEA APPLICATIONS

    Номер: US20140076547A1
    Принадлежит: WEATHERFORD/LAMB, INC.

    Multiphase flow measurement in extreme environments such as subsea or in-well is a difficult task for many reasons including reliability, survivability, and longevity issues; accessibility to the equipment; and complexity of the varying flow field as a function of position and time. Embodiments of the present invention provide techniques and apparatus for performing subsea multiphase flow measurement by combining two technologies. One is based on infrared water-cut measurement technology which is capable of measuring water and oil concentrations in multiphase flow with up to 99.5% gas volume fractions. The second technology is based on in-well fiber-optic flow measurement capable of resolving gas and total liquid flow through the measurements of flow velocity, fluid mixture speed of sound, and absolute pressure and temperature at meter location. This hybrid system represents an approach to subsea multiphase metering that may offer advantages compared to traditional systems for some applications. 1. A system for calculating at least one of phase fractions or phase flow rates of a fluid mixture in a well , comprising:{'sub': 'ss', 'a water detector configured to measure a subsea water-in-liquid ratio (WLR) of the fluid mixture;'} measure a speed of sound (SoS) through the fluid mixture; and', 'determine a bulk flow velocity of the fluid mixture in a conduit disposed in the well;, 'an optical flowmeter located in the well and configured to measure an in-situ pressure in the well; and', 'measure an in-situ temperature in the well; and, 'a pressure/temperature (P/T) gauge configured to [{'sub': in-situ', 'ss, 'calculate an in-situ WLR (WLR) based on the WLR, the in-situ pressure, the in-situ temperature, and a pressure/volume/temperature (PVT) model;'}, {'sub': 'in-situ', 'determine a liquid hold-up (HL) of the fluid mixture based on the SoS and WLR;'}, {'sub': 'in-situ', 'determine a density of the fluid mixture based on the HL and WLR; and'}, {'sub': 'in-situ', ' ...

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    20-03-2014 дата публикации

    METHOD TO PREDICT OVERPRESSURE UNCERTAINTY FROM NORMAL COMPACTION TRENDLINE UNCERTAINTY

    Номер: US20140076632A1
    Принадлежит: BAKER HUGHES INCOROPORATED

    A method for predicting a pressure window for drilling a borehole in a formation includes: obtaining a pore pressure related data value of the formation using a data acquisition tool; predicting pore pressure uncertainty from the pore pressure related data value of the formation using a processor; estimating uncertainty of a pressure window for drilling fluid using the predicted pore pressure uncertainty using a processor; and applying the estimated uncertainty to the pressure window to provide a modified pressure window using a processor. 1. A method for predicting a pressure window for drilling a borehole in a formation , the method comprising:obtaining a pore pressure related data value of the formation using a data acquisition tool;predicting pore pressure uncertainty from the pore pressure related data value of the formation using a processor;estimating uncertainty of a pressure window for drilling fluid using the predicted pore pressure uncertainty using a processor; andapplying the estimated uncertainty to the pressure window to provide a modified pressure window using a processor.2. The method according to claim 1 , further comprising defining an operating margin and applying the operating margin to the modified pressure window to provide an operating pressure window using a processor.3. The method according to claim 2 , further comprising monitoring at least one equivalent of drilling fluid pressure and determining if the monitored drilling fluid pressure equivalent is within equivalents of an upper bound and a lower bound of the operating pressure window.4. The method according to claim 2 , further comprising:defining a drilling parameter for drilling a borehole in the formation within the operating pressure window using a processor; anddrilling into the formation using a drilling tool and the operating pressure window for the drilling fluid.5. The method according to claim 4 , wherein the drilling parameter comprises at least one of a drilling fluid ...

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    27-03-2014 дата публикации

    Snorkel Tube with Debris Barrier for Electronic Gauges Placed on Sand Screens

    Номер: US20140083178A1
    Принадлежит:

    A sensing system comprises at least one gauge disposed in a wellbore, a sensing link coupled to the at least one gauge, and a debris barrier coupled to the sensing link. The debris barrier comprises a housing coupled to the sensing link, and a barrier element configured to reduce the transport of particulates from the wellbore into the sensing link. 1. A sensing system comprising:at least one gauge disposed in a wellbore;a sensing link coupled to the at least one gauge; and a housing coupled to the sensing link; and', 'a barrier element configured to reduce the transport of particulates from the wellbore into the sensing link., 'a debris barrier coupled to the sensing link, wherein the debris barrier comprises2. The sensing system of claim 1 , further comprising a filter element disposed in the wellbore claim 1 , wherein the debris barrier is disposed radially adjacent the filter element.3. The sensing system of claim 1 , wherein the sensing system further comprises at least one gauge carrier configured to retain the at least one gauge about a wellbore tubular.4. The sensing system of claim 1 , further comprising a communication medium disposed in at least one of the sensing link or the housing.5. The sensing system of claim 4 , wherein the communication medium is configured to prevent fluid mixing within at least one of the housing or the sensing link claim 4 , and wherein the communication medium is configured to communicate a pressure from the wellbore adjacent the debris barrier to the at least one gauge.6. A method of sensing in a wellbore comprising:communicating a pressure from a wellbore to at least one gauge through a sensing link;reducing the flow of particulates into the sensing link using a debris barrier, wherein the pressure communicates through the debris barrier; andsensing the pressure using the at least one gauge.7. The method of claim 6 , wherein the debris barrier and the at least one gauge are axially separated.8. The method of claim 6 , wherein ...

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    01-01-2015 дата публикации

    Formation dip geo-steering method

    Номер: US20150000980A1
    Автор: Danny T. Williams
    Принадлежит: Individual

    A geo-steering method for drilling a formation penetrated by multiple wells. The method comprises computing a stratigraphic target formation window, computing a target line utilizing an instantaneous formation dip angle correlated to offset well data from an offset well. The method further comprises calculating a target window from actual drilling data overlaying the target window over the stratigraphic target formation window to drill on the target line, identifying target deviation from target line using overlaid windows, generating a target deviation flag when the overlaid results differ above or below the stratigraphic target formation window or user inputted target deviation flag parameters, wherein the target deviation flag stops drilling by the rig. The method performs another actual survey, creating a new window, starting drilling, creating a new target window, overlaying the two windows and monitoring for target deviations, repeating the process until target depth is reached.

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    06-01-2022 дата публикации

    Methods for assessing the reliability of hydraulically-actuated devices and related systems

    Номер: US20220003112A1
    Принадлежит: Transocean Innovation Labs Ltd

    This disclosure includes methods for testing hydraulically-actuated devices and related systems. Some hydraulically-actuated devices have a housing defining an interior volume and a piston disposed within the interior volume and dividing the interior volume into a first chamber and a second chamber, where the piston is movable relative to the housing between a maximum first position and a maximum second position in response to pressure differentials between the first and second chambers. Some methods include: (1) moving the piston to the first position by varying pressure within at least one of the first and second chambers such that pressure within the second chamber is higher than pressure within the first chamber; and (2) while the piston remains in the first position: (a) reducing pressure within the second chamber and/or increasing pressure within the first chamber; and (b) increasing pressure within the second chamber and/or decreasing pressure within the first chamber.

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    05-01-2017 дата публикации

    SIDE AND BOTTOM WATER LAYER THERMAL RECOVERY METHOD ALLOWING ELECTRICALLY HEATING OIL DEPOSIT IN HORIZONTAL WELL

    Номер: US20170002637A1
    Автор: Wang Yigang, YU Wenying
    Принадлежит:

    Thermal recovery method via electrically heating edge- and bottom-water layer by horizontal wells is presented. Edge- and bottom-water layer is electrically heated by using a plurality of horizontal wells that are located at the upper part of edge- and bottom-water layer, so that the temperature of the whole oil deposit is increased to a state in which in-place oil can flow, by using the theory of centralized heat supply to improve the thermal recovery efficiency. Also disclosed is an electric heating structure for a horizontal well. The electric heating structure is provided with a sieve pipe. A plurality of ferromagnetic permanent magnets is deployed at the upper part of the inner side of the sieve pipe. Spring-shaped electric heating rods serially connected together are disposed in the middle. A heat separation board is disposed in the position of a horizontal diameter. A half lower sieve pipe is sealed and is hollow and jointly separate heat in combination with the heat separation board, and the down transfer of heat energy is reduced. 1. One thermal recovery method via electrically heating edge- and bottom-water layers , and the electrical heaters are settled in the horizontal wells so that the water layers could be electrically evenly heated until the temperature of the whole reservoir rises up to what needed for in-place oil to flow , the in-place oil could be thermally recovered; which is different from the method of partially heating oil layer at present.2. The structure design characteristic of electrical heater of the horizontal well is that several ferrite permanent magnet bars are fixed at the top of the inner liner and the spring electrical heating bars with series connection are set in the middle part; heat insulation board is set at the horizontal diameter of the liner; the lower liner , in cooperation with heat insulation board to insulate heat , is sealed in vacuum to reduce the downward transmission of thermal energy.31. According to the thermal ...

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    05-01-2017 дата публикации

    Predicting Pump Performance in Downhole Tools

    Номер: US20170002644A1
    Принадлежит:

    Systems, methods, and devices for predicting pump performance in a downhole tool are provided. A pump performance predictor may receive inputs and generate outputs that predict the performance of a pump of a pumpout module of a downhole tool. The pump performance predictor may calculate and output a set of first predictions that include, for example, the minimum alternator voltage of a power module used to power the electronics of the pumpout module, the maximum pump flowrate, the pumpout performance, and the achievable formation mobility. The pump performance predictor may also calculate and output a set of second predictions that may include, for example, a pump volume efficiency, a pressure profile in a flowline, the number of strokes to fill a sampling bottle, and the time to fill the sampling bottle. 1. A method , comprising:obtaining a plurality of operating conditions associated with a pump of a downhole tool configured to be operated in a wellbore of a well, the pump coupled to a flowline and a sample bottle for obtaining a sample of a formation fluid; anddetermining, from the plurality of operating conditions, predictions associated with performance of the pump, the predictions comprising at least one of a minimum power source voltage, a maximum pump flow rate, a pumpout performance estimate, and an achievable formation mobility.2. The method of claim 1 , wherein the predictions comprise first predictions claim 1 , the method comprising:obtaining a type of the formation fluid, one or more wellbore properties associated with the wellbore, and one or more formation properties associated with the formation; anddetermining based at least in part on the formation fluid type, the one or more wellbore properties, the one or more formation properties, and a pump flow rate at a selected achievable formation mobility, second predictions associated with performance of the pump, the second predictions comprising at least one of: a volume efficiency of the pump, a ...

