СПОСОБ ПЕРЕДАЧИ ДАННЫХ ПО КОЛОННЕ ИЗ ОДНОЙ ИЛИ НЕСКОЛЬКИХ ТРУБ И ЭЛЕМЕНТ СВЯЗИ ДЛЯ ПЕРЕДАЧИ ДАННЫХ

Группа изобретений относится к технике связи, а именно к элементу связи, присоединяемому к колонне из одной или нескольких труб, а также к способу передачи данных по колонне из одной или нескольких труб в строительном оборудовании или в буровой установке для бурения скважины вдоль траектории бурения от исходной точки до конечной точки. Элемент связи, присоединяемый к колонне из одной или нескольких труб, выполненный с возможностью возбуждения в колонне электромагнитной волны при подаче на элемент связи информационного сигнала, содержит фидерную часть, расположенную на первом конце элемента связи для приема информационного сигнала. Элемент связи содержит первую электропроводящую часть, проходящую от фидерной части ко второму концу элемента связи, присоединяемому к колонне для создания электропроводящего соединения между первой электропроводящей частью и колонной. Элемент связи также содержит вторую электропроводящую часть, проходящую от фидерной части ко второму концу элемента связи. Первая ...

СИСТЕМА И СПОСОБ (ВАРИАНТЫ) ОЦЕНКИ ПАРАМЕТРОВ ПОДЗЕМНОГО ПЛАСТА

Группа изобретений относится к оценке параметров подземного пласта, пробуренного стволом скважины. Техническим результатом является повышение надежности и информативности определения по меньшей мере одного параметра подземного пласта, а именно среднего удельного сопротивления пласта. Для этого система оценки параметров подземного пласта оснащена скважинным оборудованием и датчиком. Скважинное оборудование выполнено с возможностью установки в стволе скважины. Скважинное оборудование содержит скважинный электромагнитный узел для связи с поверхностным электромагнитным узлом. Датчик определяет по меньшей мере один параметр скважины из электромагнитного сигнала. Скважинное оборудование и поверхностный электромагнитный узел выполнены с возможностью пересылки электромагнитных сигналов между ними. Причем электромагнитные сигналы проходят через подземный пласт, в силу чего, датчик определяет по меньшей мере один параметр скважины из электромагнитного сигнала, который определяется как функция индуцированного ...

ГЕОФИЗИЧЕСКАЯ ТЕЛЕМЕТРИЧЕСКАЯ СИСТЕМА ПЕРЕДАЧИ СКВАЖИННЫХ ДАННЫХ

Изобретение относится к области геофизических методов исследований и предназначено для передачи данных от контрольно-измерительных приборов в скважине к наземной аппаратуре. Технический результат: повышение надежности, увеличение ресурса работы и повышение дальности связи. Сущность: телеметрическая система содержит изоляционный трубный элемент, отделяющий нижнюю часть бурильных труб вместе с турбобуром от основной колонны бурильных труб, ключевой элемент, управляемый кодовым сигналом скважинной аппаратуры, наземную часть, содержащую электрод заземления и блок приема кодированной информации. Ключевой элемент подключен параллельно изоляционному трубному элементу. В наземную часть между колонной бурильных труб и электродом заземления введен силовой источник электрического питания канала связи и трансформатор тока. Силовой источник электрического питания канала связи и первичная токовая обмотка трансформатора тока включены последовательно между колонной бурильных труб и дополнительным электродом ...

СПОСОБ ПЕРЕДАЧИ СКВАЖИННОЙ ИНФОРМАЦИИ ПО ЭЛЕКТРОМАГНИТНОМУ КАНАЛУ СВЯЗИ И УСТРОЙСТВО ДЛЯ ЕГО ОСУЩЕСТВЛЕНИЯ

Группа изобретений относится к области бурения скважин и предназначена для передачи скважинной информации на поверхность по электромагнитному каналу связи. Техническим результатом является повышение надежности передачи информации с забоя по электромагнитному каналу связи, расширение области его применения и упрощение конструкции устройства для его осуществления. Предложен способ передачи информации по электромагнитному каналу связи посредством возбуждения электрического тока в породе, окружающей нижнюю часть колонны бурильных труб. При этом ток в породе возбуждают при помощи ЭДС автономного генератора, подключенного к колонне, и по изолированному от колонны коаксиальному кольцу. Кроме того, в верхнюю компоновку колонны труб вводят дополнительное изолированное от колонны коаксиальное кольцо и с этого кольца осуществляют съем величины переменного напряжения, наводимого в породе вблизи поверхности колонны текущим током, генерируемым излучающим кольцом. Причем величину указанного напряжения ...

НЕПЛОСКАЯ АНТЕННА ДЛЯ НАПРАВЛЕННОГО КАРОТАЖА СОПРОТИВЛЕНИЯ

Изобретение относится к скважинным измерительным устройствам, используемым для измерения электромагнитных свойств ствола скважины. Техническим результатом является обеспечение направленного действия антенны с возможностью принимать сигналы с разных сторон. Предложен скважинный измерительный инструмент, включающий, по меньшей мере, одну неплоскую антенну, сконфигурированную для передачи и/или приема электромагнитного излучения. При этом неплоская антенна включает в себя, по меньшей мере, одну неплоскую петлю антенного провода, развернутого вокруг корпуса инструмента. Причем в одном примере варианта осуществления неплоскую антенну можно считать двухплоскостной, включающей в себя первую и вторую секции полуэллиптической по форме, образующие первую и вторую пересекающиеся геометрические плоскости. В другом примере варианта осуществления аксиальное разделение между неплоской петлей антенного провода и проходящей по окружности центральной линией антенны изменяется, по существу, синусоидально ...

СПОСОБ УЛУЧШЕНИЯ СЕЙСМИЧЕСКОГО СИГНАЛА, СОЗДАВАЕМОГО БУРОВЫМ ДОЛОТОМ, С ИСПОЛЬЗОВАНИЕМ ПАРАМЕТРОВ БУРЕНИЯ

Изобретение относится к области исследования скважин и пластов в процессе бурения и может быть использовано для повышения отношения сигнал/шум. В качестве пилот-сигнала используют сигнал, создаваемый буровым долотом. Измеряют взаимно коррелированные друг с другом пилот-сигнал и сейсмические сигналы, переданные в грунт и отраженные от пластов. Пилот-сигнал и сейсмические сигналы могут быть обращены из свертки с получением таким образом дорожек сейсмограмм, на которых сигнал искажен шумом. Одновременно с этими сигналами получают связанные с ними параметры бурения. Для обеспечения улучшенного отношения сигнала к шуму и более четкого разделения сигнала и шума пилот-сигнал и сейсмические сигналы, полученные многократными измерениями для одного и того же диапазона глубин, частично или полностью суммируют с весом на основе одного или более параметров бурения или их комбинации. Для измерения указанных сигналов служит ряд приемников, образующих сейсмическую линию. 6 з.п. ф-лы, 9 ил., 1 табл.

СПОСОБ И СИСТЕМА ПЕРЕДАЧИ ИНФОРМАЦИИ ПОСРЕДСТВОМ ЭЛЕКТРОМАГНИТНЫХ ВОЛН

Изобретение относится к бурению и эксплуатации скважин и может быть использовано при передаче информации в скважине, защищенной, как минимум частично, металлическими трубами. В скважину устаналивают передатчик/приемник информации, функционирующий при помощи направленных электромагнитных волн, создаваемых излучением электрического сигнала диполем, электрически соединенным с металлическими трубами, служащими направляющими для излученных волн. Определяют затухание передачи в некоторых слоях формации, имеющих малое удельное сопротивление, и изолируют электрически, как минимум частично, металлические трубы, находящиеся в местах вышеуказанных слоев малого удельного сопротивления. Для этого в системе некоторые металлические трубы, находящиеся в местах слоев малого удельного сопротивления, содержат средства электрической изоляции от геологических формаций, через которые пробурена скважина. Изобретение позволяет улучшить характеристики передачи. 2 с. и 12 з.п. ф-лы, 5 ил.

КОМПЛЕКСНЫЙ ИНСТРУМЕНТ ДЛЯ ЭЛЕКТРОДНОГО ИЗМЕРЕНИЯ УДЕЛЬНОГО СОПРОТИВЛЕНИЯ И ЭМ ТЕЛЕМЕТРИИ

Изобретение относится к способу и устройству для интегрирования измерений удельного сопротивления в электромагнитный ("ЭМ") телеметрический инструмент. Техническим результатом является объединение возможностей измерения удельного сопротивления в ЭМ телеметрический инструмент и получения как данных удельного сопротивления, так и телеметрии. Комплексный инструмент включает утяжеленную бурильную трубу, включающую в себя первую часть и вторую часть, разделенные изолированным зазором, и телеметрический картридж, несущий телеметрическую схему, включающую в себя источник напряжения, генерирующий падение напряжения на изолированном зазоре, и осевой ток на бурильной колонне, который возвращается через геологический пласт, включает в себя изолированный измерительный электрод, подключенный к первой части, и схему для измерения удельного сопротивления, в ходе работы подключенную к измерительному электроду и телеметрической схеме. 4 н. и 54 з.п. ф-лы, 11 ил.

Способ определения пространственного положения и геометрических параметров трещины гидроразрыва

Изобретение относится к способам контроля развития трещины гидроразрыва пласта и ее геометрии, применяется в нефтегазовой области, горном деле. Сущность: осуществляют погружение и установку в скважину в интервале пласта гидроразрыва геофизического прибора, посредством которого осуществляют ее каротаж на угол 360°, и определение пространственного положения трещины гидроразрыва. Производят электрический каротаж скважины с помощью антенного блока, с двух сторон которого осуществляют одновременно сканирование поверхностей скважины сверхвысокочастотными электромагнитными сигналами, обеспечивая зоны сканирования: с одной стороны антенного блока от 0 до 180°, с другой его стороны от 180 до 360°. Определяют геометрические параметры трещины гидроразрыва. Технический результат: упрощение технической системы реализации, повышение точности определения пространственного положения и геометрических параметров трещин гидроразрыва, а также значительное повышение эффективности способа. 1 ил.

СПОСОБ ПЕРЕДАЧИ ЗАБОЙНОЙ ИНФОРМАЦИИ И УСТРОЙСТВО ДЛЯ ЕГО ОСУЩЕСТВЛЕНИЯ

... 1. Способ передачи забойной информации, включающий измерение забойной информации при помощи забойной телеметрической системы, преобразование ее и передачу на наземную приемно-обрабатывающую аппарату по каналу связи, отличающийся тем, что передача информации осуществляется по магнитному каналу связи. 2. Устройство для передачи забойной информации, содержащее, установленную в колонне бурильных или обсадных труб забойную телеметрическую систему со скважинным прибором и подсоединенными к нему источником питания и излучателем, и наземную приемно-преобразовательную аппаратуру, в том числе приемное устройство, соединенное с компьютером, отличающееся тем, что излучатель выполнен в виде передающей катушки, намотанной на наружной поверхности бурильной или обсадной трубы из магнитного материала, соединенной резьбой с корпусом забойной телеметрической системы, передающая катушка соединена одним концом с выходом скважинного прибора, другим - с колонной бурильных или обсадных труб, а наземная приемно-преобразовательная ...

МЕТОД ДИАГНОСТИКИ БУРОВЫХ УСТАНОВОК В ПРОЦЕССЕ ИХЭКСПЛУАТАЦИИ

Метод диагностики буровых установок в процессе их эксплуатации, заключающийся в том, что измеряют нагрузки, действующие на буровые вышки в процессе спускоподъемных операций, полученную информацию обрабатывают и передают по радиоканалу на пульт оператора и блок архивации данных, отличающийся тем, что нагрузку измеряют тензодатчиками, тензодатчики (не менее двух) устанавливают на каждой опоре, измерения проводят одновременно в нескольких точках опоры вышки, количество датчиков выбирают в зависимости от требуемой точности измерения.

ДАТЧИК ДЛЯ ОБНАРУЖЕНИЯ МАГНИТНОГО ПОЛЯ В ЗОНЕ ОБСАДНОЙ ТРУБЫ, ОПУЩЕННОЙ В СКВАЖИНУ

... 1. Способ измерения магнитного поля внутри электропроводной обсадной трубы скважины, при котором электромагнитная энергия распространяется по обсадной трубе на частоте, превышающей примерно 1 Гц, причем способ включает в себя следующие этапы: обеспечивают магнитный приемник, имеющий индуктивную катушку, состоящую из магнитно-проницаемого сердечника и основной обмотки, намотанной вокруг сердечника, объединяют устройство обратной связи с магнитным приемником, располагают магнитный приемник внутри обсадной трубы скважины, формируют электромагнитную энергию снаружи от упомянутой обсадной трубы и направляют указанную энергию с возможностью ее распространения по обсадной трубе на частоте свыше 1 Гц, вследствие чего обеспечивается возможность измерения измеряемого суммарного магнитного поля внутри обсадной трубы в состоянии затухания из-за эффекта обсадной трубы, при этом эффект обсадной трубы возникает в результате взаимодействия между обсадной трубой и магнитно-проницаемым сердечником, и обеспечивают ...

СПОСОБ МЕЖСКВАЖИННОЙ ТОМОГРАФИИ И СИСТЕМЫ, ИСПОЛЬЗУЮЩИЕ УЧАСТОК ОБСАДНОЙ ТРУБЫ ПО МЕНЬШЕЙ МЕРЕ С ОДНИМ УСТРОЙСТВОМ ПЕРЕДАЧИ И ПРИЕМА ДАННЫХ

Изобретение относится к исследованию межскважинного пространства. Техническим результатом является повышение эффективности межскважинного мониторинга. В частности, предложен способ межскважинной томографии, включающий обсаживание первого ствола скважины обсадной трубой, имеющей по меньшей мере одно устройство передачи и приема данных, при этом каждое устройство передачи и приема данных имеет адаптер, сообщающийся с рамочной антенной, которая охватывает наружную сторону обсадной трубы. Способ также включает размещение внутри обсадной трубы токопроводящего тракта, который проходит от наземного интерфейса по меньшей мере к одному устройству передачи и приема данных. Способ также включает обеспечение комплектом из одной или более антенн во втором стволе скважины. Способ также включает получение электромагнитных (ЭМ) измерений для межскважинной томографии с использованием по меньшей мере одного устройства передачи и приема данных и комплекта из одной или более антенн, при этом упомянутое выше ...