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    05-01-2017 дата публикации

    CARRIER ROD FOR AN OPTICAL FIBER ASSEMBLY AND SYSTEM FOR MONITORING DEFORMATION OF WELL EQUIPMENT

    Номер: US20170002645A1
    Принадлежит:

    A carrier rod having at least one recess extending along at least part of the length of the rod, in which recess a optical fiber assembly for monitoring strain, temperature and/or other physical parameters is arranged, which optical fiber assembly is along at least part of its length bonded within the recess. The carrier rod can be used in a system or a method of monitoring deformation and other characteristics of a casing or other tubular or cylindrical well equipment in a well traversing an underground formation. 120.-. (canceled)21. A carrier rod for lowering an optical fiber assembly into a well , said carrier rod having at least one recess extending along at least part of the length of the rod , the recess having an outer width , in which recess an optical fiber assembly for monitoring strain , temperature or other physical parameters is arranged , which optical fiber assembly is along at least part of the optical fiber assembly's length bonded within the recess with a filler , whereby the filler surrounding the optical fiber assembly and the carrier rod is surrounded by two layers of protective coatings of which an inner layer is in contact with the filler across the full recess outer width.22. The carrier rod of secured at a plurality of locations distributed along the length of the carrier rod to a casing claim 21 , a sandscreen claim 21 , an electrical heater or other tubular or cylindrical well equipment.23. The carrier rod of claim 22 , wherein the carrier rod comprises a material having similar thermal expansion claim 22 , and mechanical properties as the casing claim 22 , sandscreen claim 22 , electrical heater or other well equipment.24. The carrier rod of claim 22 , wherein the carrier rod is made of the same material as the casing claim 22 , sandscreen or other well equipment.25. The carrier rod of claim 22 , wherein the carrier rod is secured to a tubular piece of well equipment by filling at least part of an annular space between an outer surface ...

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    05-01-2017 дата публикации

    Detecting Gas in a Wellbore Fluid

    Номер: US20170002646A1
    Принадлежит:

    A downhole gas detection tool includes a housing; a first test module that includes a first fluid test chamber operable to fluidly couple to an annulus of a wellbore to receive a first portion of a wellbore fluid, the first test module further including an acoustic fluid sensor to measure a fluid acoustic velocity and attenuation of the first portion of the wellbore fluid received in the first fluid test chamber, and a fluid resistivity sensor to measure a fluid resistivity of the first portion of the wellbore fluid received in the first fluid test chamber; and a second test module including a second fluid test chamber operable to fluidly couple to the annulus of the wellbore to receive a second portion of the wellbore fluid, and a pressure-temperature (PT) sensor to measure at least one of a pressure or a temperature of the second portion of the wellbore fluid. 1. A downhole gas detection tool , comprising:a housing that comprises a connection configured to couple the tool with a drilling string;a first test module at least partially enclosed within the housing, the first test module comprising a first fluid test chamber operable to fluidly couple to an annulus of a wellbore to receive a first portion of a wellbore fluid, the first test module further comprising an acoustic fluid sensor to measure a fluid acoustic velocity and attenuation of the first portion of the wellbore fluid received in the first fluid test chamber, and a fluid resistivity sensor to measure a fluid resistivity of the first portion of the wellbore fluid received in the first fluid test chamber; anda second test module at least partially enclosed within the housing, the second test module comprising a second fluid test chamber operable to fluidly couple to the annulus of the wellbore to receive a second portion of the wellbore fluid, the second test module further comprising a pressure-temperature (PT) sensor to measure at least one of a pressure or a temperature of the second portion of the ...

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    05-01-2017 дата публикации

    HEAVY OIL SAMPLING METHODS AND SYSTEMS

    Номер: US20170002655A1
    Автор: Ayyad Hazim, Jamal Sarah
    Принадлежит:

    The present disclosure relates to a formation sampling method that includes disposing a downhole tool that has an expandable packer and an extendable probe within a wellbore disposed in a subterranean formation, pumping formation fluid into the downhole tool through the extendable probe to move heavy oil from within the subterranean formation towards the wellbore, detecting arrival of the heavy oil at the wellbore, and performing formation sampling with the expandable packer in response to detecting the arrival of the heavy oil at the wellbore. 1. A formation sampling method comprising:disposing a downhole tool comprising an expandable packer and an extendable probe within a wellbore disposed in a subterranean formation;pumping formation fluid into the downhole tool through the extendable probe to move heavy oil from within the subterranean formation towards the wellbore;detecting arrival of the heavy oil at the wellbore; andperforming formation sampling with the expandable packer in response to detecting the arrival of the heavy oil at the wellbore.2. The formation sampling method of claim 1 , wherein comprising confirming a presence of mobile heavy oil within the subterranean formation prior to disposing the downhole tool within the wellbore.3. The formation sampling method of claim 2 , wherein confirming the presence of mobile heavy oil comprises performing a combination of NMR scanning and dielectric scanning.4. The formation sampling method of claim 2 , wherein disposing the downhole tool within the wellbore comprises conveying the downhole tool within the wellbore to dispose the extendable probe at a location in the wellbore corresponding to the presence of mobile heavy oil.5. The formation sampling method of claim 1 , comprising monitoring properties of the formation fluid within the downhole tool while pumping the formation fluid into the downhole tool through the extendable probe.6. The formation sampling method of claim 5 , wherein monitoring properties of ...

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    07-01-2016 дата публикации

    Interval Density Pressure Management Methods

    Номер: US20160002991A1
    Принадлежит:

    A method for estimating equivalent top of fluid level or a theoretical surface annular back pressure in a subterranean wellbore includes acquiring first and second axially spaced pressure measurements in the wellbore. The pressure measurements may then be processed to compute the equivalent top of fluid level and/or theoretical surface annular back pressure of drilling fluid between the measurement locations. A tool string including a large number of axially spaced pressure sensors (e.g., four or more or even six or more) electronically coupled with a surface processor via wired drill pipe may be used to obtain a plurality of values corresponding to various wellbore intervals. The equivalent top of fluid level and/or theoretical surface annular back pressures may be used in automated managed pressure drilling operations. 1. A method for estimating an equivalent top of fluid level in a subterranean wellbore , the method comprising:(a) deploying a tool string in the wellbore, the tool string including first and second subsurface longitudinally spaced pressure sensors deployed at corresponding first and second measured depths in the wellbore;(b) causing the first and second pressure sensors to acquire first and second annular drilling fluid pressure measurements at the first and second measured depths; and(c) causing a processor to process the first and second pressure measurements to compute an equivalent top of fluid level for a wellbore interval between the first and second measured depths.2. The method according to claim 1 , wherein:the tool string includes first, second, and third subsurface longitudinally spaced pressure sensors at corresponding first, second, and third measured depths;(b) comprises causing the first, second, and third pressure sensors to acquire first, second, and third annular drilling fluid pressure measurements; and(c) comprises processing the first, second, and third pressure measurements to compute a first equivalent top of fluid level for ...

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    07-01-2016 дата публикации

    TOOLS AND METHODS FOR USE IN COMPLETION OF A WELLBORE

    Номер: US20160003003A1
    Принадлежит:

    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; and applying 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 ...

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    07-01-2016 дата публикации

    Producing Hydrocarbons from a Formation

    Номер: US20160003017A1
    Принадлежит:

    The present disclosure provides a method of producing hydrocarbons from a formation. The method may include drilling a wellbore in the formation, wherein the wellbore is approximately horizontal; forming two or more fractures in the formation from the wellbore; receiving fracture performance data about the two or more fractures; analyzing the fracture performance data; selecting one or more fractures for injection and selecting one or more fractures for production based on the analysis of the fracture performance data; and completing the wellbore such that injection into the one or more fractures selected for injection and production from the one or more fractures selected for production may occur simultaneously. 1. A method of producing hydrocarbons from a formation , the method comprising:(a) drilling a wellbore in the formation, wherein the wellbore is approximately horizontal;(b) forming two or more fractures in the formation from the wellbore;(c) receiving fracture performance data about the two or more fractures;(d) analyzing the fracture performance data;(e) selecting one or more fractures for injection and selecting one or more fractures for production based on the analysis of the fracture performance data;(f) completing the wellbore such that injection into the one or more fractures selected for injection and production from the one or more fractures selected for production may occur simultaneously.2. The method of claim 1 , wherein the receiving fracture performance data further comprises collecting pressure claim 1 , temperature claim 1 , flow rate claim 1 , or other surveillance data during or after the forming of the fractures.3. The method of claim 1 , wherein the receiving fracture performance data further comprises providing different tracers with proppant for each fracture stage and analyzing production data for relative tracer concentrations.4. The method of claim 1 , wherein the receiving fracture performance data further comprises collecting ...

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    07-01-2016 дата публикации

    METHODS FOR TIME-DELAYED FRACTURING IN HYDROCARBON FORMATIONS

    Номер: US20160003020A1
    Автор: Sharma Mukul M.
    Принадлежит:

    Methods of fracturing a hydrocarbon formation are described herein. A method may include propagating one or more first fractures from a first wellbore in the hydrocarbon formation, allowing a selected period of time to elapse so that at least a portion of the first fractures close, and propagating at least one second fracture in the wellbore or a second wellbore after the elapsed selected period of time. 1. A method of fracturing a hydrocarbon formation , comprising:propagating one or more first fractures from a first wellbore in the hydrocarbon formation;allowing a selected period of time to elapse so that at least some of the first fractures closes; andpropagating at least one second fracture in the wellbore after the elapsed selected period of time.2. The method of claim 1 , wherein a desired amount of time is at least 30 minutes claim 1 , at least 2 hours claim 1 , or longer.3. The method of claim 1 , further comprising determining the closure of the fracture using diagnostic tools claim 1 , wherein the diagnostic tools include microseismic array claim 1 , tiltmeter claim 1 , or the like.4. The method of claim 1 , wherein wellbore is an open wellbore.5. The method of claim 1 , wherein the wellbore is a cased wellbore.6. The method of claim 1 , wherein propagating at least one second fracture comprises determining a distance from the first fracture from the wellbore.7. The method of claim 1 , wherein propagating at least one second fracture comprises determining the pressure in the first fracture and determining a distance from the first fracture.8. The method of claim 1 , further comprising providing proppant to at least one of the first fractures.9. The method of claim 1 , wherein the closed first fracture is unpropped.10. The method of claim 1 , further comprising measuring initial shut in pressure associated with propagating the first fracture.11. The method of claim 1 , wherein at least one second fracture is propagated at a distance twice a determined ...

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    07-01-2016 дата публикации

    Method of determining reservoir pressure

    Номер: US20160003026A1
    Принадлежит: BP Corp North America Inc

    A well test method for use in tight gas reservoirs prior to hydraulic fracture stimulation. The method can use injection of water using low-rate surface pumps into the reservoir below parting pressure. The measured rates and pressures are converted to sandface rate and pressure datasets for each stage. The technique can utilize either surface or bottom-hole pressure sensors. The resulting sandface datasets are analyzed using the baseline/calibration method or other analysis appropriate to stage data to determine reservoir flow properties. The small-volume, staged well test enables estimation of the flow properties of reservoir, including pressure and permeability, in hours rather than days.

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    07-01-2016 дата публикации

    SYSTEM AND METHOD FOR DETECTING STRUCTURAL INTEGRITY OF A WELL CASING

    Номер: US20160003027A1
    Принадлежит: Chevron U.S.A. INC.

    This disclosure relates to a system and method for detecting structural integrity of a well casing. The system may detect casing structural integrity events. The casing structural integrity events may include structural failures of the casing and/or potential structural failures of the casing. The well casing may be drilled and/or otherwise embedded into a geologic structure. The well casing may be subject to geologic forces generated by the geologic structure. Unplanned and/or unexpected forces and/or movement may pose a risk to the structural integrity of the casing. Forces and/or movement of sufficient magnitude may result in damage to and/or destruction of the casing. Damage to and/or destruction of the casing may cause a loss of the natural resources being extracted via the well associated with the well casing, contamination of areas surrounding the well, undesirable surface expression, and/or other negative effects. 1. A system configured to detect structural integrity of a well casing in a well , the system comprising:a conductive well casing configured to surround conductive well tubing, the tubing being configured to communicate liquid and/or gas from an underground reservoir to above ground extraction equipment at or near a wellhead, the casing being embedded in a geologic structure;one or more sensors configured to generate output signals conveying information related to a structural integrity of the casing and/or a casing-tubing pair, andone or more processors configured to detect casing structural integrity events based on the output signals, and to generate casing structural integrity event notifications that correspond to the detected casing structural integrity events for delivery to a user responsive to the detections, the casing structural integrity events including one or both of structural failures of the casing or potential structural failures of the casing.2. The system of claim 1 , wherein the one or more processors are further configured to ...

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    07-01-2016 дата публикации

    Determining Stresses in a Pipe Under Non-Uniform Exterior Loads

    Номер: US20160003030A1
    Автор: Mitchell Robert F
    Принадлежит:

    Systems and methods for determining stresses in pipe under non-uniform exterior loads to test the pipe design for structural integrity by approximating non-uniform exterior loads on the pipe and performing a stress analysis of the pipe under the non-uniform exterior loading to determine the stresses in the pipe. 1. A method for determining stresses in a pipe under non-uniform exterior loads , which comprises:a) determining coefficients in multiple stress equations for the pipe by solving boundary condition equations using a maximum lateral pressure on the pipe, a minimum lateral pressure on the pipe, an inside radius of the pipe and an outside radius of the pipe;b) solving two of the multiple stress equations that each represent a radial stress for the pipe, two of the multiple stress equations that each represent a hoop stress for the pipe, which are added together to represent a total radial stress and a total hoop stress, and one of the multiple stress equations that represents a total shear stress for the pipe using one or more of the coefficients, a predetermined pipe radius and a predetermined pipe angle; andc) calculating a stress intensity for the pipe using a computer processor, the total radial stress, the total hoop stress, the total shear stress and a predetermined total axial stress for the pipe.2. The method of claim 1 , wherein the predetermined pipe radius and the predetermined pipe angle are each within a respective predetermined range.3. The method of claim 2 , wherein the predetermined range for the predetermined pipe radius is greater than the inside radius of the pipe and is less than the outside radius of the Pipe.4. The method of claim 3 , wherein the predetermined range for the predetermined pipe angle is greater than zero and is less than π.5. The method of claim 4 , further comprising repeating steps b)-c) with another predetermined pipe radius and another predetermined pipe angle until a maximum stress intensity for the pipe is calculated. ...

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    07-01-2016 дата публикации

    INTELLIGENT TEST SYSTEM AND METHOD FOR MULTI-SEGMENT FRACTURED HORIZONTAL WELL

    Номер: US20160003031A1
    Принадлежит:

    Disclosed are an intelligent test system and method for a multi-segment fractured horizontal well. The intelligent test method for a multi-segment fractured horizontal well comprises: step A: placing a test tubular column into an underground horizontal section; step B: setting a pressure building packer and a hanging packer by means of pressurization after the test tubular column is placed into an underground designed position; step C: breaking a hydraulic release connector to separate the hydraulic release connector from a seal pipe; step D: pulling out a first oil pipe, and reserving the tubular column comprising the seal pipe and located on the downstream part of the seal pipe in a horizontal well; and step E: placing a production tubular column or a communications tubular column into a vertical section of the horizontal well. 1. An intelligent test method for a multi-segment fractured horizontal well , in which a test tubular column is used , the test tubular column comprising:a first oil pipe extending from a well head into a vertical section of the horizontal well;a hydraulic release connector arranged at a bottom end of the first oil pipe and located in the vertical section of the horizontal well;a seal pipe connected at a lower end of the hydraulic release connector and located in the vertical section of the horizontal well, with a distance between a top end of the seal pipe and the well head of the horizontal well being greater than a working depth of a oil sucking pump being placed;a hanging packer connected below the seal pipe;a data collection controller connected below the hanging packer and located in the vertical section of the horizontal well;a second oil pipe connected below the data collection controller and extends into a horizontal section of the horizontal well;a cable extending to the horizontal section of the horizontal well from the data collection controller along an outer side of the second oil pipe;a plurality of pressure building packers ...

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    07-01-2016 дата публикации

    Matrix temperature production logging tool

    Номер: US20160003032A1
    Принадлежит: ConocoPhillips Co

    A matrix production logging tool for measuring the temperature of produced fluids in a wellbore. Accurate production allocation to the pathways between the oil/gas well and the reservoir provides required data for the economic optimization of the techniques and procedures used to complete future wells. The low maintenance tool provides precise upstream, downstream and inflow temperature measurements of produced fluids within the wellbore.

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    04-01-2018 дата публикации

    SYSTEMS AND METHODS FOR RECOVERING BITUMEN FROM SUBTERRANEAN FORMATIONS

    Номер: US20180003018A1
    Автор: HACI MARC
    Принадлежит: MUST HOLDING LLC

    A well system for recovering hydrocarbons such as heavy crude oil from subsurface reservoirs is provided. The well system includes a single continuous wellbore extending from a surface entry opening to a surface exit opening. A substantially horizontal section of the wellbore is formed within the subsurface reservoir. In one embodiment, a plurality of heater-lifter units are movably disposed within the substantially horizontal wellbore section. The heater-lifter units are configured to apply heat to subsurface reservoir surrounding the substantially horizontal wellbore section to mobilize the hydrocarbons. A lifting mechanism is configured to move the heater-lifter units in bidirectional manner within the continuous wellbore so that the produced low viscosity hydrocarbons are mechanically lifted to the surface. 1. A system for recovering hydrocarbons from a subsurface reservoir , comprising:a continuous wellbore extending from a first surface location to a second surface location, the continuous wellbore including a first inclined wellbore section extending from the first surface location to the subsurface reservoir, a substantially horizontal wellbore section lying within the subsurface reservoir, and a second inclined wellbore section extending from the subsurface reservoir to the second surface location;a plurality of heater-lifter units disposed within the substantially horizontal wellbore section, the heater-lifter units being configured to apply heat to the subsurface reservoir to produce a hydrocarbon fluid and to sweep the hydrocarbon fluid along a direction of motion of the heater-lifter units to mechanically lift the hydrocarbon fluid to the first surface location and the second surface location;a carrier line carrying the heater-lifter units in a spaced apart fashion, the carrier line extends through the continuous wellbore and between the first and second surface locations; anda lifting mechanism configured to move the carrier line and thus the heater- ...

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    04-01-2018 дата публикации

    AUTOMATED WELL PRESSURE CONTROL AND GAS HANDLING SYSTEM AND METHOD

    Номер: US20180003023A1
    Принадлежит:

    A method includes pumping fluid into a drill string extending through a riser into a well. A managed pressure drilling system is operated to maintain a selected fluid pressure in the well between the well and the drill string. A fluid influx into the well or a fluid loss into a formation traversed by the well is detected using measurements of fluid pressure in the well and fluid flow into and out of the well. The method includes automatically abating the fluid influx by closing an annular blowout preventer disposed in the riser or abating the fluid loss by operating the annular blowout preventer and pumping a sacrificial fluid into the drill string. 1. An apparatus , comprising:an annular blowout preventer disposed in a riser between a subsea wellhead coupled to a top of a well and a drilling platform;a managed pressure drilling system in fluid communication between an outlet of the riser and a drilling fluid flow system disposed on the drilling platform; anda processor operable to accept as input measurements of fluid pressure in the well, fluid flow rate into the well and fluid flow rate out of the well, the processor operable to determine a fluid loss into a formation or a fluid influx into the well from the input measurements, the processor operable to automatically control the annular blowout preventer and the managed pressure drilling system to, (i) drill the well with a selected fluid pressure therein, (ii) abate the fluid influx, and (iii) abate the fluid loss into the formation.2. The apparatus of claim 1 , wherein the managed pressure drilling system comprises a controllable orifice choke in a fluid discharge path from the well.3. The apparatus of claim 1 , wherein the managed pressure drilling system comprises a rotating control device.4. The apparatus of claim 1 , wherein the managed pressure drilling system comprises a flow meter in a fluid outlet path from the well.5. The apparatus of claim 1 , wherein the processor is in signal communication with a ...