Способ определения величины и направления деформации наружной составляющей бугров пучения вечной мерзлоты

Изобретение относится к области геодезического пространственного мониторинга инженерных сооружений и природных объектов и может быть использовано как для наблюдений за осадками и деформациями инженерных сооружений, так и природных объектов (бугров, провалов, холмов, склонов, оползней и т.п.). Заявлен способ определения величины и направления деформации наружной составляющей бугров пучения вечной мерзлоты, включающий создание планово-высотного обоснования, закрепление точек по периметру бугра пучения, выполнение геодезических измерений. Согласно изобретению вышеупомянутые точки по периметру бугра пучения располагают и закрепляют строго по сторонам света север, запад, юг, восток, выполняют бурение скважин, расположенных на вершине бугра пучения, подошве бугра пучения. По закрепленным точкам определяют георадаром примерную границу подземной составляющей бугра пучения, бурение выполняют до определения точных границ подземной составляющей бугра пучения. Выполняют определение координат X, Y, ...

Способ беспроводной передачи энергии и/или информации для контроля и/или управления удаленными объектами

АНТЕННЫ ДЛЯ ИНСТРУМЕНТОВ ГЕОФИЗИЧЕСКОГО ИССЛЕДОВАНИЯ В СТВОЛЕ СКВАЖИНЫ И СПОСОБЫ ИЗГОТОВЛЕНИЯ

УЧАСТОК ОБСАДНОЙ ТРУБЫ, ИМЕЮЩИЙ ПО МЕНЬШЕЙ МЕРЕ ОДНО УСТРОЙСТВО ПЕРЕДАЧИ И ПРИЕМА ДАННЫХ

УСТРОЙСТВО ДЛЯ ИЗМЕРЕНИЯ ДЕБИТА НЕФТЕДОБЫВАЮЩИХ СКВАЖИН

Устройство для измерения дебита нефтедобывающих скважин, содержащее тахометрический генератор переменного тока, установленный в скважине на расстоянии одной насосно-компрессорной трубы от добывающего насоса, отличающееся тем, что информационный сигнал от тахометрического генератора переменного тока передается на поверхность, где в цепь тахометрического генератора последовательно включены катушка индуктивности L и переменная емкость С, а измерительный прибор подключается параллельно к емкости С.

СОЕДИНИТЕЛЬ ИЗЛУЧАТЕЛЯ ТЕЛЕМЕТРИЧЕСКОЙ СИСТЕМЫ СО СКВАЖИННЫМ ПРИБОРОМ

... 1. Соединитель излучателя телеметрической системы с магнитным каналом связи, содержащий корпус, отличающийся тем, что он выполнен в виде переводника, в котором установлен центратор, закрепленный от осевого и радиального смещения. 2. Соединитель по п.1, отличающийся тем, что центратор от радиального смещения фиксирует пустотелая втулка, входящая в поперечное отверстие, выполненное в ребре центратора. 3. Соединитель по п.1 или 2, отличающийся тем, что в теле переводника для соединения вывода катушки с разъемом выполнены продольное и поперечное отверстия, причем поперечное отверстие герметично закрыто пробкой с уплотнительным кольцом. 4. Соединитель по п.1 или 2, отличающийся тем, что полости отверстий и центратора заполнены герметиком. 5. Соединитель по п.3, отличающийся тем, что полости отверстий и центратора заполнены герметиком.

СПОСОБ ОПРЕДЕЛЕНИЯ ПАРАМЕТРОВ ТРЕЩИНЫ ГИДРОРАЗРЫВА ПЛАСТА (ВАРИАНТЫ)

... 1. Способ определения параметров трещины гидроразрыва пласта, включающий использование по меньшей мере одной скважины, оборудованной обсадной трубой, нагнетание в ствол одной из скважин жидкости гидроразрыва под давлением, позволяющим жидкости гидроразрыва создать трещину вокруг скважины и проникнуть в нее и далее через поверхности трещины в зону фильтрации в пласте вокруг трещины, создание численной модели изменения параметров электромагнитного поля, создаваемого прохождением жидкости гидроразрыва через зону фильтрации, для заданных параметров пласта, данных гидроразрыва и предполагаемых параметров трещины, измерение параметров электромагнитного поля, создаваемого прохождением жидкости гидроразрыва через зону фильтрации, последующее сравнение результатов измерений с модельными расчетами и определение параметров трещины на основе обеспечения наилучшего совпадения результатов измерений и модельных расчетов, отличающийся тем, что в процессе гидроразрыва осуществляют измерения параметров электромагнитного ...

Скважинный электромагнитный каротажный инструмент

Изобретение к каротажному оборудованию в области нефтегазового промыслового машиностроения. Техническим результатом является повышение точности измерений электромагнитным каротажным инструментом. Заявлен скважинный электромагнитный каротажный инструмент, содержащий передающую систему для создания магнитного поля, матрицу датчиков магнитного поля для приема вторичного магнитного поля и модуль управления, соединенный с передающей системой и матрицей датчиков магнитного поля. При этом передающая система содержит верхнюю передающую катушку и нижнюю передающую катушку, расположенные над и под матрицей датчиков магнитного поля, соответственно, для создания магнитных полей с противоположными полярностями и противоположными направлениями. Магнитные поля с разными направлениями, создаваемые верхней и нижней передающими катушками, концентрируются, согласно принципу однополярного отталкивания, в месте, где расположена матрица датчиков магнитного поля. Причем матрица датчиков магнитного поля принимает ...

CПOCOБ ПEPEДAЧИ ИHФOPMAЦИИ C ГЛУБИHHOГO ПPИБOPA

Method and apparatus for determining speed and properties of flowing fluids using nmr measurements

Methods and systems employing fiber optic sensors for electromagnetic cross-well telemetry

A tool and method for facilitating communication between a computer apparatus and a device in a drill string

A top drive apparatus for facilitating communication between a computer apparatus and a device in a drill string, particularly, but not exclusively during tripping, includes a drill string comprising a pipe 13 having a threaded box end 140 and a pipe communication element 160 therein. The top drive apparatus has a top drive (30, fig 1) having a main shaft (29, fig 1) and a tool 101 rotationally fast therewith, the tool 101 comprising a threaded pin end 125 having a tool communication element 170 projecting therefrom, such that in use the thread does not have to be made up to obtain a communication between the pipe communication element and the tool communication element, either by induction and most optionally a physical contact therebetween to provide an electrical contact therebetween.

Systems and methods for downhole communication

A system and method for electromagnetic uplink and/or downlink communication are provided. A downhole communication system may include two gap subs, a first 526-1 located at a communication tool, such as an MWD and a second 526-2 located at a rotary steerable system (RSS) 514. An electromagnetic (EM) downlink ignal transmitted from the surface 516 may be received at one or both gap subs 526-21, 526-2. For example, the EM signal may be received directly at the RSS 514 or may be received by the first gap sub 526-1 at the MWD, which may relay the EM signal wirelessly to be received at the second gap sub 526-2 at the RSS 514. In this manner, the EM signal may be received at the RSS, thereby enabling the surface 516 to communicate with the RSS 514. Communication with the RSS 514 may allow the RSS 514 to receive direction and/or information from the surface 516, which may help improve directional drilling of the RSS 514.

Systems and methods for downhole communication

Wireless power and communications cross-bar switch.

Detecting boundary locations of multiple subsurface layers

Systems, methods, and software for detecting boundary locations of multiple subsurface layers are described. In some aspects, the boundaries of multiple subsurface layers in a subterranean region are identified based on measurements associated with multiple different transmitter-receiver spacings. The measurements are generated based on operating multiple transmitters and multiple receivers of a resistivity logging tool at a tool depth in a wellbore in the subterranean region. A first pair of the subsurface boundary locations are determined based on a first measurement associated with a first transmitter-receiver spacing. A second, different pair of the subsurface boundary locations are determined based on a second measurement associated with a second, longer transmitter-receiver spacing. The first pair of subsurface boundary locations reside between the second pair of subsurface boundary locations in the subterranean region.

Method and apparatus for remotely controlling downhole tools using untethered mobile devices

Remote operation of downhole tools in a subterranean wellbore is performed by inserting untethered, mobile devices sequentially into the wellbore. The mobile devices can include motive means, power supply, communication and data storage means, etc. In one embodiment, the method comprises maneuvering a first mobile device into proximity with a downhole tool, the device powering the tool. The first device is then removed, such as by flowing up or dissolving. The now-powered tool is used to perform a test or other operation. A second mobile device is maneuvered into proximity with the downhole tool and data is transferred. The second device is retrieved with the data or, using on¬ board logic devices, provides "if-then" commands to the downhole tool. Alternately, a third mobile device can be used to power and transfer commands to the tool. The method can be used for various tasks, such as opening bypass ports on ICD valves.

LWD resistivity imaging tool with adjustable sensor pads

A logging while drilling tool for measuring a geological formation surrounding a wellbore includes a tool body having one or more sensor pads. Each sensor pad is coupled to the tool body by an extendable coupling that is operable to adjust the radial position of the sensor pad by extending away from or retracting toward the tool body. One or more sensors are mounted to each sensor pads and the sensors are operable to obtain a measurement a property of the formation. The tool also includes a downhole control unit having a transmitter and receiver. The downhole control unit is operable to receive the measurement and transmit the measurement to a surface controller, wherein the transmitted measurement indicates a measurement resolution.

Fiberoptic systems and methods for formation monitoring

A disclosed formation monitoring system includes a casing that defines an annular space within a borehole. An array of electromagnetic field sensors is positioned in the annular space and configured to communicate with the surface via a fiberoptic cable. A computer coupled to the fiberoptic cable receives said measurements and responsively derives the location of any fluid fronts in the vicinity such as a an approaching flood front to enable corrective action before breakthrough. A disclosed formation monitoring method includes: injecting a first fluid into a reservoir formation; producing a second fluid from the reservoir formation via a casing in a borehole; collecting electromagnetic field measurements with an array of fiberoptic sensors in an annular space between said casing and said borehole, said array communicating measurements to a surface interface via one or more fiberoptic cables; and operating on said measurements to locate a front between the first and second fluids.

2D WELL TESTING WITH SMART PLUG SENSORS

An apparatus for characterising the permeability of a formation surrounding a wellbore, comprising: a drillstem test (DST) tool comprising, a packer for isolating a zone of the wellbore, a valve for controlling fluid into and out of the zone via the drill string of the tool and, a pressure gauge for detecting the pressure in the zone; wherein the apparatus further comprises an array of at least two antennas arranged on the tool above the packer such that when in use each antenna of the array aligns with a corresponding pressure sensor placed in the formation to obtain pressure measurements and therefore allow horizontal and vertical permeability to be determined.

METHOD AND SYSTEM FOR TRANSMITTING A DATA FRAME OF AN ELECTROMAGNETIC TELEMETRY SIGNAL TO OR FROM A DOWNHOLE LOCATION

Methods, techniques, and systems for transmitting a data frame of an electromagnetic (EM) telemetry signal to or from a downhole location can be performed using multi- channel transmissions in which at least two different channels at two different frequencies are used to send a long header and the data frame. At least a portion of the long header is transmitted at a first frequency, and at least a portion of the data frame and any remaining portion of the long header not transmitted at the first frequency are transmitted at one or more additional frequencies different from each other and the first frequency. In one example, only two channels are used: one channel is used to transmit all of the long header, another channel is used to transmit all of the data frame, and either of the channels is used to transmit an identifier identifying the type of the data frame.

INTEGRATED COMPUTATIONAL ELEMENT-BASED OPTICAL SENSOR NETWORK AND RELATED METHODS

An optical sensor network utilizing Integrated Computational Elements ("ICE") provides the capability to measure chemical compositions in a variety of application environments in real-time. In one exemplary application, the network comprises a plurality of ICE modules distributed throughout a downhole well environment. The ICE modules are communicably coupled to a computer station which controls the operation and power consumption of the ICE modules. The computer station may selectively activate and deactivate one or more of the ICE modules to regulate power consumption and/or may select the optimal ICE modules to activate at any given time.

ELECTROMAGNETIC BOREHOLE TELEMETRY SYSTEM INCORPORATING A CONDUCTIVE BOREHOLE TUBULAR

An electromagnetic borehole telemetry system for transmitting information between a borehole transceiver and a surface transceiver located at or near the surface of the earth. Tubulars, such as steel casing and liners, are typically set within the well borehole to stabilize the wall of the borehole and to assist in hydraulically isolating penetrated formations. The invention utilizes these tubulars cooperating with one or more signal wires to reduce attenuation and noise in signals transmitted between the borehole and surface transceivers. The one or more signal wires are typically disposed within an annulus formed by the borehole wall and the outside surface of the casing. The one or more signal wires are connected at one end to one or more connection terminals positioned preferably near the bottom a tubular string. Opposing ends of the one or more signal wires are connected to one or more terminals of the surface transceiver. By minimizing signal attenuation and noise, the telemetry system ...

WELLBORE INSPECTION SYSTEM AND METHOD FOR ULTRA-DEEP VERTICAL SHAFT

Disclosed are a wellbore inspection system and method for an ultra-deep vertical shaft. The wellbore inspection system includes a wire rope moving system, inspection robots, a visual image acquisition system, a wireless communication module, a central control system, and an image post-processing system of an upper computer. The wire rope moving system includes a surface wire rope guide rail, an underground wire rope guide rail, a surface wire rope moving device, an underground wire rope moving device, and a wire rope. The visual image acquisition system includes explosion-proof cameras. After image information acquired by the explosion-proof cameras is processed by a lower computer, the processed image is transmitted by a wireless image transmission module to the image post-processing system of the upper computer. The central control system is connected to the inspection robots and the wire rope moving system, and the inspection robots are connected to the central control system.

IMPROVED SENSOR SUB CONFIGURATION

A sensor sub is provided for use in a tubular handling system, the sensor sub being located adjacent to and removably connected to a saver sub pin connection. The sensor sub collects raw data relating to operation of the tubular handling system, digitizes the raw data and transmits the raw data to a remote receiver. The sensor sub is powerable by one or more commercially available lithium batteries. A battery holder is also provided having a housing for housing batteries in a hazardous environment, wherein the batteries are replaceable within the battery holder while the battery holder remains in the hazardous environment. Finally, a method of replacing a battery in a hazardous environment is also provided.

INTEGRATED DOWNHOLE SYSTEM WITH PLURAL TELEMETRY SUBSYSTEMS

COLLABORATIVE TELEMETRY

A method may include providing one or more telemetry transmission systems, the one or more transmission systems comprising one or more receivers and one or more transmitters. The method may also include transmitting a first synchronization sequence from the one or more telemetry transmission systems, the first synchronization sequence transmitted in a first channel, and the first synchronization sequence being at least a portion of a first telemetry signal. In addition, the method may include transmitting a second synchronization sequence the one or more telemetry transmission systems, the second synchronization sequence transmitted in a second channel, and the second synchronization sequence being at least a portion of a second telemetry signal. The first and second synchronization sequences may be transmitted simultaneously or at a predetermined time difference. The method may include receiving the first synchronization sequence at the one or more receivers, and receiving the second synchronization ...

METHOD FOR PLACEMENT OF SURFACE ELECTRODES FOR ELECTROMAGNETIC TELEMETRY

A method for placement of electrodes includes determining spatial distribution of a signal caused by generating an electromagnetic field in an instrument disposed in drill string used to drill a wellbore. The electromagnetic field comprises encoded measurements from at least one sensor associated with the instrument. Voltages induced by noise are measured across at least one pair of spaced apart electrodes placed at a plurality of positions spaced apart from a surface location of the wellbore. A spatial distribution of noise is estimated using the measured voltages. Positions for placement of at least two electrodes are selected using the spatial distribution of signal and the spatial distribution of noise.

SUB-SURFACE ELECTROMAGNETIC TELEMETRY SYSTEMS AND METHODS

A method may include drilling a section of a first wellbore and casing a section of a first wellbore. The method may include lowering a downhole receiving system into the first wellbore to a first wellbore depth and drilling at least one section of a second wellbore. In addition, the method may include positioning an EM telemetry system in the at least one section of the second wellbore and transmitting an EM telemetry signal from the EM telemetry system. The method may include receiving the EM telemetry signal with the downhole receiving system.

ENERGY EFFICIENT METHOD OF RETRIEVING WIRELESS NETWORKED SENSOR DATA

A method of communicating in a wireless network. Devices are positioned such that each device communicates with one or more other devices. Some of the devices include one or more sensors. Each device is a node in the wireless network. At one of the devices, values are recorded from the sensors associated therewith. At least some of the devices, one or more recorded values from the sensors associated with said each device, and/or a sensor associated with at least one other device, are processed in accordance with a variable instruction set, to thereby generate a processed dataset. At each device, at least one of recorded values, a processed dataset associated with another device, or a revision to the variable instruction set are received from another device. At least one of the one or more recorded values, and one or more processed datasets, are transmitted at each device to another device.

MULTI-MODE CONTROL OF DOWNHOLE TOOLS

A method for establishing downlink telemetry communication to a downhole system involves placing into a drillstring a telemetry transcoder, and advancing the drillstring so the telemetry transcoder is below the surface. The method then transmits downlink EM telemetry signals from surface equipment. These signals are received at the telemetry transcoder which retransmits the signals as mud pulse signals. The mud pulse signals are received at the downhole system.

METHOD AND SYSTEM FOR PERFORMING COMMUNICATIONS DURING CEMENTING OPERATIONS

A method and system are described for communicating within a system, which may be along tubular members and used during cementing installation operations. The method includes constructing a communication network and installing the communication nodes along a wellbore. The communication nodes are used to monitor the fluids adjacent to the communication nodes during the cementing installation operations. Once the cement is installed, the cementing installation operations may be used for hydrocarbon operations, such as hydrocarbon exploration, hydrocarbon development, and/or hydrocarbon production.

DOWNHOLE CABLES WITH BOTH FIBER AND COPPER ELEMENTS

Provided is a method of manufacturing a downhole cable, the method including, forming a helical shape in an outer circumferential surface of a metal tube, the metal tube having a fiber element housed therein, and stranding a copper element in a helical space formed by the metallic tube. Also provided is a downhole cable including, a metallic tube having a helical space in an outer circumferential surface thereof, wherein the metallic tube has a fiber element housed therein, and a copper element disposed in a helical space formed by the steel tube. Double-tube and multi-tube configurations of the downhole cable are also provided.

ELECTROMAGNETIC COMMUNICATIONS SYSTEM AND METHOD FOR A DRILLING OPERATION

A wireless communications system for a downhole drilling operation comprises surface communications equipment and a downhole telemetry tool. The surface communications equipment comprises a surface EM communications module with an EM downlink transmitter configured to transmit an EM downlink transmission at a frequency between 0.01 Hz and 0.1 Hz. The downhole telemetry tool is mountable to a drill string and has a downhole electromagnetic (EM) communications unit with an EM downlink receiver configured to receive the EM downlink transmission. The downhole EM communications unit can further comprise an EM uplink transmitter configured to transmit an EM uplink transmission at a frequency greater than 0.5 Hz, in which case the surface EM communications module further comprises an EM uplink receiver configured to receive the EM uplink transmission. More particularly, the downhole EM uplink transmitter can be configured to transmit the EM uplink transmission at a frequency that is at least ten ...

ROBUST TELEMETRY REPEATER NETWORK SYSTEM AND METHOD

A robust network telemetry repeater system exploits the repeater structure of data propagation and transmission and reception bidirectionality to increase network robustness. For example, multiple perceived receive attempts are created with no additional overhead. The system can be configured whereby nodes "hear" the transmissions of both adjacent and non- adjacent nodes forming implicit acknowledgement ("Acks"), and originating nodes can retransmit until implicit acknowledgments ("Acks") are "heard," indicating a successful link relay. Implicit acknowledgment can be applied to bidirectional networks, and bidirectional action can enable all nodes in the network to know the status of all other nodes.

AN APPARATUS FOR WELL LOGGING

An apparatus for well logging that includes a drill collar body and an array of antennas is described. The array of antennas includes four transmitting antennas (T1, T2, T3 and T4), and four receiving antennas (R1, R2, R3 and R4). The array of antennas is installed from a drill-collar-tail to a drill- head of the drill collar body in the following order: the receiving antenna R3, the transmitting antenna T3, the transmitting antenna T1, the receiving antenna R1, the receiving antenna R2, the transmitting antenna T2, the transmitting antenna T4, and the receiving antenna R4. The middle point between the receiving antennas R1 and R2 is the measurement point. The transmitting antennas T1 and T2 are installed symmetrically about the measurement point, and the transmitting antennas T3 and T4 are installed symmetrically about the measurement point. The installation angles of the receiving antennas R3 and R4 are respectively set to be 45°and -45° relative to an axis of the drill-collar. Any combination ...

APPARATUS AND METHODS FOR DETERMINING SURFACE WETTING OF MATERIAL UNDER SUBTERRANEAN WELLBORE CONDITIONS

Methods and apparatuses for determining surface wetting of metallic materials at downhole wellbore condition with fixed or changing well fluids are disclosed. In general, the methods according to the disclosure include carrying out an electrical impedance spectroscopy ("EIS") for a system simulating downhole conditions for the wetting of a surface by simultaneously dynamically moving electrodes exposed to the well fluid while measuring the changes in electrical characteristics between the electrodes.

DOWNHOLE SHORT WAVELENGTH RADIO TELEMETRY SYSTEM FOR INTERVENTION APPLICATIONS

A telemetry system and method of downhole communication is disclosed. A first electromagnetic signal propagates through a first annular region between a work string and a wellbore wall and is received at an electromagnetic receiver of a repeater. A second electromagnetic signal related to the received first electromagnetic signal is created at a processing unit coupled to the electromagnetic receiver. The second electromagnetic signal is transmitted from a transmitter of the repeater into a second annular region between the work string and the wellbore wall. The repeater may be detachably coupled to the work string and may facilitate communication between a first communication device at one of an uphole location and a downhole location and a second communication device at another of the uphole location and the downhole location.

METHOD AND APPARATUS FOR CONTROLLING A DOWNHOLE TOOL

A downhole processing apparatus (44) for controlling a downhole tool (100) in a well is disclosed and comprises a downhole processing device (202) providing a first timing operation (TIMER 1; 302) and a second timing operation (TIMER 2; 304); the first timing operation (TIMER 1; 302) being associated with a first downhole sensor (60) capable of at least receiving a signal sent via a first transmission mechanism; the second timing operation (TIMER 2; 304) being associated with a second downhole sensor (210) capable of at least receiving a signal sent via a second transmission mechanism; a data storage device capable of storing data received from the first (60) and second (210) downhole sensors; and the downhole processing device (202) being adapted to be triggered by the first (TIMER 1; 302) and second (TIMER 2; 304) timing operations to check the data storage device, at least once during the respective first (TIMER 1; 302) and second (TIMER 2; 304) timing operations, for data received from ...

DEDICATED WIREWAYS FOR COLLAR-MOUNTED BOBBIN ANTENNAS

A system to protect a downhole antenna from fluid penetration, in some embodiments, comprises a collar; a bobbin antenna, mounted on the collar, including multiple coil slots on an outer surface of the bobbin antenna and including one or more intra-bobbin wireways between at least one of the coil slots and an outlet of the bobbin antenna; and a collar wireway that is dedicated to the bobbin antenna.

REPEATER FOR A WELLBORE

A repeater system provided in a wellbore including a plurality of communication units spaced at intervals along a length of a wellbore, the communication units being communicatively coupled via a transmission medium. The communication units are configured to relay data from one communication unit to another communication unit selected from the plurality of communication units along the transmission medium, wherein at least one of the communication units is hopped over as data is relayed across the plurality of communication units along the length of the wellbore.

ELECTROMAGNETIC PULSE DOWNHOLE TELEMETRY

An apparatus for transmitting electromagnetic (EM) telemetry data from a downhole location to surface comprising: an EM signal transmitter configured to generate positive and negative polarity EM pulses corresponding to a telemetry signal; and an electronics subassembly communicative with the EM signal transmitter and comprising a processor and a memory having encoded thereon program code executable by the processor to perform a method comprising encoding measurement data into an EM telemetry signal using a modulation scheme comprising mapping a symbol set to at least one positive polarity EM pulse and one negative polarity EM pulse; and sending a control signal to the EM signal transmitter to generate EM pulses corresponding to the EM telemetry signal. The EM signal transmitter can comprise an H-bridge circuit electrically coupled to positive and negative ends of a gap sub such that applying a voltage across a positive pathway of the H-bridge circuit generates the positive polarity EM ...

TELEMETRY OPERATED SETTING TOOL

A setting tool for hanging a tubular string includes: a mandrel having an upper portion and a lower portion for extending into the tubular string; a housing connected to the mandrel upper portion; and a bonnet. The bonnet is: for receiving an upper end of the tubular string, disposed along the mandrel, and linked to the housing. The setting tool further includes: an actuator for stroking the bonnet relative to the mandrel and the housing, thereby setting a hanger of the tubular string; an electronics package in communication with the actuator for operating the actuator in response to receiving a command signal; and a latch. The latch is: connected to the mandrel lower portion, operable between an extended position and a retracted position, for being restrained in the retracted position by being disposed in the tubular string, and extendable by being removed from the tubular string.

DUAL-MODE CASING COLLAR LOCATOR (CCL) TOOL, MODE SELECTION CIRCUIT AND METHOD

Provided herein are various embodiments of casing collar locator (CCL) tools, circuits and methods, which enable a CCL tool to selectively operate in passive or active mode. More specifically, a dual-mode CCL tool is provided herein with a mode selection circuit, which may be coupled between a coil of the CCL tool and a wireline of a well survey system. The mode selection circuit may be generally configured to detect a voltage on the wireline, connect the coil of the CCL tool to the wireline if the detected voltage is less than a threshold voltage, and connect the coil of the CCL tool to an amplifier circuit if the detected voltage is greater than or equal to the threshold voltage. The mode selection circuit described herein therefore enables a single CCL tool to be used for a variety of different downhole operations, including but not limited to wireline logging and well perforation jobs.

SURFACE COMMUNICATION DEVICE AND METHOD FOR DOWNHOLE TOOL

A device for communicating with a downhole measurement tool includes a processor module comprising a set of commands and configured to issue a command from the set to the downhole tool and receive a corresponding reply from the downhole tool. The set of commands includes at least one of a command to switch the downhole measurement tool between a sleep mode and an active mode and a command to download data from the downhole measurement tool. The device includes a transceiver module coupled to the processor module and an antenna coupled to the transceiver module. The antenna and transceiver module are configured to transmit commands and replies between the processor module and the downhole measurement tool.

COMMUNICATION THROUGH AN ENCLOSURE OF A LINE

A communication system can include a transmitter which transmits a signal, and at least one sensing device which receives the signal, the sensing device including a line contained in an enclosure, and the signal being detected by the line through a material of the enclosure. A sensing system can include at least one sensor which senses a parameter, at least one sensing device which receives an indication of the parameter, the sensing device including a line contained in an enclosure, and a transmitter which transmits the indication of the parameter to the line through a material of the enclosure. Another sensing system can include an object which displaces in a subterranean well. At least one sensing device can receive a signal from the object. The sensing device can include a line contained in an enclosure, and the signal can be detected by the line through a material of the enclosure.