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    04-01-2018 дата публикации

    Multi-Directionally Rotating Downhole Drilling Assembly and Method

    Номер: US20180003025A1
    Автор: Smith Gary
    Принадлежит:

    Embodiments of a downhole drilling assembly generally include a rotatable lower drilling assembly, a rotatable upper drilling assembly, and a drill bit, wherein the upper drilling assembly contains a mud motor adapted for clockwise rotation of its stator and counter-clockwise rotation of its rotor, whereby the lower drilling assembly is rotatable in the opposite direction of the upper drilling assembly or maintainable in a non-rotating state. The apparatus further includes sensors adapted to continuously measure physical properties and/or drilling parameters and a mechanism for continuously transmitting information relating thereto to the surface. 1. A downhole drilling assembly for use in a subsurface wellbore , comprising:a rotatable lower drilling assembly;a rotatable upper drilling assembly; and [ a first motor adapted to provide rotational force to said drill bit in a first direction; and', 'a sensor assembly comprising one or more sensors; and, 'said lower drilling assembly comprises, 'a second motor adapted to provide rotational force to said lower drilling assembly in a second direction; wherein:', 'said upper drilling assembly comprises, 'said upper drilling assembly is adapted to provided rotational force directed in said first direction and rotational force directed in said second direction to said lower drilling assembly; and', rotating in said first direction;', 'rotating in said second direction; and', 'not rotating., 'said lower drilling assembly is adapted to be rotated, by said rotational force directed in said first direction and said rotational force directed in said second direction, in one or more rotation modes selected from the group consisting of], 'a drill bit; wherein2. The downhole drilling assembly of claim 1 , wherein said sensor assembly comprises at least one sensor selected from the group consisting of:a total gamma ray sensor;a spectral gamma ray sensoran inclination sensor;an azimuthal gamma sensor;a pressure sensor;a strain sensor; ...

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    04-01-2018 дата публикации

    Mapping of fracture geometries in a multi-well stimulation process

    Номер: US20180003033A1
    Автор: Matthew A. Dawson
    Принадлежит: Reveal Energy Services Inc

    Systems and methods for assessing geometric fractures parameters in a subsurface formation are disclosed. A first pressure signal and a second pressure signal in a first (observation) wellbore in the subsurface formation may be assessed using a pressure sensor in direct fluid communication with a fluid in the first wellbore. The fluid in the first wellbore may be in direct fluid communication with at least a first fracture in the subsurface formation. The first pressure signal may include a pressure change that is induced by a second fracture being formed from a second (stimulation) wellbore in the subsurface formation. The second pressure signal may include a pressure change that is induced by a third fracture being formed from the second wellbore. One or more geometric parameters of the second and third fractures may be assessed using the first pressure signal and the second pressure signal.

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    04-01-2018 дата публикации

    System and method for downhole sensing

    Номер: US20180003035A1
    Принадлежит: General Electric Co

    A downhole sensing system includes a casing connector configured to fluidly couple segments of a downhole conduit through which a fluid flows. The downhole sensing system includes a sensing device disposed in the casing connector and configured to measure one or more parameters. The downhole sensing system also includes a wireless communication device disposed in the casing connector and configured to wirelessly communicate one or more parameters.

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    04-01-2018 дата публикации

    Downhole Communications Using Frequency Guard Bands

    Номер: US20180003037A1
    Автор: Roberson Mark W.
    Принадлежит:

    A system that is positionable in a wellbore can include a chain of transceivers that are positionable external to a casing string. Each transceiver in the chain of transceivers can be operable to transmit a wireless signal using a separate frequency guard band that is assigned to that transceiver and to receive wireless signals using another frequency guard band assigned to a prior transceiver in the chain of transceivers. 1. A system that is positionable in a wellbore , the system comprising:a chain of transceivers that are positionable external to a casing string, each transceiver in the chain of transceivers being operable to transmit a wireless signal using a separate frequency guard band assigned to that transceiver and to receive wireless signals using another frequency guard band assigned to a prior transceiver in the chain of transceivers.2. The system of claim 1 , wherein the frequency guard band comprises an unused range of frequencies that is between adjacent frequency bands for separating the adjacent frequency bands.3. The system of claim 1 , wherein each transceiver in the chain of transceivers is operable to receive a control signal from a remote device and select the separate frequency guard band based on the control signal.4. The system of claim 3 , wherein each transceiver in the chain of transceivers is remotely programmable subsequent to the transceiver being positioned in the wellbore.5. The system of claim 1 , wherein each transceiver in the chain of transceivers comprises:a processing device; and receive a control signal; and', 'select the frequency guard band and a particular frequency within the frequency guard band based on the control signal by consulting a lookup table stored in the memory device in which the frequency guard band and a plurality of frequencies within the frequency guard band are mapped to a plurality of characteristics of the control signal., 'a memory device in which instructions executable by the processing device are ...

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    04-01-2018 дата публикации

    Downhole Wireless Communications Using Surface Waves

    Номер: US20180003040A1
    Принадлежит:

    A communication system that is positionable in a wellbore can include a first transceiver for coupling externally to a casing string. The first transceiver can be for wirelessly transmitting data by generating and modulating a surface wave that propagates along an interface surface. The surface wave can include an electromagnetic wave that has a magnetic field or an electric field that is at an acute angle to a direction of propagation of the surface wave. The communication system can also include a second transceiver for coupling to the casing string and for wirelessly receiving the surface wave and detecting the data. 1. A communication system that is positionable in a wellbore , the communication system comprising:a first transceiver for coupling externally to a casing string and for wirelessly transmitting data by generating and modulating a surface wave that propagates along an interface surface, wherein the surface wave comprises an electromagnetic wave that includes a magnetic field or an electric field that is at an acute angle to a direction of propagation of the surface wave; anda second transceiver for coupling to the casing string and for wirelessly receiving the surface wave and detecting the data.2. The communication system of claim 1 , wherein the interface surface is between the casing string and a cement sheath.3. The communication system of claim 1 , wherein the first transceiver is electrically coupled to a sensor comprising a pressure sensor claim 1 , a temperature sensor claim 1 , a microphone claim 1 , a resistivity sensor claim 1 , a vibration sensor claim 1 , or a fluid flow sensor for receiving a sensor signal from the sensor and modulating the surface wave based on the sensor signal.4. The communication system of claim 3 , wherein the first transceiver comprises:a processing device; and receive the sensor signal from the sensor;', 'generate a transmission signal based on the sensor signal; and', 'transmit the transmission signal to an ...

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    04-01-2018 дата публикации

    Downhole Communications Using Selectable Frequency Bands

    Номер: US20180003041A1
    Автор: Roberson Mark W.
    Принадлежит:

    A system that is positionable in a wellbore in a subterranean formation can include a first transceiver that is positionable external to a casing string in the wellbore. The first transceiver can wirelessly transmit data via a signal within a frequency band that is selected based on a fluid property of a fluid in the wellbore and a property of the subterranean formation. The system can also include a second transceiver that is positionable externally 1. A system that is positionable in a wellbore in a subterranean formation , the system comprising:a first transceiver that is positionable external to a casing string in the wellbore for wirelessly transmitting data via a signal within a frequency band that is selected based on a fluid property of a fluid in the wellbore and a property of the subterranean formation; anda second transceiver that is positionable externally the casing string and operable to receive the signal.2. The system of claim 1 , wherein the first transceiver is operable to transmit the data via the signal and via another signal within another frequency band substantially simultaneously.3. The system of claim 1 , wherein the fluid comprises a combination of a wellbore servicing fluid and a formation fluid.4. The system of claim 1 , wherein the first transceiver comprises:a processing device; and receive a sensor signal from a sensor;', 'determine the fluid property based on the sensor signal;', 'determine the property of the subterranean formation based on the sensor signal; and', 'select the frequency band based on the fluid property and the property of the subterranean formation by consulting a lookup table stored in the memory device in which a plurality of fluid properties and a plurality of subterranean formation properties are mapped to a plurality of frequency bands., 'a memory device in which instructions executable by the processing device are stored for causing the processing device to5. The system of claim 1 , wherein the first ...

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    04-01-2018 дата публикации

    Systems and Methods for Downhole Fluid Analysis

    Номер: US20180003047A1
    Принадлежит:

    The present disclosure relates to a system that includes a downhole that includes a packer module with an inlet disposed between an upper packer and a lower packer configured to seal an interval of a wellbore. The inlet is configured to admit a formation fluid disposed in the interval. The downhole tool also includes a pump out module, a fluid analysis module, and a sample module including a sample chamber containing an external fluid. The downhole tool also includes a data processing system configured to identify a composition of the formation fluid and includes one or more tangible, non-transitory, machine-readable media including instructions to identify a condition indicating stopping the pump out module, transfer the external fluid from the sample chamber to the interval the inlet, resume pumping of the formation fluid from the inlet via the pump out module, and output the composition of the formation fluid. 1. A system , comprising: [ an upper packer and a lower packer configured to seal an interval of a wellbore in a geological formation; and', 'an inlet disposed between the upper packer and the lower packer, wherein the inlet is configured to admit a formation fluid disposed in the interval into a flow line of the downhole tool;, 'a packer module, wherein the packer module comprises, 'a pump out module configured to pump the formation fluid from the inlet;', 'a fluid analysis module configured to analyze the formation fluid pumped to the fluid analysis module via the pump out module;', 'a sample module comprising a sample chamber containing an external fluid;', 'a flow line coupled to the packer module, pump out module, fluid analysis module, and sample module; and', identify a condition indicating stopping the pump out module;', 'transfer the external fluid from the sample chamber to the interval via the flowline and the inlet;', 'resume pumping of the formation fluid from the inlet via the pump out module; and', 'output the composition of the formation ...