METHOD AND APPARATUS FOR TRANSMITTING SENSOR RESPONSE DATA AND POWER THROUGH A MUD MOTOR

Apparatus and methods for establishing electrical communication between an instrument subsection disposed below a mud motor and an electronics sonde disposed above the mud motor in a drill string conveyed borehole logging system. Electrical communication is established via at least one conductor disposed within the mud motor and the electronics sonde. The link can be embodied as a current coupling link, a magnetic coupling ling, an electromagnetic telemetry ling and a direct electrical contact link. Two way data transfer is established in all link embodiments. Power transfer is also established in all but the electromagnetic telemetry link.

COMMUNICATIONS MODULE FOR ALTERNATE PATH GRAVEL PACKING, AND METHOD FOR COMPLETING A WELLBORE

A communications module and methods for downhole operations having utility with production of hydrocarbon fluids from a wellbore, including at least one alternate flow channel and an electrical circuit. Generally, the electrical circuit is pre-programmed to (i) receive a signal and, in response to the received signal, deliver an actuating command signal. The communications module further has a transmitter-receiver. The communications module allows a downhole tool to be actuated within a completion interval of a wellbore without providing an electric line or a working string from the surface. The tool may be actuated in response to a reading from a sensing tool, or in response to a signal emitted in the wellbore by a downhole carrier, or information tag.

POWER GENERATING COMMUNICATION DEVICE

A self-powered borehole communication assembly including a first electrode member having a first electrode potential and a second electrode member having a second electrode potential different than the first electrode potential. The first and second electrodes form an electrochemical cell when disposed in a borehole fluid that is at least partially electrolytic. The electrochemical cell is operatively arranged for producing a current and a voltage with at least one of the current or the voltage configured to directly convey information related to at least one borehole condition, property, or parameter. A method of communicating is also included.

METHOD AND SYSTEM FOR PREDICTING A DRILL STRING STUCK PIPE EVENT

Predicting a drill string stuck pipe event. At least some of the illustrative embodiments are methods including: receiving a plurality of drilling parameters from a drilling operation; applying the plurality of drilling parameters to an ensemble prediction model comprising at least three machine-learning algorithms operated in parallel, each machine-learning algorithm predicting a probability of occurrence of a future stuck pipe event based on at least one of the plurality of drilling parameters, the ensemble prediction model creates a combined probability based on the probability of occurrence of the future stuck pipe event of each machine-learning algorithm; and providing an indication of a likelihood of a future stuck pipe event to a drilling operator, the indication based on the combined probability.

DOWNHOLE ELECTROMAGNETIC TELEMETRY SYSTEM UTILIZING ELECTRICALLY INSULATING MATERIAL AND RELATED METHODS

A downhole electromagnetic telemetry system and method whereby electrically insulating material is placed above and/or below an electrical current launching device or receiver along a well string in order to extend the range of the telemetry system, increase the telemetry rate, and/or reduce downhole power requirements.

WIRELESS ACTIVATABLE VALVE ASSEMBLY

A wireless actuation system comprises a transmitter, an actuation system comprising a receiving antenna, and one or more sliding members transitional from a first position to a second position. The transmitter is configured to transmit an electromagnetic signal, and the sliding member prevents a route of fluid communication via one or more ports of a housing when the sliding member is in the first position. The sliding member allows fluid communication via the one or more ports of the housing when the sliding member is in the second position, and the actuation system is configured to allow the sliding member to transition from the first position to the second position in response to recognition of the electromagnetic signal by the receiving antenna.

DOWNHOLE ELECTROMAGNETIC TELEMETRIC DEVICE

OPTIMIZATION OF TRANSMISSION WELL DATA WITH THE HELP OF NADDOLOTNYKh SENSORS AND UNITS

СИСТЕМА ПЕРЕДАЧИ ТЕЛЕМЕТРИЧЕСКОЙ ИНФОРМАЦИИ

Изобретение относится к системам передачи телеметрической информации (ТИ) по цепям питания погружных электродвигателей насосных установок. Система передачи ТИ состоит из подземного передающего устройства (ППУ), подключенного между нулем "звезды" обмоток электродвигателя (ОЭ) и его заземленным корпусом, и наземного приемного устройства (НПУ), подключенного между нулем "звезды" вторичных обмоток трехфазного трансформатора (ТТ) и его заземленным корпусом, при этом ОЭ подключены к вторичным обмоткам ТТ через кабель подачи питания. ППУ содержит стабилизатор напряжения (СН), устройство сбора и передачи информации (УСПИ), датчики, электронный ключ, управляемый УСПИ и подключённый параллельно СН для передачи ТИ. Выход СН соединен с датчиками и УСПИ, при этом ППУ подключено к нулю "звезды" ОЭ через конденсатор, подключённый ко входу СН. НПУ содержит источник переменного напряжения, питающий ППУ, подключённый последовательно с ним резистор, устройство приема и обработки информации (УПОИ), при этом ...

OPTIMIZATION OF TRANSMISSION WELL DATA WITH THE HELP OF NADDOLOTNYKh SENSORS AND UNITS

ЗОНД ДЛЯ ПОДЗЕМНОГО БУРЕНИЯ, СИСТЕМА И БУРОВОЙ ПОДЗЕМНЫЙ СНАРЯД, СОДЕРЖАЩИЕ УКАЗАННЫЙ ЗОНД, А ТАКЖЕ СПОСОБ ПОДЗЕМНОГО БУРЕНИЯ

Снаряд для применения в подземном бурении содержит глубинный зонд, имеющий генератор сигналов телеметрической системы с электромагнитным каналом связи и электрические контакты для передачи телеметрических сигналов из генератора сигналов телеметрической системы с электромагнитным каналом связи в первую и вторую части электрического разделителя в бурильной колонне. Наружная поверхность зонда и внутренняя поверхность электрического разделителя покрыты слоями электроизоляционного материала. Пути электропроводности внутри электрического разделителя устранены, что повышает эффективность телеметрии с электромагнитным каналом связи.

НАЗЕМНАЯ СВЯЗЬ СО СКВАЖИННЫМИ ПРИБОРАМИ

Предложены способ и устройство для передачи данных в скважинный прибор или из него, когда прибор находится на поверхности или возле нее, используя беспроводной канал передачи данных. Скважинный прибор содержит стыковочный переводник с трубчатой секцией с первой и второй продольно разнесенными электропроводными частями, которые электрически изолированы друг от друга. Электромагнитный телеметрический передатчик подключен для приложения разности потенциалов между первой и второй электропроводными частями. Однопроводная шина обеспечивает обмен данными между одной из первой и второй электропроводных частей и процессором для обработки данных.

ОПТИМИЗАЦИЯ ПЕРЕДАЧИ СКВАЖИННЫХ ДАННЫХ С ПОМОЩЬЮ НАДДОЛОТНЫХ ДАТЧИКОВ И УЗЛОВ

Данные передают на поверхностное оборудование от датчиков в местоположении в скважине возле бурового долота. Связь с поверхностным оборудованием может быть прямой или может проходить через ряд узлов. Узлы в некоторых случаях логически перенастраивают для достижения желаемых скоростей передачи данных, достижения целей управления питанием и/или компенсации вышедших из строя узлов.

Non-contact electromagnetic coupling digital differential communicating device suitable for well drilling rod

The invention discloses a non-contact electromagnetic coupling digital differential communicating device suitable for a well drilling rod. The device comprises coupling modules, a locking module, a differential drive circuit module and a drilling rod communicating module. The non-contact electromagnetic coupling digital differential communicating device has the advantages that non-contact coupling differential communication between fast interconnecting equipment are achieved by non-contact signal transmission between the two coupling modules through electromagnetic induction; the problems of communication reliability due to the fact that in traditional oil drilling, the mechanical communication plug at the drilling rod connection is prone to abrasion or loosening and electrolyte permeates into the gap of the plug.

Signal processing method and system for resistivity measurement of electromagnetic waves while drilling

Underground ropeless testing system for oil well

The embodiment of the invention provides an underground ropeless testing system for an oil well. The underground ropeless testing system comprises a wireless tester and a self-generating set, wherein the wireless tester comprises an underground tester, a sensor group, an underground test end circuit and an electromagnetic wave transmitter, wherein the sensor group is arranged on the underground tester, the underground test end circuit is connected with the sensor group and used for amplifying and converting production data collected by the sensor group; and the electromagnetic wave transmitter is connected with the underground test end circuit, and used for transmitting the processed production data to a ground processing system. The sensor group, the underground test end circuit and the electromagnetic wave transmitter are arranged on the underground tester, thus ropeless directly-reading test of underground production data of a pumping machine is realized, and the problems of high cost ...

Be applied to wireless data teletransmission signal enhancement equipment of oil gas probing

63 Gamma energy spectrum three-probe logging instrument

High-temperature resistant underground self-powered signal generator

Raise boring machine communication system and control method thereof

Method for detecting stratigraphical boundary by using non-rotating tool

Methods and apparatus for communicating across casing

Remote logging operation method and system

The invention provides a remote logging operation method and system. The method comprises the following steps: establishing a remote data acquisition unit and a well site data acquisition unit; the remote data acquisition unit and the well site data acquisition unit are communicated based on a remote transmission network; the remote data acquisition unit issues a control instruction to the well site data acquisition unit, simultaneously acquires data and sends logging data to the real-time database, so that remote logging data acquisition is realized, and well site logging equipment and data acquisition can be controlled at a remote end under the condition of not depending on well site operation logging acquisition software; the system not only collects data of ground equipment and downhole instruments of a logging system, but also supports remote control operation and data collection of the logging winch, the number of well site operation engineers and the number of winch workers can be ...

método de detecção de filtrado de lama sintética ou de determinação de contaminação de filtrado em um fluido de poço abaixo, sistema para a determinação da contaminação de filtrado e método de análise utilizando espectroscopia

METHOD AND APPARATUS FOR REMOTELY CONTROLLING DOWNHOLE TOOLS USING UNTETHERED MOBILE DEVICES

ELECTROMAGNETIC COMMUNICATIONS SYSTEM AND METHOD FOR A DRILLING OPERATION

A wireless communications system for a downhole drilling operation comprises surface communications equipment and a downhole telemetry tool. The surface communications equipment comprises a surface EM communications module with an EM downlink transmitter configured to transmit an EM downlink transmission at a frequency between 0.01 Hz and 0.1 Hz. The downhole telemetry tool is mountable to a drill string and has a downhole electromagnetic (EM) communications unit with an EM downlink receiver configured to receive the EM downlink transmission. The downhole EM communications unit can further comprise an EM uplink transmitter configured to transmit an EM uplink transmission at a frequency greater than 0.5 Hz, in which case the surface EM communications module further comprises an EM uplink receiver configured to receive the EM uplink transmission. More particularly, the downhole EM uplink transmitter can be configured to transmit the EM uplink transmission at a frequency that is at least ten ...

SCALABLE COMMUNICATION SYSTEM FOR HYDROCARBON WELLS

A scalable communication system for data transmission in oil and gas well applications. The communication system includes a high-speed fiber optic line connecting a surface module to a downhole module. The downhole module is further connected to a tool bus which in turn is connected to one or more tool modules. Each tool module permits communication of data to and/or from one or more downhole tools. A broadband signal comprising multiple channels may be used to transmit data to and from the tool modules.

METHODS AND APPARATUSES FOR SYNCHRONIZATION OF DOWNHOLE TOOL WITH REMOTE TRANSMITTERS AND SENSORS

The present disclosure includes an apparatus and method for operating a downhole tool in a borehole. The apparatus may include a downhole tool that may include at least one second clock, which may be synchronized to a first clock by way of a modulator/demodulator device. The downhole tool may be configured to estimate a parameter of interest of an underground feature. The underground feature may relate to one or more of: a borehole, a casing, or an earth formation. The downhole tool may comprise two or more sections that are configured to operate synchronously when the one or more second clocks are synchronized with the first clock. The modulator/demodulator may include a modem associated with the first clock, a modem associated with the at least one second clock, and a low frequency conductor between the two modems. The method includes using the apparatus.

INTRA-BOTTOM HOLE ASSEMBLY (BHA) WIRELESS COMMUNICATION SYSTEM

A method is disclosed for receiving, from a downhole system, data at a transmitter module of an intra-bottom hole assembly (BHA), wherein the transmitter module comprises a magnetic transmission antenna; transmitting, via a wireless short-range communication using the magnetic transmission antenna, the data to a receiver module of the intra-BHA, wherein the transmitter module and the receiver module form an intra-BHA network using the wireless short-range communication; receiving, via the wireless short-range communication, the data at the receiver module; transmitting the data to a measurement while drilling (MWD) tool; receiving, at the MWD tool, the data; and transmitting, via a type of telemetry, the data from the MWD tool to a surface processor.

WINDOW CORE FOR GAMMA RAY DETECTION IN A DOWNHOLE TOOL

A downhole tool includes a window cap located in a cover that is positioned between an electromagnetic radiation detector in the downhole tool and a geological formation into which a borehole is formed and where the downhole tool is to be positioned. The electromagnetic radiation detector is to detect an electromagnetic radiation from the geological formation. The downhole tool includes a window core positioned behind the window7 cap relative to an external environment of the downhole tool, wherein the window core is positioned between the window cap and the electromagnetic radiation detector.

METHOD OF IMAGING USING AZIMUTHALLY RESOLVED NMR WHILE DRILLING

A nuclear magnetic resonance (NMR) sensor and methods and systems for use are provided. The method comprises disposing a nuclear magnetic resonance (NMR) sensor into a borehole, the NMR sensor comprising a magnet assembly to create a static magnetic field and a first transversal-dipole antenna having an azimuthally selective response function. The method further comprises, while rotating the NMR sensor, initiating azimuthally selective NMR excitation in at least one sensitivity region at a first frequency using the first transversal-dipole antenna and the magnet assembly, wherein the at least one sensitivity region is determined by the static magnetic field and the RF magnetic field. The method then comprises acquiring one or more azimuthally selective NMR signals at the first frequency using the first transversal-dipole antenna.