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    02-01-2020 дата публикации

    Snorkel Tube with Debris Barrier for Electronic Gauges Placed on Sand Screens

    Номер: US20200003023A1
    Принадлежит:

    A sensing system comprises at least one gauge disposed in a wellbore, a sensing link coupled to the at least one gauge, and a debris barrier coupled to the sensing link. The debris barrier comprises a housing coupled to the sensing link, and a barrier element configured to reduce the transport of particulates from the wellbore into the sensing link. 1. A sensing system comprising:at least one gauge disposed in a wellbore;a sensing link coupled to the at least one gauge; a housing coupled to the sensing link; and', 'a barrier element configured to reduce the transport of particulates from the wellbore into the sensing link; and, 'a debris barrier coupled to the sensing link, wherein the debris barrier comprisesa communication medium disposed in at last one of the sensing link or the housing, wherein the communication medium is configured to prevent fluid mixing within at least one of the housing or the sensing link, and wherein the communication medium is configured to communicate a pressure from the wellbore adjacent to the at least one gauge, wherein the debris barrier and the at least one gauge are axially separated.2. The sensing system of claim 1 , further comprising a filter element disposed in the wellbore claim 1 , wherein the debris barrier is disposed radially adjacent the filter element.3. The sensing system of claim 2 , wherein the at least one gauge is axially separated from the filter element.4. The sensing system of claim 1 , wherein the barrier element comprises a plug disposed within the housing claim 1 , wherein the housing comprises a seat claim 1 , and wherein the plug is configured to engage the seat.5. The sensing system of claim 1 , wherein the barrier element comprises a plug disposed within the housing claim 1 , wherein the barrier element comprises a bladder disposed within the housing.6. The sensing system of claim 1 , wherein the barrier element comprises a piston slidingly engaged within the housing.7. The sensing system of claim 1 , ...

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    02-01-2020 дата публикации

    MEASUREMENT OF POROELASTIC PRESSURE RESPONSE

    Номер: US20200003037A1
    Принадлежит:

    Method for characterizing subterranean formation is described. One method involves injecting a fluid into an active well of the subterranean formation at a pressure sufficient to induce one or more hydraulic fractures. Measuring, via a pressure sensor, a poroelastic pressure response caused by inducing of the one or more hydraulic fractures. The pressure sensor is in at least partial hydraulic isolation with the one or more hydraulic fractures. 1. A method for characterizing a subterranean formation during a hydraulic fracturing operation comprising:a) injecting a fluid into an active well of the subterranean formation at a pressure sufficient to induce one or more hydraulic fractures; andb) measuring, via a pressure sensor, a poroelastic pressure response caused by inducing of the one or more hydraulic fractures, wherein the pressure sensor is in at least partial hydraulic isolation with the one or more hydraulic fractures.2. The method of claim 1 , wherein the hydraulic fracturing operation is a multi-zone hydraulic fracturing operation.3. The method of claim 1 , wherein the pressure sensor is installed at the surface or in the active well.4. The method of claim 3 , wherein the active is divided into multiple zones by a well plug.5. The method of claim 4 , wherein at least one of the multiple zones is hydraulically isolated.6. The method of claim 4 , wherein the pressure sensor is installed inside a zone of the multi-zone zones.7. The method of claim 1 , wherein the pressure sensor is installed outside of a casing in the active well.8. The method of claim 1 , wherein the poroelastic pressure response is measured through an open toe of the active well.9. The method of claim 1 , wherein the pressure sensor is a pressure gauge.10. The method of claim 1 , wherein the pressure sensor is conveyed through casing or tubing claim 1 , suspended at wellhead claim 1 , or installed permanently or temporarily.11. A method for characterizing a subterranean formation during a ...

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    02-01-2020 дата публикации

    REDUCING ELECTROMAGNETIC NOISE DETECTED IN SURFACE MEASUREMENTS

    Номер: US20200003048A1
    Автор: Orban Jacques
    Принадлежит:

    A method for reducing noise at a wellsite includes transmitting a plurality of first signals from a variable frequency drive (VFD) to an alternating current (AC) induction motor. A timing of a plurality of second signals is varied to control transistors in an inverter of the VFD, thereby reducing harmonic distortion of the first signals output from the VFD. The timing is varied based at least partially upon an estimation of the harmonic distortion. 1. A method for reducing noise at a wellsite , comprising:transmitting a plurality of first signals from a variable frequency drive (VFD) to an alternating current (AC) induction motor; andvarying a timing of a plurality of second signals to control transistors in an inverter of the VFD, thereby reducing harmonic distortion of the first signals output from the VFD, wherein the timing is varied based at least partially upon an estimation of the harmonic distortion.2. The method of claim 1 , further comprising:detecting the first signals using a measurement system; andcoordinating with an acquisition system and the VFD to reduce the harmonic distortion in a predetermined bandwidth for the detected first signals.3. The method of claim 1 , where the estimation of the harmonic distortion is obtained by determining an effect of a pulse sequence of the second signals on the VFD and the AC induction motor.4. The method of claim 3 , further comprising reducing the harmonic distortion before applying the pulse sequence on the inverter of the VFD claim 3 , wherein the harmonic distortion is reduced via an iterative process.5. The method of claim 1 , wherein the estimation of the harmonic distortion is directly obtained from a measurement performed on the first signals output from the VFD claim 1 , allowing the harmonic distortion in subsequent first signals to be further reduced.6. The method of claim 1 , wherein the VFD comprises a plurality of inverters claim 1 , wherein a rectifier in the VFD generates direct current (DC) power ...

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    02-01-2020 дата публикации

    FLUID PRESSURE PULSE GENERATOR FOR A TELEMETRY TOOL

    Номер: US20200003050A1
    Принадлежит:

    A fluid pressure pulse generator apparatus for a telemetry tool comprising a stator and a rotor. The stator comprises a stator body and a plurality of radially extending stator projections spaced around the stator body and the spaced stator projections define stator flow channels extending therebetween. The rotor comprises a rotor body and a plurality of radially extending rotor projections spaced around the rotor body. The rotor projections are axially adjacent the stator projections and the rotor is rotatable relative to the stator such that the rotor projections move in and out of fluid communication with the stator flow channels to create fluid pressure pulses in fluid flowing through the stator flow channels. At least one of the rotor projections and at least one of the stator projections has a standard outer diameter. At least one of the rotor projections and/or at least one of the stator projections has a reduced outer diameter. The reduced outer diameter rotor and/or stator projections provide bypass channels for flow of fluid and allow for generation of a pattern of different fluid pressure pulses. 2. The apparatus of claim 1 , wherein the rotor projections have a radial profile comprising an uphole end and downhole end with two opposed side faces and a distal face extending between the uphole end and the downhole end claim 1 , wherein the uphole end or the downhole end of the rotor projections comprises a rotor radial face.3. The apparatus of claim 2 , wherein the radial length of the rotor radial face of the at least one rotor projection with the reduced outer diameter is reduced compared to the radial length of the rotor radial face of the at least one rotor projection with the standard outer diameter.4. The apparatus of claim 2 , wherein the stator projections have a radial profile with an uphole end and downhole end with two opposed side faces and a distal face extending between the uphole end and the downhole end claim 2 , wherein at least one of the ...

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    02-01-2020 дата публикации

    SAMPLE PHASE QUALITY CONTROL

    Номер: US20200003053A1
    Принадлежит: Halliburton Energy Services, Inc.

    Systems and methods for subterranean formation testing. A method may include: lowering a formation testing tool into a subterranean formation, wherein the formation testing tool may include memory, a pump, a formation probe, at least two sample chambers, wherein the at least two sample chambers may include probes to measure pressure and temperature; extracting a fluid from the subterranean formation with the pump and the formation probe; flowing the fluid into the at least two sample chambers with the pump; storing pressure and temperature data of the fluid in the memory; and removing the at least two sample chambers from the formation testing tool. 1. A method comprising:lowering a formation testing tool into a subterranean formation, wherein the formation testing tool comprises memory, a pump, a formation probe, at least two sample chambers, wherein the at least two sample chambers comprise probes to measure pressure and temperature;extracting a fluid from the subterranean formation with the pump and the formation probe;flowing the fluid into the at least two sample chambers with the pump;storing pressure and temperature data of the fluid in the memory; andremoving the at least two sample chambers from the formation testing tool.2. The method of claim 1 , wherein the at least two sample chambers comprise a cushioned sample chamber comprising a nitrogen section and a fluid sample section claim 1 , and an un-cushioned sample chamber comprising a fluid sample section.3. The method of claim 2 , further comprising continuously monitoring pressure and temperature of the fluid within the un-cushioned sample chamber and the cushioned sample chamber from a time of recovery of the fluid to a time of opening the un-cushioned sample chamber and the cushioned sample chamber.4. The method of claim 1 , wherein the memory comprises volatile memory or non-volatile memory.5. The method of claim 1 , wherein the probes comprise feed through wires configured to allow communication and ...

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    07-01-2016 дата публикации

    Non-electronic air chamber pressure sensor

    Номер: US20160003701A1
    Принадлежит: Halliburton Energy Services Inc

    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.

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    07-01-2021 дата публикации

    Acid Fracturing Treatments in Hydrocarbon-Bearing Formations in Close Proximity to Wet Zones

    Номер: US20210002993A1
    Принадлежит: Saudi Arabian Oil Co

    System, methods, and devices for simultaneously fracturing a target formation and an adjacent secondary formation are disclosed. The simultaneous fracturing operations interfere with each other to form in-situ dynamic barriers. The in-situ barriers prevent acid from the fracturing treatment in the target formation from invading the secondary formation and, in some instances, sealing formation rock at the location of the in-situ barrier to prevent or reduce water movement from the secondary formation into the primary formation.

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    07-01-2021 дата публикации

    Method for calculating single-well controlled reserve of low-permeability/tight gas reservoir and analyzing residual gas thereof

    Номер: US20210002999A1
    Принадлежит: SOUTHWEST PETROLEUM UNIVERSITY

    The present invention belongs to the technical field of oil and gas field development, and discloses a method for calculating a single-well controlled reserve of a low-permeability/tight gas reservoir and analyzing residual gas thereof. The method includes: calculating a reserve controlled by each gas well in a block by using a gas reservoir dynamic reserve calculation method; establishing a new reserve calculation formula for solution and comparative analysis by an example; and quantitatively analyzing an effect of a startup pressure gradient and a stress sensitivity on a calculation result of the single-well controlled reserve, wherein the analysis of the factors affecting reserve calculation shows that, when the startup pressure gradient reaches 0.02 MPa/m, the calculated reserve is significantly reduced compared with a conventional method, but when the startup pressure gradient is greater than 0.1 MPa/m, the effect gradually stabilizes.