EXPANDABLE MESHED COMPONENT FOR GUIDING AN UNTETHERED DEVICE IN A SUBTERRANEAN WELL

Embodiments provide an expandable meshed component for guiding an untethered measurement device used in a subterranean well. The expandable meshed component includes an uphole radial portion, an intermediate radial portion, a downhole radial portion, an outer meshed wall, and an inner meshed wall. The expandable meshed component has a density less than a fluidic component occupying the space. A method for guiding an untethered measurement device used in a subterranean well includes deploying a compressed expandable meshed component tethered to the untethered measurement device, disconnecting the compressed expandable meshed component and the untethered measurement device, and releasing a sleeve surrounding the compressed expandable meshed component such that the expandable meshed component expands, ascends, and fits into an annulus. 1. An expandable meshed component for guiding an untethered measurement device used in a subterranean well ascending from a space provided by a wellbore wall and a terminus of a casing , the expandable meshed component , in an expanded configuration , comprising:an uphole radial portion;an intermediate radial portion, the intermediate radial portion having an outer diameter less than an inner diameter of the uphole radial portion, the intermediate radial portion having an inner diameter less than an outer diameter of the casing;a downhole radial portion, the downhole radial portion having an outer diameter greater than an outer diameter of the uphole radial portion;an outer meshed wall; andan inner meshed wall,wherein the expandable meshed component has a density less than a fluidic component occupying the space.2. The expandable meshed component of claim 1 , wherein a radial gap between the outer diameter of the downhole radial portion and a diameter of the wellbore wall is less than a diameter of the untethered measurement device.3. The expandable meshed component of claim 1 , wherein the uphole radial portion comprises at least two ...

Apparatus and method for aligning downhole measurements

Apparatuses and methods are described, such as for aligning downhole measurements. Apparatuses and methods include an arrangement of at least two tilted transmitters and at least one tilted receiver along a longitudinal axis of the tool. A first and second plurality of azimuthal measurements are processed to provide a first and a second plurality of higher order mode signals configured to be time-shifted.

Alternating polarity of casing-side antennas in a wellbore

An antenna system can include casing-side antennas and a full wave rectifier. The casing-side antennas can be coupled to a casing string that is positioned in a wellbore for communicatively coupling to a tubing-side antenna positioned in the wellbore. Each of the casing-side antennas can include a conductive wire positioned to carry current that can be induced on the conductive wire in response to an electromagnetic field from the tubing-side antenna. A direction, relative to a common antenna junction point, of the current on the conductive wire can be opposite to the direction, relative to the common antenna junction point, in which an adjacent casing-side antenna is positioned to carry current induced in response to the electromagnetic field. The full-wave rectifier can be conductively coupled to the casing-side antennas for converting alternating current that can be generated on the casing-side antennas into direct current.

Self-Winding Power Generating Systems and Methods for Downhole Environments

Self-winding power generating device, system, and method are disclosed. The device includes a mechanical winding knob for receiving mechanical energy from a downhole environment, a gear train including a plurality of gears engaged with each other, wherein a first gear in the gear train is operatively connected to the mechanical winding knob, and configured to receive mechanical energy from the mechanical winding knob and transfer the mechanical energy to a second gear in the gear train, a spiral spring attached to one of the gears in the gear train, the spiral spring configured to self-wind and store the mechanical energy upon receiving the mechanical energy from the first gear, and a power generation unit configured to receive the mechanical energy from a last of the plurality of gears and convert the mechanical energy into electrical energy.

RESONANT RECEIVER FOR ELECTROMAGNETIC TELEMETRY

A resonant receiver for electromagnetic telemetry of wellbore-related data can be used to improve signal reception for transmitting or receiving low-amplitude downhole signals that include noise. A system can comprise a surface assembly with an antenna for wirelessly communicating signals with equipment positioned downhole in a wellbore. The surface assembly can comprise an amplifier and a tank circuit operable to resonate at a resonant frequency to pass a received signal at the resonant frequency to the amplifier while also shunting noise outside of the resonant frequency to ground. In some embodiments, a downhole transceiver in wireless communication with the surface assembly can comprise a similar tank circuit and amplifier.

METHODS AND SYSTEMS WITH DOWNHOLE SYNCHRONIZATION BASED ON A DIRECT DIGITAL SYNTHESIZER (DDS)

A downhole system includes a first module having a transmitter that transmits at least one sync control signal. The system also includes a second module having a sync module with a direct digital synthesizer (DDS). The sync module analyzes the at least one sync control signal to identify at least one of a sync frequency and a sync phase. The DDS adjusts a local receiver clock based on the identified at least one of a sync frequency and a sync phase.

In-cutter sensor LWD tool and method

An instrumented cutter including a polycrystalline diamond table bonded to a substrate with a sensor, for monitoring the condition of the polycrystalline compact diamond table, embedded in the substrate. Further the instrumented cutter includes a wireless transmitter equipped with a power supply to power to the wireless transmitter.

DOWNHOLE INDUCTIVE TRANSMISSION COUPLER WITH NONLINEAR COIL

A transmission element for a downhole tool comprising an annular housing and an annular ferrite channel within the annular housing. An annular nonlinear coil may be disposed within the annular ferrite channel, and the nonlinear coil may be connected to a cable running within the downhole tool. The housing may be an annular groove or recess within the tool, an annular metal trough, or an annular polymeric block. The polymeric block may comprise a composite of a polymer and a volume of ferrite elements comprising Fe and Mn. The annular nonlinear coil may comprise a wave, a helix, a twisted pair of wires, a transformer comprising a coil and a metal core, or a combination thereof. The polymeric block may comprise and bumper on its periphery and a void opening within the block proximate the bumper. The ferrite channel and the coil may be molded within the polymeric block.

Наддолотный модуль для измерений геофизических и технологических параметров в процессе бурения с электромагнитным каналом связи

Предлагаемая полезная модель относится к области геофизических исследований скважин, а именно к приборам для измерений геофизических и технологических параметров в процессе бурения, в частности для измерения физико-механических и фильтрационно-емкостных свойств горных пород и геонавигации. Задачей полезной модели является расширение функциональных возможностей наддолотного модуля (НДМ) за счет использования дополнительного измерительного средства на основе акустического импедансного каротажа, обеспечивающего определение физико-механических и фильтрационно-емкостных свойств сложных по геологическому строению горных пород. НДМ содержит корпус с центральным промывочным отверстием, на котором размещен центральный электрод, расположенный между изоляторами и электрически изолированный от корпуса, в котором расположены электрические схемы, измерительные датчики, источник питания и передающее устройство, и снабжен зондом импедансного акустического каротажа, содержащим излучатель низкочастотных упругих колебаний, подключенный к блоку управления и обработки данных, содержащему в своем составе задающий генератор, генератор токовых импульсов, усилитель мощности токовых импульсов, коммутатор управления режимом излучения и приема, счетчик токовых импульсов, автономный источник питания, при этом выход счетчика токовых импульсов подсоединен к центральному электроду НДМ. РОССИЙСКАЯ ФЕДЕРАЦИЯ (19) RU (11) (13) 168 123 U1 (51) МПК E21B 47/12 (2012.01) G01V 1/52 (2006.01) G01V 11/00 (2006.01) ФЕДЕРАЛЬНАЯ СЛУЖБА ПО ИНТЕЛЛЕКТУАЛЬНОЙ СОБСТВЕННОСТИ (12) ФОРМУЛА ПОЛЕЗНОЙ МОДЕЛИ К ПАТЕНТУ РОССИЙСКОЙ ФЕДЕРАЦИИ (21)(22) Заявка: 2016131985, 03.08.2016 (24) Дата начала отсчета срока действия патента: 03.08.2016 (73) Патентообладатель(и): Камалетдинов Талгат Раисович (RU), Шайхутдинов Рамиль Анварович (RU) 18.01.2017 Приоритет(ы): (22) Дата подачи заявки: 03.08.2016 Адрес для переписки: 452614, Рес. Башкортостан, г. Октябрьский, ул. Свердлова, 34, кв. 16, Гуторову Ю.А. 1 6 8 1 2 3 R U (57) ...

Устройство для токоподвода к электробуру при бурении скважин

Полезная модель может быть использовано для токоподвода и передачи сигналов в скважину и из скважины в процессе бурения. Устройство для токоподвода к электробуру содержит КС (1), длина которых равна длине бурильной трубы БТ (2), и имеющие электроконтактные разъемы (3) и (4), узел (5) радиальной и осевой фиксации КС (1). Устройство снабжено жесткими герметичными корпусами К (7), в каждом из которых зафиксирована КС (1), и узлом (8) герметичного соединения К (7). К (7) установлены в БТ (2) с возможностью осевого перемещения. Исключается возможность механического повреждения кабельной секции при монтаже и эксплуатации, обеспечивается надежное соединение разъемов. 4 з.п. ф-лы, 2 ил. РОССИЙСКАЯ ФЕДЕРАЦИЯ (19) RU (11) (13) 179 962 U1 (51) МПК E21B 47/12 (2012.01) E21B 17/02 (2006.01) ФЕДЕРАЛЬНАЯ СЛУЖБА ПО ИНТЕЛЛЕКТУАЛЬНОЙ СОБСТВЕННОСТИ (12) ОПИСАНИЕ ПОЛЕЗНОЙ МОДЕЛИ К ПАТЕНТУ (52) СПК E21B 47/12 (2006.01); E21B 17/02 (2006.01) (21)(22) Заявка: 2018101047, 11.01.2018 (24) Дата начала отсчета срока действия патента: Дата регистрации: 29.05.2018 (45) Опубликовано: 29.05.2018 Бюл. № 16 (56) Список документов, цитированных в отчете о поиске: RU 2229583 C1, 27.05.2004. RU (54) Устройство для токоподвода к электробуру при бурении скважин (57) Реферат: Полезная модель может быть использовано герметичными корпусами К (7), в каждом из для токоподвода и передачи сигналов в скважину которых зафиксирована КС (1), и узлом (8) и из скважины в процессе бурения. Устройство герметичного соединения К (7). К (7) установлены для токоподвода к электробуру содержит КС (1), в БТ (2) с возможностью осевого перемещения. длина которых равна длине бурильной трубы БТ Исключается возможность механического (2), и имеющие электроконтактные разъемы (3) повреждения кабельной секции при монтаже и и (4), узел (5) радиальной и осевой фиксации КС эксплуатации, обеспечивается надежное (1). Устройство снабжено жесткими соединение разъемов. 4 з.п. ф-лы, 2 ил. R U 1 7 9 9 6 2 84063 U1, 26.07.2009. SU 546703 A1, 15 ...

Резистивиметр скважинный

Полезная модель относится к устройствам для геофизических исследований в нефтяных и газовых скважинах и может быть использована для измерения удельного электрического сопротивления скважинной жидкости. Скважинный резистивиметр содержит полый цилиндрический корпус, выполненный из двух соосно расположенных соединенных друг с другом посредством посадки с натягом труб. При этом на внешней поверхности внутренней трубы выполнены симметрично относительно продольной оси корпуса два продольных паза для кабеля. Технический результат заключается в упрощении технологии и снижении трудоемкости изготовления, расширении эксплуатационных возможностей, повышении надежности и ремонтопригодности, увеличении срока службы, упрощении обслуживания, возможности использования универсального технологического оборудования, а также расширении арсенала технических средств указанного назначения. 2 ил. РОССИЙСКАЯ ФЕДЕРАЦИЯ (19) RU (11) (13) 184 117 U1 (51) МПК E21B 47/12 (2012.01) G01V 3/00 (2006.01) ФЕДЕРАЛЬНАЯ СЛУЖБА ПО ИНТЕЛЛЕКТУАЛЬНОЙ СОБСТВЕННОСТИ (12) ОПИСАНИЕ ПОЛЕЗНОЙ МОДЕЛИ К ПАТЕНТУ (52) СПК E21B 47/12 (2018.08); G01V 3/00 (2018.08) (21)(22) Заявка: 2018112855, 09.04.2018 (24) Дата начала отсчета срока действия патента: Дата регистрации: 16.10.2018 (45) Опубликовано: 16.10.2018 Бюл. № 29 (56) Список документов, цитированных в отчете о поиске: US 4873488 A, 10.10.1989. US (54) РЕЗИСТИВИМЕТР СКВАЖИННЫЙ (57) Реферат: Полезная модель относится к устройствам для геофизических исследований в нефтяных и газовых скважинах и может быть использована для измерения удельного электрического сопротивления скважинной жидкости. Скважинный резистивиметр содержит полый цилиндрический корпус, выполненный из двух соосно расположенных соединенных друг с другом посредством посадки с натягом труб. При этом на внешней поверхности внутренней трубы выполнены симметрично относительно R U 1 8 4 1 1 7 4651101 A, 17.03.1987. US 5467019 A, 14.11.1995. SU 177559 A1, 18.12.1966. SU 115891 A1, 01.01.1958. Стр.: 1 ...