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    07-01-2021 дата публикации

    DRILL STEM TESTING

    Номер: US20210003003A1
    Принадлежит:

    Systems and techniques for determining properties of a formation comprising are disclosed. A test tool attached to test string comprising a fluid conduit is deployed to a test position within a wellbore. The deployment includes hydraulically isolating a portion of the wellbore proximate the test tool to form an isolation zone containing the test position. A fluid inflow test is performed within the isolation zone and an initial formation property and a fluid property are determined based on the fluid inflow test. A fluid injection test is performed within the isolation zone including applying an injection fluid through the test string into the isolation zone, wherein the flow rate or pressure of the injection fluid application is determined based, at least in part, on the at least one of the formation property and fluid property, The fluid injection test further includes measuring pressure within the isolation zone to determine a pressure transient associated with the injection of the injection fluid. A property of the formation is determined based on the determined pressure transient. 1. A method for determining properties of a formation comprising:performing a fluid inflow test within an isolation zone of a wellbore;determining a first formation property based, at least in part, on the fluid inflow test; and applying an injection fluid into the isolation zone, wherein a flow parameter for the injection fluid application is determined based, at least in part, on the first formation property; and', 'measuring pressure within the isolation zone to determine a pressure transient associated with the application of the injection fluid., 'performing a fluid injection test within the isolation zone including2. The method of claim 1 , further comprising determining a second formation property based on the determined pressure transient.3. The method of claim 2 , wherein said determining a second formation property comprises determining at least one of a formation flow ...

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    03-01-2019 дата публикации

    SEALING DEVICE TEST SYSTEMS AND METHODS

    Номер: US20190003301A1
    Принадлежит:

    A dynamic testing system for sealing devices includes a shaft that is reciprocated in a bore through a body. The shaft includes a first seal assembly and a second seal assembly disposed a distance apart on the shaft. When the shaft is inserted into the bore, the first seal assembly and the second seal assembly form a fluid-tight seal between the external surface of the shaft and the internal surface of the bore—this forms a fluid-tight cavity between the seal assemblies. Sealing devices in each of the first seal assembly and the second seal assembly experience chemical attack and mechanical wear. One or more axial force measurement sensors measure the force applied by a prime mover to reciprocate the shaft within the bore. Data acquisition circuitry collects the force information and generates a graphical output that plots friction force against reciprocating cycle count. 1. A test apparatus , comprising:a shaft having a first end and a second end and a first diameter;an axial force measurement device coupleable to the first end of the shaft;a first seal assembly disposed about a perimeter of the shafta second seal assembly disposed about the perimeter of the shaft, the second seal assembly spaced apart from the first seal assembly;a body including a bore extending completely through the body, the bore having a second diameter that is larger than the first diameter, the bore to receive the shaft such that a reciprocating fluid-tight cavity forms between the first seal assembly and the second seal assembly;an inlet port fluidly coupled to the enclosed chamber; andan outlet port fluidly coupled to the enclosed chamber.2. The test apparatus of claim 1 , further comprising:a first shaft seal coupleable to the body, the first shaft seal to seal about the perimeter of the shaft, the first shaft seal positioned between the first seal assembly and the first end of the shaft, the first shaft seal including a first leakage port to drain leakage through the first seal assembly ...

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    03-01-2019 дата публикации

    Subsea sensor assemblies

    Номер: US20190003817A1
    Принадлежит: General Electric Co

    Integrated penetrator and proximity sensor probe assemblies are provided for monitoring a position of a rotating target within a subsea rotating device such as subsea motors and pumps. The integrated penetrator and proximity sensor probe assemblies are configured to communicate information related to the position of the rotating target through a wall of the device housing, and can be inserted through an opening in the wall of the device housing and mounted to the wall of the device to position a proximity sensor tip assembly adjacent the rotating target. The proximity sensor probe assemblies are pressure-compensated and configured to withstand subsea pressures and conditions.

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    07-01-2021 дата публикации

    Simulation Method for Flow Field of Multi-Stage Fracturing on Horizontal Well in Tight Oil Reservoir

    Номер: US20210003742A1
    Принадлежит:

    A simulation method for flow field of multi-stage fracturing on horizontal well in tight oil reservoir is provided. The tight oil reservoir comprises multiple horizontal wells with multi-stage fracturing, and for any horizontal well of the multiple horizontal wells, the method comprises: establishing a seepage mathematical model involving threshold pressure gradient according to reservoir physical property data and production data of the horizontal well, and determining formation pressure distribution of the horizontal well after multi-stage fracturing production according to the seepage mathematical model; determining formation pressure field distribution of the horizontal well after multi-stage fracturing production according to the formation pressure distribution and basing on principle of complex potential superposition; and establishing a criterion for identifying effective producing range of the horizontal well according to the formation pressure field distribution, and determining flow field range of the horizontal well according to the criterion. 1. A simulation method for flow field of multi-stage fracturing on horizontal well in tight oil reservoir , the tight oil reservoir comprises multiple horizontal wells with multi-stage fracturing , and for any horizontal well of the multiple horizontal wells , the method comprises:establishing a seepage mathematical model involving threshold pressure gradient according to reservoir physical property data and production data of the horizontal well, and determining formation pressure distribution of the horizontal well after multi-stage fracturing production according to the seepage mathematical model;determining formation pressure field distribution of the horizontal well after multi-stage fracturing production according to the formation pressure distribution and basing on principle of complex potential superposition; andestablishing a criterion for identifying effective producing range of the horizontal well ...

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    13-01-2022 дата публикации

    Managed Pressure Drilling System and Method

    Номер: US20220010636A1
    Принадлежит:

    A method for controlling pressure in a well includes pumping fluid into a riser extending between a drilling vessel and a wellhead, pumping fluid out of the riser to the drilling vessel by operating a first jet pump disposed in a conduit extending from the riser to the drilling vessel, wherein a rate of pumping power fluid into a power fluid inlet of the first jet pump is adjusted to maintain a liquid level in the drilling riser at a selected elevation. 1. A method for controlling pressure in a well , comprising:pumping fluid into a riser extending between a drilling vessel and a wellhead;pumping fluid out of the riser to the drilling vessel by operating a first jet pump disposed in a conduit extending from the riser to the drilling vessel; andwherein a rate of pumping power fluid into a power fluid inlet of the first jet pump is adjusted to maintain a liquid level in the drilling riser at a selected elevation.2. The method of further comprising pumping gas into a mud return line extending from a working fluid outlet of the first jet pump to the drilling vessel.3. The method of further comprising connecting an auxiliary line associated with the riser to a power fluid inlet of the first jet pump and pumping power fluid through the auxiliary line.4. The method of further comprising adjusting a rate of pumping the power fluid to maintain the liquid level at a selected elevation.5. The method of wherein the selected elevation corresponds to a selected equivalent circulating density.6. The method of wherein the selected elevation corresponds to a selected pressure in the wellbore.7. The method of further comprising adjusting a setting of an iris type annular pressure control device disposed in the riser in an annular space between the riser and a drill string disposed in the riser to increase back pressure on the well.8. The method of further comprising filtering cuttings exceeding a selected size from fluid entering a working fluid inlet of the first jet pump.9. The ...

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    13-01-2022 дата публикации

    OPTIMIZING WASTE SLURRY DISPOSAL IN FRACTURED INJECTION OPERATIONS

    Номер: US20220010655A1
    Принадлежит:

    Methods and apparatus are provided for optimizing operations for a fracturing injection waste disposal well especially where the formation is damaged or tight such that pressure fall-off tests are impractical due to extended leak-off rate times. Formation closure pressure and formation stress are calculated using Instantaneous Shut-in Pressure rather than traditional methods requiring actual fracture closure. 1. A method of predicting fracture closure pressure in a target zone of an injection well having a wellbore extending through the target zone , the method comprising:using instantaneous shut-in pressure (ISIP) data from the well, the ISIP data taken from a plurality of fall-off tests performed on the well after a plurality of injection cycles at pressures above the fracture pressure of the target zone, the fall-off tests for durations less than the fracture closure times;calculating fracture closing pressures corresponding to the plurality of fall-off tests; andpredicting, using the calculated fracture closing pressures, at least one future fracture closure pressure for a future injection cycle in the target zone.2. The method of claim 1 , wherein calculating fracture closure pressures further comprises using formation properties are taken from the group consisting of: formation permeability claim 1 , Young's modulus claim 1 , Poisson's ratio claim 1 , formation pressure claim 1 , overburden stress and porosity.3. The method of claim 1 , further comprising: calculating formation stress corresponding to the plurality of fall-off tests; and predicting claim 1 , using the calculated formation stress claim 1 , at least one future formation stress for a future injection cycle in the target zone.4. The method of claim 1 , further comprising: creating an injection history from the calculated fracture closure pressures; dividing the injection history into one or more injection intervals based on changes in injection flow rates or batch volumes used in the plurality of ...

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    08-01-2015 дата публикации

    SENSORS FOR MEASURING TEMPERATURE, PRESSURE TRANSDUCERS INCLUDING TEMPERATURE SENSORS AND RELATED ASSEMBLIES AND METHODS

    Номер: US20150007650A1
    Принадлежит:

    Quartz resonator pressure transducers for use in subterranean boreholes include a quartz pressure sensor and an electronic temperature sensor. Temperature sensors include a constant current generator, a proportional to absolute temperature (PTAT) current generator, and a relaxation oscillator. Pressure transducers may include such a temperature sensor. Methods of monitoring pressure in a subterranean borehole may include monitoring a frequency output of a quartz pressure sensor and monitoring a frequency output of an electronic temperature sensor. 1. A quartz resonator pressure transducer for use in a subterranean borehole , comprising:a pressure housing comprising at least one chamber;an electronics housing comprising an electronics assembly;a quartz pressure sensor in communication with the at least one chamber and for measuring pressure of a fluid disposed within the at least one chamber, wherein the electronics assembly is configured to drive the quartz pressure sensor at a selected frequency and to sense a pressure-related frequency response from the quartz pressure sensor; andan electronic temperature sensor electrically coupled to the electronics assembly and configured to output a temperature signal to the electronics assembly.2. The quartz resonator pressure transducer of claim 1 , wherein the temperature signal comprises a frequency signal.3. The quartz resonator pressure transducer of claim 1 , wherein the electronic temperature sensor comprises a silicon temperature sensor.4. The quartz resonator pressure transducer of claim 3 , wherein the electronic temperature sensor comprises a proportional to absolute temperature (PTAT) current generator configured to generate a PTAT current.5. The quartz resonator pressure transducer of claim 4 , wherein the electronic temperature sensor further comprises a constant current generator configured to generate a constant current.6. The quartz resonator pressure transducer of claim 5 , wherein the electronic temperature ...

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    08-01-2015 дата публикации

    METHOD AND APPARATUS FOR PERMANENT MEASUREMENT OF WELLBORE FORMATION PRESSURE FROM AN IN-SITU CEMENTED LOCATION

    Номер: US20150007976A1
    Автор: Godager Oivind
    Принадлежит: SENSOR DEVELOPMENTS AS

    A pressure gauge system and a method for in-situ determination of a wellbore formation pressure through a layer of cement, where the pressure gauge system comprises: a housing arranged to be permanently installed in the cement on the outside of a wellbore casing, wherein said housing comprises a pressure sensor with an output pressure signal, wherein: the pressure gauge system further comprises: a first temperature sensor with a first temperature signal, a second temperature sensor with a second temperature signal; and a computer implemented compensation means arranged to receive the pressure signal, the first and second temperature signals, and calculate a temperature compensated output pressure signal. 1. A pressure gauge system for in-situ determination of a wellbore formation pressure through a layer of cement , said pressure gauge system comprising:a housing arranged to be permanently installed in said cement on the outside of a wellbore casing, wherein said housing comprises:a pressure sensor with an output pressure signal, wherein said pressure gauge system further comprises;a first temperature sensor with a first temperature signal arranged to measure a first temperature outside said wellbore casing; anda computer implemented compensation means arranged to receive said pressure signal and said first temperature signal, and calculate a temperature compensated output pressure signal.2. A pressure gauge system according to claim 1 , comprising:a second temperature sensor with a second temperature signal arranged to measure a second temperature inside said wellbore casing, wherein said computer implemented compensation means is arranged to receive said second temperature signal, and calculate said temperature compensated output pressure signal also based on said second temperature signal.3. A pressure gauge system according to claim 1 , comprising:a rate of change temperature sensor with rate of change temperature signal arranged to measure a rate of change of ...

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    20-01-2022 дата публикации

    DETERMINING FRACTURE DRIVEN INTERACTIONS BETWEEN WELLBORES

    Номер: US20220018245A1
    Принадлежит:

    Techniques for determining a fracture driven interaction include identifying pressure response data from one or more pressure sensors that are in direct fluid communication with a fluid at least partially enclosed within one or more monitor wellbores formed from a terranean surface to one or more subterranean formations; calculating at least one pressure response value from the pressure response data; determining the fracture driven interaction between the treatment wellbore and at least one of the one or more monitor wellbores based at least in part on the calculated at least one pressure response value; and preparing a graphic representation of the determined FDI for display on a graphical user interface. 1. A computer-implemented method , comprising:identifying, with one or more hardware processors, pressure response data from one or more pressure sensors, each of the one or more pressure sensors in direct fluid communication with a fluid at least partially enclosed within one or more monitor wellbores formed from a terranean surface to one or more subterranean formations, the pressure response data comprising a recordable change in pressure of the fluid in response to a hydraulic fracturing treatment in a treatment wellbore formed from the terranean formation to initiate one or more hydraulic fractures from the treatment wellbore into the one or more subterranean formations;calculating, with the one or more hardware processors, at least one pressure response value from the pressure response data;determining, with the one or more hardware processors, a fracture driven interaction (FDI) between the treatment wellbore and at least one of the one or more monitor wellbores based at least in part on the calculated at least one pressure response value; andpreparing, with the one or more hardware processors, a graphic representation of the determined FDI for display on a graphical user interface (GUI).2. The computer-implemented method of claim 1 , wherein the at least ...

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    12-01-2017 дата публикации

    Acoustic Methods and Devices for Determining the Value of Formation Overpressure During Drilling and for Detecting Gas Packs Containing Hydrogen Sulfide Gas

    Номер: US20170009544A1
    Принадлежит:

    A method for determining formation pressure during exploratory drilling for oil includes generating a series of negative pressure shock waves at successively increasing well pressures to characterize gas kick forming at the bottom of a well. Once the lower end of the gas kick has been formed, the well pressure level as detected by a pressure sensor near the surface of the well is used to calculate the formation pressure along with the weight of the fluid column located in the well. 1. A method for detecting formation pressure at a time of appearance of a gas kick entering a well comprising the steps of:a. abruptly changing fluid pressure from a first pressure level to a second pressure level to generate a pressure shock wave,b. maintaining fluid pressure at said second pressure level for a period of time sufficient to allow said pressure shock wave to travel down along said well, reflect from a well bottom, and ascend upwards,c. monitoring said fluid pressure as a function of time from the onset of said change in fluid pressure and during the time of said pressure shock wave traveling down and then up along said well,d. detecting a presence of an upper end of said gas kick using a pressure peak in said fluid pressure and absence of a lower end of said gas kick,e. repeating steps (a) through (d) at higher successive pressures until detecting presence of a lower end of the gas kick, andf. calculating formation pressure using said higher pressure from step (e) recorded upon detecting said lower end of the gas kick, well depth and fluid column weight therein.2. The method as in claim 1 , wherein said fluid is a drilling mud and said fluid pressure is an outlet pressure of said drilling mud exiting said well.3. The method as in claim 1 , wherein said second pressure level is lower than said first pressure level claim 1 , whereby said pressure shock wave is a negative pressure shock wave.4. The method as in claim 1 , wherein said step (b) of maintaining said fluid ...

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    12-01-2017 дата публикации

    SHARED EQUATION OF STATE CHARACTERIZATION OF MULTIPLE FLUIDS

    Номер: US20170009558A1
    Автор: Fleming Graham, Wong Terry
    Принадлежит:

    System and methods of modeling fluids in a simulation of fluid production in a multi-reservoir system with a common surface network are provided. Pressure-volume-temperature (PVT) data is determined for fluids in each of a plurality of reservoirs coupled to the common surface network. A shared equation of state (EOS) characterization representing each of the fluids across the plurality of reservoirs is generated based on the corresponding PVT data. Data representing properties of the fluids in each reservoir is calculated based on the shared EOS characterization of the fluids. When the calculated data is determined not to match the PVT data associated with the fluids in each reservoir, to the shared EOS characterization is adjusted based on a difference between the calculated data and the PVT data. 1. A computer-implemented method of modeling fluids in a simulation of fluid production in a multi-reservoir system with a common surface network , the method comprising:determining pressure-volume-temperature (PVT) data for fluids in each of a plurality of reservoirs coupled to the common surface network;generating a shared equation of state (EOS) characterization representing each of the fluids across the plurality of reservoirs, based on the corresponding PVT data for the fluids in each reservoir;calculating data representing properties of the fluids in each reservoir, based on the shared EOS characterization of the fluids;determining whether or not the calculated data matches the PVT data associated with the fluids in each reservoir; andwhen the calculated data is determined not to match the PVT data, adjusting the shared EOS characterization based on a difference between the calculated data and the PVT data.2. The method of claim 1 , wherein the PVT data is based on existing data within a range of temperature and pressure conditions within the common surface network.3. The method of claim 1 , wherein the PVT data is generated based on a previously established EOS ...

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    12-01-2017 дата публикации

    LATER STAGE HYDROCARBON PRODUCTION PROCESSES

    Номер: US20170009562A1
    Принадлежит:

    A hydrocarbon production process comprising operating a first early stage hydrocarbon production process within a first communication domain with a first well pair, and operating a second early stage hydrocarbon production process within a second communication domain with a second well pair, such that an intermediate reservoir region including stranded bitumen becomes disposed between the first and second communication domains; wherein the first early stage hydrocarbon production process includes injecting a first production-initiating fluid via a first injection well of the first well pair into a first communication domain such that hydrocarbon material is mobilized and conducted to a first production well of the first well pair, and producing the received hydrocarbon material via the first production well; and wherein the second early stage hydrocarbon production process includes injecting a second production-initiating fluid via a second injection well of the second well pair into a second communication domain such that hydrocarbon material is mobilized and conducted to a second production well of the second well pair, and producing the received hydrocarbon material via the second production well; selecting a pre-selected zone within the reservoir, wherein the selecting is based upon temperature fall-off data within the first and second communication zones; and positioning a portion of an infill well within the pre-selected zone for receiving mobilized hydrocarbon material of at least the intermediate reservoir region and for producing the received hydrocarbon material. 1. A hydrocarbon production process comprising:operating an early stage hydrocarbon production process with a first well pair within a reservoir, wherein the early stage hydrocarbon production process includes injecting a production-initiating fluid via an injection well of the first well pair into a communication domain such that hydrocarbon material is mobilized and conducted to a production ...

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    12-01-2017 дата публикации

    Wide temperature range peak hold circuit

    Номер: US20170009565A1
    Автор: Kenneth Tomkins
    Принадлежит: Sondex Wireline Ltd

    A peak hold circuit configured for use in a downhole sensor includes a long tail pair circuit, a correction circuit, and a current mirror circuit. The current mirror circuit includes two current mirrors connected to a long tail pair formed by a first transistor and a second transistor. The current mirror also includes a first resistor and a second resistor connected to a third transistor. The first transistor is connected to a correction transistor of the correction circuit. The value of the first resistor is selected to be essentially equal to the same value as the second resistor so that when the long tail pair is balanced, the current flowing through a collector of the second transistor is equal to the current flowing through the first transistor, causing the correction transistor to switch off.