Наддолотный модуль системы скважинной телеметрии

Полезная модель относится к области скважинной телеметрии, а именно к устройству для передачи сигналов от наддолотного модуля.Технический результат, достигаемый предложенным решением, заключается в повышении надежности работы наддолотного модуля.Указанный технический результат достигается благодаря тому, что разработан наддолотный модуль системы скважинной телеметрии, содержащий: первую часть модуля, содержащую блок электроники, и выполненную с возможностью прикрепления к бурильной колонне, содержащей бурильные трубы и забойный двигатель; вторую часть модуля, выполненную с возможностью прикрепления к долоту; причем первая часть модуля и вторая часть модуля механически соединены друг с другом посредством резьбы, причем обеспечена электрическая изоляция первой части модуля и второй части модуля друг от друга; причем блок электроники выполнен с возможностью создавать разность потенциалов между первой и второй частями модуля для передачи сигналов телеметрии; причем в зазоре между первой и второй частями модуля расположен непроводящий электричество упорный узел, выполненный с возможностью принимать механические нагрузки, возникающие при соединении первой и второй частей модуля. 7 з.п. ф-лы, 4 фиг. РОССИЙСКАЯ ФЕДЕРАЦИЯ (19) RU (11) (13) 187 546 U1 (51) МПК E21B 47/13 (2012.01) ФЕДЕРАЛЬНАЯ СЛУЖБА ПО ИНТЕЛЛЕКТУАЛЬНОЙ СОБСТВЕННОСТИ (12) ОПИСАНИЕ ПОЛЕЗНОЙ МОДЕЛИ К ПАТЕНТУ (52) СПК E21B 47/122 (2018.08) (21)(22) Заявка: 2018119867, 29.05.2018 (24) Дата начала отсчета срока действия патента: Дата регистрации: (73) Патентообладатель(и): Общество с ограниченной ответственностью "ТНГ-Групп" (RU) 12.03.2019 (56) Список документов, цитированных в отчете о поиске: RU 2633884 C2, 19.10.2017. RU (45) Опубликовано: 12.03.2019 Бюл. № 8 169710 U1, 29.03.2017. RU 2449120 C2, 27.04.2012. RU 2509209 C1, 10.03.2014. RU 65133 U1, 27.07.2007. US 4496174 A1, 29.01.1985. 1 8 7 5 4 6 R U (54) НАДДОЛОТНЫЙ МОДУЛЬ СИСТЕМЫ СКВАЖИННОЙ ТЕЛЕМЕТРИИ (57) Реферат: Полезная модель относится к области долоту; ...

Device for Measuring Temperature in Electromagnetic Fields

For a temperature measurement in areas having electromagnetic fields, shielding devices must be provided. According to the proposed technique, at least one temperature sensor is designed as a fiber-optic sensor having Bragg gratings (FBG), wherein the sensor is arranged in a non-metallic housing that precludes or minimizes expansion effects for the individual FBG sensors. For example, the proposed technique can be used advantageously to measure the temperature distribution in oil sand deposits, for which purpose a suitable measuring arrangement is required.

Self Adaptive Two Dimensional Least Square Filter for Distributed Sensing Data

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.

Apparatus and method for downhole communication

A method for downhole communication and an apparatus for remote actuation of a downhole tool is disclosed. The method comprises the steps of: programming at least one tag ( 20 ) to emit a radio frequency identification signal in the form of a frequency change in a carrier wave; locating a reader ( 10 ) responsive to signals emitted from the at least one tag downhole; moving the at least one tag ( 20 ) past the downhole reader ( 10 ) such that the downhole reader ( 10 ) is capable of reading data from the tag ( 20 ) when the tag ( 20 ) passes the reader ( 10 ); and thereby communicating data from the tag ( 20 ) to the reader ( 10 ) downhole. Typically, the method includes programming the tag ( 20 ) and the reader ( 10 ) to communicate data by at least one of the following means: transitions between discrete frequencies; use of specific discrete frequencies; and length of time in which a carrier wave emits a specific frequency in preference to at least one other frequency.

Determining the Order of Devices in a Downhole String

A string of subs includes a controller sub. The controller sub includes a first end, a second end, a controller, a first controller bus coupled to the controller, the first controller bus exiting at the first end of the controller sub, and a second controller bus coupled to the controller, the second controller bus being separate from the first controller bus, the second controller bus exiting at the second end of the controller sub. The string of subs also includes a first measuring sub and a second measuring sub. A process, running on a computer, discovers that the first measuring sub is connected to the first controller bus, discovers that the second measuring sub is connected to the first controller bus, determines that the first measuring sub is physically closer to the controller sub than the second measuring sub, and use the fact that the first measuring sub is physically closer to the controller sub than the second measuring sub in controlling the operation of the string of subs.

Downhole Data Transmission System

A method and system are disclosed herein relating to transmitting data within a borehole. The method and system include having a transmitter disposed at a first location within the borehole and configured to generate a first signal, and more than one receiver and/or repeater disposed at a second location within the borehole. The receivers and/or repeaters are configured to receive the first signal, and further are configured to communicate with each other.

Downhole Tool Delivery System With Self Activating Perforation Gun

An apparatus for use in deployment of downhole tools is disclosed. Preferably, the apparatus includes at least an in-ground well casing, a housing providing a hermetically sealed electronics compartment, a tool attachment portion, and a first flow through core. The housing is preferably configured for sliding communication with the well casing. The hermetically sealed electronics compartment secures a processor and a location sensing system, which communicates with the processor while interacting exclusively with features of the well casing to determine the location of the housing within the well casing. A preferred embodiment further includes a well plug affixed to the tool attachment portion, the well plug includes a second flow through core capped with a core plug with a core plug release mechanism, which upon activation provides separation between the second flow through core and the core plug, allowing material to flow through said first and second flow through cores.

Optical casing collar locator systems and methods

Disclosed are fiber optic enabled casing collar locator systems including a wireline sonde or a coil tubing sonde apparatus configured to be conveyed through a casing string by a fiber optic cable. The sonde includes at least one permanent magnet producing a magnetic field that changes in response to passing a collar in the casing string. Such magnetic field changes induce voltages changes within associated pick-up electrical coil conductors. Some embodiments include a cylinder configured to change its diameter in response to the changes in the magnetic field and/or impressed voltage, and an optical fiber wound around the cylinder to convert the cylinder diameter change into an optical path length change for light being communicated along the fiber optic cable. The cylinder may include a magnetostrictive material or a piezoelectric material.

HYDROCARBON DETECTION IN ANNULUS OF WELL

Disclosed is an apparatus for completion of a well. The apparatus includes a tubular configured to be disposed in a wellbore penetrating the earth where an annulus region is defined between an exterior surface of the tubular and a wall of the wellbore. The apparatus further includes a plurality of sensors disposed in the annulus region and configured to sense hydrocarbons during cementing of the tubular to the wall of the wellbore. A receiver is disposed remote from the wellbore and configured to receive measurement data from the plurality of sensors and to provide an indication if hydrocarbons are sensed in the annulus region. 1. An apparatus for completion of a well , the apparatus comprising:a tubular configured to be disposed in a wellbore penetrating the earth, an annulus region being defined between an exterior surface of the tubular and a wall of the wellbore;a plurality of sensors disposed in the annulus region and configured to sense hydrocarbons; anda receiver disposed remote from the wellbore and configured to receive measurement data from the plurality of sensors and to provide an indication if hydrocarbons are sensed in the annulus region.2. The apparatus according to claim 1 , wherein the receiver is disposed at a drilling rig and the indication is provided to a drilling operator.3. The apparatus according to claim 2 , further comprising a computer processing system configured to receive the measurement data from the plurality of sensors and to determine if hydrocarbons are present in the annulus region.4. The apparatus according to claim 3 , wherein the computer processing system is configured to provide an alarm to a drilling operator upon detection of hydrocarbons in the annulus region.5. The apparatus according to claim 2 , further comprising a blowout preventer disposed at a surface of the earth and coupled to the tubular claim 2 , the blowout preventer being configured to close upon receipt of a command from the drilling rig.6. The apparatus ...

Detector, preamplifier selection apparatus, systems, and methods

Optical detection apparatus ( 300 ) comprising an optical detector ( 302, 304, 306 ), a detector amplifier ( 336, 338, 340 ), and switching means, e.g., a multiplexer ( 344, 348 ), for dynamically selecting at least one of the optical detector or the detector amplifier by switching from among at least two alternative optical detectors and/or at least two detector amplifiers such as to minimize noise equivalent power (NEP) of a selected detector or combination of detector and amplifier under given operating conditions.

REAL TIME DATA COMPRESSION AND TRANSMISSION

Systems, methods, and devices are provided for compressing a variety of signals, such as measured signals from a hydrocarbon operation, that may be stored and/or transmitted in compressed form. Segmentation tools and techniques are used to compress the signals. Segmentation techniques include breaking a signal into segments and representing the data samples of the signal as segment boundary points, which may reflect where changes occur in the signal, and segment parameters, which may be utilized to model the segmented data. Embodiments can be used in real-time or in batch modes. New data samples can influence previous segment boundary points and/or segment parameters in some cases. Systems may modify what has already been stored or displayed as a result in revising segmentation information based on analysis utilizing the new data samples. Embodiments may utilize different Bayesian analysis techniques including the use of prior probability distributions and maximum a posteriori analyses. 12-. (canceled)3. A method of compressing sensor data comprising:identifying a plurality of data samples from a first sensor;determining a segmentation of the plurality of data samples from the first sensor, wherein the determined segmentation includes a plurality of segments of varying sizes, each segment of the determined segmentation including:more segment parameters that provide a representation of the data samples for the respective segment; anda segment boundary point that indicates a point in the plurality of data samples where a threshold has been exceeded for the data samples with respect to the one or more segment parameters of a previous segment; andstoring the segment boundary point and one or more segment parameters for each of the one or more segments of the determined segmentation.4. The method of compressing sensor data of further comprising:determining a plurality of segmentations of the plurality of data samples from the first sensor;selecting one of the plurality ...

Wireless Two-Way Communication For Downhole Tools

Systems, methods, and devices for two-way communication with a downhole tool string are provided. In one example, a method may include placing a downhole tool string into a pressure riser of a well while at least one component of the downhole tool string is not activated. Thereafter, a wireless control signal may be issued through the pressure riser to the downhole tool to cause the downhole tool string to activate the component. The wireless control signal may involve an acoustic signal, an optical signal, and/or an electromagnetic signal such as electrical dipole coupling or magnetic dipole coupling. 1. A method comprising:placing a downhole tool string into a pressure riser of a well while at least one component of the downhole tool string is not activated; andissuing a wireless control signal through the pressure riser to the downhole tool to cause the downhole tool string to activate the at least one component.2. The method of claim 1 , wherein the at least one component of the downhole tool string comprises a well-logging tool claim 1 , and wherein issuing the wireless control signal causes the well-logging tool to begin or prepare to begin to gather well-logging data.3. The method of claim 1 , wherein the at least one component of the downhole tool string comprises an electronic nuclear radiation generator claim 1 , and wherein issuing the wireless control signal causes the nuclear radiation generator to begin or to prepare to begin to generate radiation.4. The method of claim 1 , wherein the wireless control signal is issued through the pressure riser via magnetic dipole coupling and wherein the wireless control signal comprises a signal-to-noise ratio of greater than or equal to 11.6 dB.5. The method of claim 1 , wherein the wireless control signal comprises an acoustic signal claim 1 , an optical signal claim 1 , or an electromagnetic signal claim 1 , or any combination thereof.6. The method of claim 1 , comprising receiving a wireless feedback signal from ...

ACTIVE DRILLING MEASUREMENT AND CONTROL SYSTEM FOR EXTENDED REACH AND COMPLEX WELLS

A dynamically controlled drill string includes a communications sub, a circulation sub and a measurement sub. The communications sub is operable to receive a wireless signals and retransmit the signals wirelessly. The measurement sub is operable to detect a downhole condition and transmit wirelessly a corresponding data signal. The circulation sub is operable to selectively permit fluid communication between the interior fluid conduit and the exterior of the dynamically controlled drill string at the circulation sub. The circulation sub is operable to selectively permit fluid communication through the internal fluid conduit at the circulation sub. A method for using the dynamically controlled drill string in a well bore includes the steps of introducing the dynamically controlled drill string into the well bore and introducing fluid operable to modify a detected downhole conditions into the well bore. 1. A method for modifying a detected downhole condition in a well bore using a dynamically controlled drill string comprising the steps of:introducing the dynamically controlled drill string into the well bore such that a well bore annulus forms between an external surface of the dynamically controlled drill string and a wall of the well bore, where the dynamically controlled drill string includes a communications sub, a measurement sub and a circulation sub along its operable length, has an internal fluid conduit and the external surface for its operative length and has an open distal end that is operable to pass fluid between the internal fluid conduit and the well bore, where the circulation sub is operable to selectively modify a fluid circulation flow path for a fluid in the well bore upon receiving of a pre-designated command signal, and where the well bore is defined by the well bore wall that extends from a surface into a hydrocarbon-bearing formation and contains the fluid;inducing circulation of the fluid in the well bore such that the fluid circulates ...

WELL

A well comprising a borehole and wellhead apparatus, and a communication box at or proximate to the wellhead apparatus, the well comprising a plurality of sensors coupled to wireless transmitters which are adapted to transmit information from the sensors to the communication box; the sensors comprising at least one pressure sensor;and the well comprising a first memory device spaced apart from the communication box, the first memory device configured to store information from the sensors, wherein the communication box comprises a receiver adapted to receive signals from the transmitters, and at least one of a transmission device and a second memory device to transmit and/or store data received from the transmitters. The communication box is typically highly shock resistant (above 50 Gs for at least 5 ms, all axes) and so provides, together with other optional features, a system to monitor a well, especially before, during or after an emergency situation. 1. A well comprising a borehole and wellhead apparatus , and a communication box at or proximate to the wellhead apparatus , the well comprising a plurality of sensors coupled to wireless transmitters which are adapted to transmit information from the sensors to the communication box;the sensors comprising at least one pressure sensor;and the well comprising a first memory device spaced apart from the communication box, the first memory device configured to store information from the sensors,wherein the communication box comprises a receiver adapted to receive signals from the transmitters, and at least one of a transmission device and a second memory device to transmit and/or store data received from the transmitters.2. A well as claimed in claim 1 , wherein the communication box has a survivability shock rating of least 50 Gs for at least 5 ms claim 1 , all axes claim 1 , optionally more than 100 Gs for at least 5 ms claim 1 , all axes; and more optionally more than 500 Gs for at least 5 ms claim 1 , all axes.3. A ...

Valve assembly

A downhole valve assembly including at least one membrane permeable to a flow of a downhole fluid, the at least one membrane defining a passage through a chamber. A quantity of particles is disposed in the chamber and the at least one membrane is impermeable to the particles. The particles are responsive to a magnetic field. At least one magnetic element is operatively arranged to produce the magnetic field for enabling the at least one magnetic element to selectively move the particles between a first position at which the particles impede the flow of the downhole fluid through the at least one membrane and a second position at which the particles do not impede the flow of the downhole fluid through the at least one membrane. A method of controlling a flow of fluid is also included.

WIRELESS DRILL STRING DISCONNECT

A disconnector drill string has an uphole section and a downhole section coupled together by a disconnection sub, an operative length and an internal fluid conduit that extends along its operative length. The disconnection sub is operable to receive wirelessly a pre-designated command signal, to selectively couple the uphole section and the downhole section together, and to selectively uncouple the uphole section and the downhole section from one another. A method for using the disconnector drill string in a well bore includes the steps of introducing the disconnector drill string into the well bore, transmitting wirelessly the pre-designated command signal to the disconnection sub such that the disconnection sub selectively operates to uncouple the uphole section of the disconnector drill string from the downhole section of the disconnector drill string, and removing the uphole section of the disconnector drill string from the well bore. 1. A method for using a disconnector drill string in a well bore comprising the steps of:introducing the disconnector drill string into the well bore, where the disconnector drill string has a disconnection sub, an internal fluid conduit, an operative length, an uphole section and a downhole section that are coupled together by the disconnection sub, the uphole section positioned uphole of the downhole section along the operative length of the disconnector drill string, and where the well bore is defined by a well bore wall extending from the surface into a hydrocarbon-bearing formation and contains a well bore fluid;transmitting wirelessly a pre-designated command signal to the disconnection sub such that the disconnection sub selectively operates to uncouple the uphole section of the disconnector drill string from the downhole section of the disconnector drill string, severing the internal fluid conduit of the disconnector drill string; andremoving the uphole section of the disconnector drill string from the well bore such that ...

Surface Wellbore Operating Equipment Utilizing MEMS Sensors

A method comprising mixing a wellbore servicing composition comprising Micro-Electro-Mechanical System (MEMS) sensors in surface wellbore operating equipment at the surface of a wellsite. An interrogator retrieves data regarding a parameter sensed by the MEMS sensor.

DOWNHOLE DOWNLINKING SYSTEM EMPLOYING A DIFFERENTIAL PRESSURE TRANSDUCER

A downhole tool includes a downlinking system deployed in a downhole tool body having an internal through bore. The downlinking system includes a differential pressure transducer configured to measured a pressure difference between drilling fluid in the internal through bore and drilling fluid external to the tool (in the borehole annulus). The differential transducer is electrically connected with an electronic controller (deployed substantially anywhere in the drill string) that is configured to receive and decode pressure waveforms. 120.-. (canceled)21. A method , comprising:deploying a differential transducer in a longitudinal bore in a pressure housing to form a downlinking system;disposing the downlinking system in a downhole tool body;forming a pressure tight seal with a bulkhead deployed in the longitudinal bore; andelectrically connecting the bulkhead with the differential transducer.22. The method of claim 21 , further comprising:sealingly deploying the downlinking system in a chassis slot of the downhole tool body.23. The method of claim 21 , further comprising:fully assembling the downlinking system prior to disposing the downlinking system in the downhole tool body.24. The method of claim 21 , further comprising:further comprising testing the downlinking system prior to disposing the downlinking system in the downhole tool body.25. The method of claim 21 , further comprising:disposing the downhole tool in a borehole;measuring a differential pressure with the differential transducer; andreceiving and decoding a differential pressure waveform from the differential transducer.26. The method of claim 25 , further comprising at least one of:controlling a second downhole tool based on the decoded differential pressure waveform; andtransmitting the decoded commands to a device in electronic communication with the downlinking system.27. The method of claim 25 , further comprising:servicing the downhole tool.28. The method of claim 27 , wherein the servicing ...

Method for Transmission of Data from a Downhole Sensor Array

A method for transmission of data from a downhole sensor array. A continuous unidirectional data stream is sent from the downhole sensor array to two or more different types of data transmitters at the same time. One or more of the two or more different types of data transmitters is then activated to transmit the data from the downhole sensor array. If desired, all of the different types of data transmitters may be activated to contemporaneously transmit the data from the downhole sensor array

APPARATUS FOR MEASURING BENDING ON A DRILL BIT OPERATING IN A WELL

An apparatus for measuring the bending on a drill bit operating down hole in a well may comprise at least three pockets circumferentially spaced equidistantly around the drill collar of the drill string to which the drill bit is attached. Four strain gauges are equidistantly circumferentially spaced around each of the pockets so as to form first and second sets of strain gauges. The strain gauges in the first set are connected into one Wheatstone bridge while the gauges in the second set are connected in a second bridge. Each of the strain gauges that are oriented similarly within each of the pockets are connected in series within a single leg of a bridge so that the output voltage of the bridge is unaffected by bending in the drill string. The output of first bridge is used to determine the bending on the drill bit. Further, an apparatus for measuring the bending, weight, and torque on a drill bit operating down hole in a well may comprise at least three pockets circumferentially spaced equidistantly around the drill collar of the drill string to which the drill bit is attached with twelve strain gauges that are equidistantly circumferentially spaced around each of the pockets so as to form first and second sets of strain gauges. The arrangement of the twelve strain gauges allow for a bending on bit measurement that cancels out the affects of the weight on bit and torque on bit. 1. An apparatus for sensing the bending applied to a drill bit coupled to a drill string operating down hole in a well , comprising:a) a drill pipe, said drill pipe defining a centerline thereof and having means for being coupled into a drill string;b) at least first, second and third pockets formed in said drill pipe, said pockets circumferentially spaced approximately equidistantly around said drill pipe, each of said pockets forming at least one wall;c) a set of strain sensors for each of said pockets, each of said sets of strain sensors affixed to said wall of its respective pocket, ...

Data Retrieval Device for Downhole to Surface Telemetry Systems

A data retrieval device for communicating between a downhole location within a wellbore ( 16 ) and a surface location ( 22 ) in which a downhole to surface telemetry system is installed and adapted to communicate between a first telemetry module and a second telemetry module with the second telemetry module ( 18 ) positioned downhole and connected to a string ( 12 ) positioned within the wellbore ( 16 ). The data retrieval device is provided with a housing adapted to be positioned inside the string; a communication device supported by the housing; a connection port positioned on the housing and adapted to be connected to a line; and an electronic module supported by the housing. The electronic module is in communication with the communication device and is adapted to store and use at least an identification parameter of the first telemetry module to intercept a signal transmission addressed to the first telemetry module from the second telemetry module ( 18 ) via the communication device.

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

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.

METHOD OF CONSTRUCTING A WELL LOG OF A QUANTITATIVE PROPERTY FROM SAMPLE MEASUREMENTS AND LOG DATA

A method of constructing a well log of a quantitative property representative of a porous formation, from sample measurements and log data, is disclosed. A quantitative property (mineralogical proportions) of samples selected from among a set of samples is measured and each sample is grouped into homogeneous classes regarding the log data. The average value of the quantitative property is then determined in each class. A well log representing the probability of assigning a sample to each class as a function of depth is constructed. Finally, the well log representing the quantitative property as a function of depth is constructed from the log representing the assignment probability and from the average values. 15-. (canceled)6. A method of constructing a well log of a quantitative property representative of a porous formation penetrated by at least one borehole , from a set of samples from the porous formation taken at depths for which log data are available , comprising:a) measuring at least one quantitative property of samples selected from among the set of samples;b) grouping each one of the samples selected into homogeneous classes by an analysis of the log data;c) determining an average value for the quantitative property in each one of the classes;d) constructing a well log representing a probability of assigning a sample to each one of the classes as a function of depth in the at least one borehole; ande) constructing the well log representing the quantitative property as a function of depth in the at least one borehole from the log representing an assignment probability and from the average values.8. A method as claimed in claim 6 , wherein the quantitative property is selected from: mineralogical proportion of samples claim 6 , lithology claim 6 , matrix density and porosity.9. A method as claimed in claim 7 , wherein the quantitative property is selected from: mineralogical proportion of samples claim 7 , lithology claim 7 , matrix density and porosity.10. ...

Mask free protection of work function material portions in wide replacement gate electrodes

In a replacement gate scheme, after formation of a gate dielectric layer, a work function material layer completely fills a narrow gate trench, while not filling a wide gate trench. A dielectric material layer is deposited and planarized over the work function material layer, and is subsequently recessed to form a dielectric material portion overlying a horizontal portion of the work function material layer within the wide gate trench. The work function material layer is recessed employing the dielectric material portion as a part of an etch mask to form work function material portions. A conductive material is deposited and planarized to form gate conductor portions, and a dielectric material is deposited and planarized to form gate cap dielectrics.

Simulating Downhole Flow Through a Perforation

A system for testing a core sample comprises a non-permeable sleeve configured to be placed over a core sample, a first pair of opposing actuators to apply opposing force to the non-permeable sleeve in a first axis normal to an axis of the core sample, a second pair of opposing actuators to apply opposing force to the non-permeable sleeve in a second axis normal to the axis of the core sample and normal to the first axis, a wellbore pressure reservoir to provide simulated wellbore pressure, and a formation pressure reservoir to provide simulated formation fluid pressure. 1. A system for testing a core sample , comprising:a non-permeable sleeve configured to be placed over a core sample;a first pair of opposing actuators to apply opposing force to the non-permeable sleeve in a first axis normal to an axis of the core sample;a second pair of opposing actuators to apply opposing force to the non-permeable sleeve in a second axis normal to the axis of the core sample and normal to the first axis;a wellbore pressure reservoir to provide simulated wellbore pressure; anda formation pressure reservoir to provide simulated formation fluid pressure.2. The system of claim 1 , wherein the first pair of opposing actuators and the second pair of opposing actuators are hydraulic actuators.3. The system of claim 1 , wherein the first pair of opposing actuators and the second pair of opposing actuators are electrical actuators.4. The system of claim 1 , wherein the force applied by the first pair of opposing actuators and the second pair of opposing actuators are separately controlled.5. The system of claim 1 , wherein the force applied to the core sample by the first pair of opposing actuators is based on a vertical overburden pressure.6. The system of claim 1 , wherein the force applied to the core sample by the second pair of opposing actuators is based on a horizontal overburden pressure.7. The system of claim 1 , further comprising the core sample disposed within the non- ...

Asynchronous ds-cdma receiver

Methods, apparatus, and systems are provided for collecting data from a plurality of downhole sensors located in a wellbore utilizing an asynchronous direct-sequence code division multiple access (DS-CDMA)-based communication scheme. One example method includes receiving a superposed signal comprising asynchronous signals from the downhole sensors, wherein a spreading sequence has been applied to data generated by each of the downhole sensors to form each of the asynchronous signals; sampling the received superposed signal; and processing the sampled superposed signal using decorrelation to determine the data from at least one of the downhole sensors before the spreading sequence was applied.

Methods and Apparatus to Process Measurements Associated with Drilling Operations

Methods and apparatus to process measurements associated with drilling operations are described. An example method of modifying processing results during a subterranean formation drilling operation includes identifying a plurality of parameters and processing measurements associated with the subterranean formation obtained while drilling and the plurality of parameters to generate first results. Additionally, the example method includes processing measurements associated with the subterranean formation obtained while drilling is temporarily suspended and the plurality of parameters to generate second results and comparing the first and second results. Further, the example method includes, in response to the comparison of the first and second results, modifying the first results based on the second results to improve a quality of the first results. 1. A drillstring , comprising:a measurement device to measure one or more parameters;a processor to process the one or more measured parameters and one or more processing parameters to generate results; andan apparatus to link results generated during a first time interval and results generated during a second time interval.2. The drillstring as defined in claim 1 , wherein the apparatus is to predict results based on at least some of the generated results.3. The drillstring as defined in claim 1 , wherein the apparatus is to update the one or more processing parameters based on at least some of the generated results.4. The drillstring as defined in claim 1 , wherein the apparatus is to constrain at least some of the generated results.5. The drillstring as defined in claim 1 , wherein the apparatus comprises a Kalman filter or an apparatus to implement a prediction operation.6. A method of selectively associating processing results during a drilling operation claim 1 , comprising:identifying a plurality of parameters;processing measurements obtained while drilling and the plurality of parameters to generate first results; ...

METHOD FOR ESTIMATING PROPERTIES OF A SUBTERRANEAN FORMATION

A method for estimating properties of a subterranean formation penetrated by a wellbore provides for injecting a fluid with the plurality of tracer agents wherein each tracer agent is an object of submicron scale, into the wellbore and formation, flowing the fluid back from the subterranean formation and determining the properties of the formation. The properties are determined by analyzing changes in the tracers size and type distribution function between the injection fluid and produced fluid. 1. A method for estimating properties of a subterranean formation penetrated by a wellbore comprising the steps of:introducing an injection fluid into the well and the subterranean formation, the injection fluid comprising a plurality of tracer agents, wherein each tracer agent is an object of submicron scale,flowing fluid back from the subterranean formation anddetermining the properties of the formation by analyzing changes in the tracer agents concentration, size and type distribution function between the injection and produced fluids.2. The method of wherein analyzing changes in the tracer agents concentration claim 1 , size and type distribution function between the injection and produced fluids is performed while flowing in the formation by the acoustics claim 1 , electric claim 1 , thermal claim 1 , neutron or gamma-ray logging.3. The method of wherein analyzing changes in the tracer agents concentration claim 1 , size and type distribution function between the injection and produced fluids is performed by comparing samples of the injection and produced fluids.4. The method of wherein the properties of the subterranean formation include pore size distribution claim 1 , effective pore ensembles permeability claim 1 , distribution of the fluid saturation claim 1 , distribution of the fluid/rock chemical properties claim 1 , rock wettability distribution over the pore ensembles claim 1 , temperature of the formation.5. The method of wherein the plurality of tracer agents ...