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    12-01-2017 дата публикации

    TEMPERATURE SENSOR TECHNIQUE FOR DETERMINING A WELL FLUID CHARACTERISTIC

    Номер: US20170009568A1
    Принадлежит:

    A method of determining changing well characteristics at downhole locations based on changes in detected temperatures by permanently installed downhole sensors. The methods and tools utilized involve the establishing of baseline temperature profiles, for example, at the outset of well operations. The installed sensors may be powered are rechecked on a periodic or continuous basis for substantial deviations to the temperature profiles which are indicative of particular well condition changes such as the depositing of asphaltene or decreases in fluid velocity. 1. A method of monitoring a downhole well condition , the method comprising:installing a temperature sensor at a downhole location in the well;powering the sensor;calibrating the sensor to establish a baseline temperature profile at a given point in time;detecting a substantial deviation from the baseline temperature profile at another point in time after the given point in time;correlating the substantial deviation with a non-temperature based condition in the well at the sensor; andtaking corrective action in the well based on the correlating of the substantial deviation with the condition.2. The method of wherein the taking of the corrective action comprises one of introducing a chemical injection mix to the location of the sensor and reducing the rate of fluid flow in the well.3. The method of wherein the non-temperature based condition is one of a change in fluid velocity in the well adjacent the sensor and buildup at the sensor.4. The method of wherein the substantial deviation is an increase in temperature from the baseline temperature profile and the change in velocity is a decrease in fluid velocity adjacent the sensor.5. The method of wherein the substantial deviation is an increase in temperature from the baseline temperature profile and the buildup at the sensor is a buildup of asphaltene.6. The method of further comprising:performing an application in the well prior to the detecting of the ...

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    12-01-2017 дата публикации

    CAPROCK BREACH DETERMINATION TECHNIQUE

    Номер: US20170009569A1
    Автор: Lovell John, Manin Yves
    Принадлежит:

    A technique for determination of out of zone injection. The technique may include taking temperature readings of the well at locations adjacent the cap rock during injection of injection fluid into the injection well at temperatures that are below that of the cap rock. Analysis of the rate of change in temperatures adjacent the cap rock may be used to monitoring effects of the injection application including deciphering cap rock breach of injection fluid when the rate of change substantial enough. 1. A method of determining out of zone injection of a fluid from an injection well and into cap rock over a reservoir at an oilfield , the method comprising:positioning a sensor device in the injection well adjacent the cap rock;recording an initial temperature of the sensor device corresponding to the cap rock;injecting the fluid into the injection well at a temperature different from that of the cap rock;monitoring the sensor device for a change in temperature at an anomalous rate corresponding to out of zone injection of the fluid into the cap rock.2. The method of claim 1 , further comprising:taking corrective action when the out of zone injection of the fluid into the cap rock is detected during the monitoring of the sensor device.3. The method of claim 2 , wherein the corrective action comprises one of reducing a rate of the injecting of the fluid into the injection well and shutting off the injection well.4. The method of claim 2 , further comprising:shutting in the injection well; andmonitoring temperature of the sensor device during the shutting in of the injection well for a warmback period to confirm the reduction in temperature at a rate corresponding to the out of zone injection in advance of the taking of the corrective action.5. The method of claim 1 , further comprising:shutting in the injection well; andstoring temperature of the sensor device during the shutting in of the injection well for a warmback period to establish reference temperature data.6. The ...

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    12-01-2017 дата публикации

    Downhole Sensing Systems and Methods Employing Squeezed Light Interferometry

    Номер: US20170009571A1
    Принадлежит: Halliburton Energy Services, Inc.

    An illustrative downhole sensing system includes a phase-squeezer assembly, an interferometer with a downhole sensor on the sensing path, and a receiver. The phase squeezer assembly provides a phase-squeezed laser beam, preferably with a squeeze parameter greater than 2. Certain embodiments include a pulse generator that gates the phase-squeezed laser beam to form a sequence of phase-squeezed laser pulses, and may further include a compensator that converts the sequence of pulses into a sequence of double pulses with a slight frequency shift between the pulses in each pair. The interferometer conveys a reference portion of the phase-squeezed laser beam along a reference path and a sensing portion of the phase-squeezed laser beam along a sensing path. A downhole sensor along the sensing path provides the sensing portion of the phase-squeezed laser beam with a measurement-parameter dependent phase shift relative to the reference portion of the phase-squeezed laser beam, which is measured by the receiver. 1. A downhole sensing system that comprises:a phase squeezer assembly that provides a phase-squeezed laser beam;an interferometer that directs a reference portion of the phase-squeezed laser beam along a reference path and a sensing portion of the phase-squeezed laser beam along a sensing path;a downhole sensor along the sensing path to provide the sensing portion of the phase-squeezed laser beam with a measurement-parameter dependent phase shift relative to the reference portion of the phase-squeezed laser beam; anda receiver that measures said phase shift.2. The system of claim 1 , including a fiberoptic cable that conveys the phase-squeezed laser beam to the downhole sensor.3. The system of claim 2 , further comprising a processing unit that collects measurements of said phase shift from the receiver and derives a time-dependent parameter for display to a user.4. The system of claim 3 , wherein the parameter is in a set consisting of temperature claim 3 , pressure ...

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    27-01-2022 дата публикации

    MANDRIL ASSEMBLY FOR CHEMICAL INJECTION IN OIL WELLS

    Номер: US20220025734A1
    Принадлежит: PETROLEO BRASILEIRO S.A. - PETROBRAS

    The present invention refers to a mandrel assembly for chemical injection in use in an oil well production string where the water depth can reach 3,000 m, exerting extreme hydrostatic pressures on the mandrel. The mandrel assembly is capable of dosing the chemical fluid flow rate to avoid some types of unwanted situations in the production string, mainly related to fouling. It has the characteristic of not using injection valves having small diameters, causing the annular space between the mandrel body and the inner part to ensure greater space for the flow of chemical fluid, thus reducing the likelihood of a possible plugging. Such characteristics ensure lower maintenance interventions, thus generating lower costs and increasing well reliability. 12100200300. A CHEMICAL INJECTION MANDREL ASSEMBLY () IN OIL WELLS , comprising a concentric mandrel tube () , a concentric jacket () , and a chemical injection mandrel ().2100101103105. The MANDREL ASSEMBLY of claim 1 , wherein the concentric mandrel tube () comprises three parts: the upper portion of the mandrel tube () claim 1 , the central portion of the mandrel tube () claim 1 , and the lower portion of the tube ().3200203201. The MANDREL ASSEMBLY of claim 1 , wherein the concentric jacket () comprises a parallel thread () claim 1 , a solid space ().4300302303304305. The MANDREL ASSEMBLY according to claim 1 , wherein the chemical injection mandrel () comprises: hydraulic connectors () claim 1 , rupture discs () claim 1 , preferably two check valves () and pressurization devices ().5200201202. THE MANDREL ASSEMBLY according to claim 2 , wherein the concentric jacket () is preferably segregated in the solid part () being replaced with a cap () claim 2 ,6205201205202. THE MANDREL ASSEMBLY of claim 3 , comprising any amounts of holes () in the solid portion () or holes () in the cap ().7300205. THE MANDREL ASSEMBLY according to claim 6 , wherein elements of the chemical injection mandrel () are installed in the holes (). ...

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    12-01-2017 дата публикации

    Interferometric High Fidelity Optical Phase Demodulation

    Номер: US20170010133A1
    Автор: Barfoot David A.
    Принадлежит: Halliburton Energy Services, Inc.

    An illustrative interferometric system with high-fidelity optical phase demodulation includes a receiver having a fiberoptic coupler that produces optical interferometry signals having mutual phase separations of 120° and balanced photo-detectors that each produce an electrical difference signal based on a respective pair of said optical interferometry signals. The system further includes circuitry that converts the electrical difference signals into measurements of an interferometric phase. 1. An interferometric system with high-fidelity optical phase demodulation , comprising: a fiberoptic coupler that produces optical interferometry signals having mutual phase separations of 120°;', 'balanced photo-detectors that each produce an electrical difference signal based on a respective pair of said optical interferometry signals; and, 'a receiver havingcircuitry that converts the electrical difference signals into measurements of an interferometric phase.2. The system of claim 1 , further comprising:a source that transmits at least one light pulse along a distributed sensing fiber,wherein the circuitry windows said measurements based on a time delay after each pulse to associate said measurements with a position on the distributed sensing fiber.3. The system of claim 2 , wherein the distributed sensing fiber couples one or more return signals to the receiver claim 2 , and wherein the receiver splits the one or more return signals across two optical paths having a propagation delay difference to enable the fiberoptic coupler to produce said optical interferometry signals.4. The system of claim 3 , further comprising a first circulator that couples said at least one light pulse from the source to the distributed sensing fiber claim 3 , and further couples the return signal to the receiver.5. The system of claim 3 , wherein the fiberoptic coupler splits the return signal across the two optical paths claim 3 , and wherein the two optical paths are reflectively terminated.6. ...

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    14-01-2016 дата публикации

    METHOD FOR PERFORMING WELLBORE FRACTURE OPERATIONS USING FLUID TEMPERATURE PREDICTIONS

    Номер: US20160010443A1
    Автор: Xu Wenyue
    Принадлежит:

    A method of performing an oilfield operation about a wellbore penetrating a subterranean formation. The method involves performing a fracture operation comprising injecting fluid into the formation and generating fractures about the wellbore. The fractures form a fracture network about the wellbore. The method further involves collecting during the performing data comprising injection temperature and pressure, generating a fluid distribution through the fracture network by performing real time simulations of the fracture network based on the collected data (the fluid distribution comprising temperature distribution), and performing a production operation comprising generating production based on the temperature distribution. 1. A method of performing an oilfield operation about a wellbore penetrating a subterranean formation , the method comprising:performing a fracture operation comprising injecting fluid into the formation and generating fractures about the wellbore, the fractures forming a fracture network about the wellbore;collecting during the performing data comprising injection temperature and pressure;generating a fluid distribution through the fracture network by performing real time simulations of the fracture network based on the collected data, the fluid distribution comprising temperature distribution; andperforming a production operation comprising generating production based on the temperature distribution.2. The method of claim 1 , further comprising measuring actual production and comparing the predicted production with the actual production.3. The method of claim 2 , further comprising adjusting the performing based on the comparing.4. The method of claim 3 , further comprising repeating the generating until the generated production is within a desired range of the actual production.5. The method of claim 1 , further comprising optimizing the fracture operation by adjusting the fracture operation based on a comparison of the predicted production ...

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