Downhole Data Communication and Logging System

A logging system and method for use in a wellbore formed in an earth formation. A tubular conduit that extends from the surface into the wellbore is included in the system. The conduit includes a stabilizer with sensors to obtain data from the wellbore. A communication interface is used to communicate data from the stabilizer to the logging tool string. Also, a surface communication and control device, along with a telemetry device can be included in the system. The telemetry device could be used to send and receive data to and/or from the surface communication and control device, if needed. Also provided is a logging tool string that is capable of passing from a position within the conduit to a position outside the lower end of the conduit. In addition, a memory storage device used to and store data collected from the wellbore for further analysis and communication. 1. A logging system for use in a wellbore that comprises:a conduit extending into the wellbore from the surface;a logging tool string, the logging tool string being capable of passing from a position within the conduit to a lower position extending outside a lower end of the conduit into the borehole; and a blade; and', 'a sensor within the blade; and, 'a stabilizer coupled to the tubular conduit, including a conduit communication device located in the conduit; and', 'a logging tool communication device located in the logging tool string; and', 'the conduit communication device being able to wirelessly communicate data collected by the sensor with the logging tool communication device., 'a communication interface including2. The logging system of claim 1 , wherein the logging tool string is capable of being suspended in the position outside the conduit.3. The logging system of claim 1 , further comprising a memory storage device coupled to the tubular conduit capable of storing measurement data from the sensor.4. The logging system of claim 1 , further comprising a surface communication and control ...

Deployment of cables for landing strings

Embodiments may generally take the form of a cable winch system installable within a riser on a landing string. In particular, one embodiment may take the form of a system having a tubular deployable within a riser and a cable winch deployable within a riser. The cable winch is configured to travel with the tubular as it is deployed within the riser.

MULTI-INFORMATION COUPLING PREDICTION METHOD OF COAL AND GAS OUTBURST DANGER

Disclosed in the invention is a multi-information coupling prediction method of coal and gas outburst danger, which is achieved by establishing a multi-index coupling prediction model to detect indexes including original gas pressure of a coal layer, the original rock stress, the critical burst gas pressure of a coal sample, the mechanical performance of coal body, the exploit influence, the drilling cutting gas desorption index, the drilling cutting quantity index and the like, therefore to coupling predict the coal and gas outburst danger. By the multi-information coupling prediction method, the information of the coal and gas outburst danger can be fully complemented; the gas and crustal stress outburst danger prediction is carried out; the defects of insufficient complementation information of a single-index and inaccurate prediction are overcome; and the accuracy of the coal and gas outburst danger prediction is improved. 1{'sub': 'max', 'a. testing an original gas pressure P in coal seams in a mining zone and a maximum concentrated ground stress σin a coal body in front of the mining face, and testing the critical gas pressure rupture and critical compression strength of coal samples obtained on site;'}{'sub': 1', '2', '3', 'max', '1', '2', '3', 'max, 'b. drilling a hole in length not less than 10 m into the coal body in front of the mining face in the mining direction, measuring a gas desorption index of drill cutting once every 1 m drilling length, and recording a desorption index Kat 1 m, a desorption index Kat 2 m, a desorption index Kat 3 m, . . . , respectively, until the desorption index has stabilized, and taking the stabilized desorption index as a maximum desorption index K; measuring a total amount of drill cutting within every 1 m drilling segment, recording, a total amount of drill cutting Swithin the 1 m segment, total amount of drill cutting Swithin the 2 m segment, total amount of drill cutting Swithin the 3 m segment, . . . , respectively, and ...

Communication through an enclosure of a line

A communication system can include a transmitter which transmits a signal, and at least one sensing device which receives the signal, the sensing device including a line contained in an enclosure, and the signal being detected by the line through a material of the enclosure. A sensing system can include at least one sensor which senses a parameter, at least one sensing device which receives an indication of the parameter, the sensing device including a line contained in an enclosure, and a transmitter which transmits the indication of the parameter to the line through a material of the enclosure. Another sensing system can include an object which displaces in a subterranean well. At least one sensing device can receive a signal from the object. The sensing device can include a line contained in an enclosure, and the signal can be detected by the line through a material of the enclosure.

MEASURING OIL AND WATER TRANSMISSIVITY OF WELLS FROM MULTIPLE LOGS

Models of fluid flow in wells in formation of a subsurface earth reservoir are formed by computers based on measurements obtained by well logging tools run in the wells and measurements of formation rock characteristics obtained from laboratory data. The models so formed are used to form measures of injection/production profiles and assist reservoir engineers in allocation of production and injection wells for the reservoir, and in other reservoir production planning and analysis. 1. A method of obtaining a measure of oil and water transmissibility of fluids in a subsurface formation at a location in a well bore , the method comprising the steps of:obtaining data with a logging while drilling tool from the formation at the location in the well bore;obtaining data with a permeability logging tool from the formation at the location in the well bore;obtaining data with a viscosity logging tool from the formation at the location in the well bore;obtaining relative permeability test data regarding the formation;processing the obtained data from the logging tools in a computer to obtain a measure of fluid transmissibility in the subsurface formation at the location in the well bore by performing the computer processing steps of:determining a measure of the thickness of the subsurface formation from the obtained data from the logging while drilling tool;determining a measure of the relative permeability to oil of the subsurface formation from the obtained data from the permeability logging tool and the relative permeability test data;determining a measure of the relative permeability to water of the subsurface formation from the obtained data from the permeability logging tool and the relative permeability test data;determining a measure of the viscosity of fluids in the subsurface formation from the obtained data from the viscosity tool;determining the transmissibility of oil in the subsurface formation at the location in the formation based on the determined measures of ...

Wireless Communication Platform for Operation in Conduits

Described herein are systems, devices, and methods for sensing, measuring, transmitting, and receiving information pertaining to a live oil or gas production environment. A measuring device may be positioned and secured within a production conduit in such a manner that sudden changes in temperature resulting in expansion of one or more components of the measuring device do not disrupt or negatively impact electrical connections established between the measuring device and the inner wall of the conduit. As a result, the measuring device described herein may reside in the conduit for longer periods of time while maintaining optimum performance. Further, the measuring device may be retrofit within an existing production environment and selectively secured at a desirable location within the production conduit. 1. A measuring apparatus for use within a live oil or gas production environment , the apparatus comprising:a first electrical contact component establishing electrical contact between the apparatus and a conduit;a second electrical contact component establishing electrical contact between the apparatus and the conduit;an electronics vessel in electrical communication with the conduit through the first and second electrical contact components, the electronics vessel comprising one or more sensors for sensing properties of interest within the conduit,wherein the apparatus withstands thermal expansion without inducing a strain at the first or second electrical contact components.2. The apparatus of claim 1 , further comprising a flexible coupling interposed between the first and second electrical contact components.3. The apparatus of claim 2 , wherein the flexible coupling is an expansion joint.4. The apparatus of claim 1 , further comprising a flexible electrode assembly comprising the first electrical contact component claim 1 , the flexible electrode assembly configured to translate along a central axis of the apparatus.5. The apparatus of claim 4 , wherein the ...

SYSTEM AND METHOD FOR DETERMINING FAULT LOCATION

Apparatus and methods for locating faults in inductively coupled wired drill pipe while drilling. In one embodiment, apparatus includes a drill string and a wired drill pipe fault monitor. The drill string includes a plurality of wired drill pipes. Each wired drill pipe includes an inductive coupler at each terminal end. The wired drill pipe fault monitor is coupled to the wired drill pipes. The fault monitor includes an impedance measuring system and a fault locator. The impedance measuring system is configured to measure, while drilling the borehole, an input impedance of the wired drill pipes. The fault locator is configured to determine a propagation constant for the wired drill pipes, and to analyze the measured input impedance and determine, as a function of the measured input impedance and the propagation constant, a location of a fault in the wired drill pipes. 1. A method for locating a fault in wired drill pipe , comprising:measuring input impedance of wired drill pipes of a drill string while drilling a borehole, the drill string disposed in the borehole;computing a first distance to a fault based on the fault being an open circuit;computing a second distance to the fault based on the fault being a short circuit;determining which of the first distance and the second distance provides a best estimate of a true distance to the fault.2. The method of claim 1 , wherein the determining comprises:determining which of the first distance and the second distance has a smaller valued imaginary part; andselecting one of the first distance and the second distance having the smaller valued imaginary part to be the best estimate.3. The method of claim 1 , wherein the determining comprises:determining which of the first distance and the second distance is more frequency independent; andselecting the more frequency independent of the first distance and the second distance to be the best estimate.4. The method of claim 1 , wherein computing the first distance and the ...

SYSTEM AND METHOD FOR DETERMINING FAULT LOCATION

Apparatus and method for locating faults in wired drill pipe while drilling. In one embodiment, a fault location system includes a plurality of conductively coupled media sections, impedance measurement electronics, and a fault locator. Each media section includes conductive couplers on opposing ends of the media section, and conductive media connected to and communicatively coupling the conductive couplers. The impedance measurement electronics is configured to measure an input impedance of the media sections. The fault locator is configured to determine a propagation constant for the media sections, and to determine, as a function of the input impedance and the propagation constant, a location of a fault in the media sections. 1. A method for locating a fault in wired drill pipe , comprising:disposing a drill string comprising a plurality of wired drill pipes in a borehole;measuring the input impedance of the wire drill pipes while drilling:determining a propagation constant for the wire drill pipes;determining, based on the input impedance, whether a fault in the wired drill pipe is an open circuit or a short circuit.2. The method of claim 1 , wherein the analyzing comprising analyzing an imaginary portion of the input impedance and determining claim 1 , based on the imaginary part of the input impedance claim 1 , whether the fault is an open circuit or a short circuit.3. The method of claim 2 , wherein the analyzing further comprises:determining that the fault is an open circuit based on the imaginary part being negative below a predetermined frequency; anddetermining that the fault is a short circuit based on the imaginary part being positive below the predetermined frequency.4. The method of claim 1 , further comprising determining a distance from a point of input impedance measurement to the fault as a function of the propagation constant claim 1 , the measured input impedance claim 1 , and whether the fault is an open circuit or a short circuit.5. The method ...

System For Logging While Running Casing

A well logging while casing instrument system includes a segment of pipe having at least one window therein corresponding to selected well logging instrument sensors. The segment of pipe has at least one of a float collar, a reaming shoe or a casing drill bit attached to one end thereof. At least one well logging instrument is disposed inside the segment of pipe. The at least one well logging instrument includes at least one sensor disposed at longitudinal position corresponding to the at least one window. The at least one well logging instrument includes a fishing neck at one longitudinal end thereof to enable retrieval of the at least one well logging instrument from the interior of the segment of pipe. 1. A well logging while casing instrument system , comprising:a segment of pipe having at least one window therein corresponding to selected well logging instrument sensors, the segment of pipe having at least one of a float collar, reaming shoe or casing drill bit attached to one end thereof;at least one well logging instrument disposed inside the segment of pipe, the at least one well logging instrument including at least one sensor disposed at longitudinal position corresponding to the at least one window.2. The system of further comprising a fishing neck at one longitudinal end of the well logging instrument to enable retrieval of the at least one well logging instrument from the interior of the segment of pipe.3. The system of wherein the at least one well logging instrument comprises one of electromagnetic propagation sensors claim 1 , nuclear magnetic resonance sensors claim 1 , gamma ray detectors claim 1 , neutron detectors claim 1 , galvanic electrodes claim 1 , and acoustic transducers.4. The system of further comprising at least one centralizer disposed along the well logging instrument to maintain a lateral position thereof inside the wellbore pipe.5. The system of further comprising a telemetry interface associated with the at least one well logging ...

System And Method For Wireless Drilling And Non-Rotating Mining Extenders In A Drilling Operation

Various embodiments of methods and systems for wireless power and data communications transmissions to a sensor subassembly below a mud motor in a bottom hole assembly are disclosed. Power and/or communications are transmitted through stationary or fixed coils. By leveraging resonantly tuned circuits and impedance matching techniques for the stationary coils, power and/or communications can be transmitted efficiently from one stationary coil to the other stationary coil despite any vibration and/or misalignment of the two coils. 4. The drilling and mining extender device of claim 1 , wherein one or more of the electrical transmissions are selected from the group of power transmissions and data communication transmissions.5. The drilling and mining extender device of claim 1 , wherein the first coil is of a mandrel type and the second coil is of a annular type.6. The drilling and mining extender device of claim 1 , wherein the first coil is of a mandrel type and the second coil is of a mandrel type.7. The drilling and mining extender device of claim 1 , wherein the first coil is of an annular type and the second coil is of an annular type.8. The drilling and mining extender device of claim 1 , wherein the first tool and second tool mate together using a fixed and non-movable coupling.9. The drilling and mining extender device of claim 8 , wherein the fixed and non-movable coupling comprises a mechanical fastener.10. The drilling and mining extender device of claim 9 , wherein the fixed and non-movable coupling comprises at least one of screw threads claim 9 , rivets claim 9 , and welds.11. A drilling and mining (“D&M”) extender device for communicatively coupling two stationary tools in a bottom hole assembly of a drill string claim 9 , the extender device comprising:a first stationary coil associated with a first tool; anda second stationary coil associated with a second tool;wherein electrical transmissions between the first and second tools are transmitted ...

GAUGE FOR USE IN WIRED-PIPE TELEMETRY APPLICATIONS

A gauge assembly that is utilized for wired-pipe telemetry, has been developed where the gauge assembly includes: a trigger, a push rod, wherein the rod is operatively coupled with the trigger, a bearing housing assembly, wherein the bearing housing assembly is operatively coupled with the push rod, an indicator, wherein the indicator is operatively coupled with the push rod, a base plate assembly, and a sensor device, stylus or combination thereof that is both operatively coupled with the push rod and the indicator. Methods of use are also disclosed. 1. A gauge assembly that is utilized for wired-pipe telemetry , wherein the gauge assembly comprises:a trigger assembly,a push rod, wherein the rod is operatively coupled with the trigger,a bearing housing assembly, wherein the bearing housing assembly is operatively coupled with the push rod,an indicator, wherein the indicator is operatively coupled with the push rod,a base plate assembly, anda sensor device, stylus or combination thereof that is both operatively coupled with the push rod and the indicator.2. The gauge assembly of claim 1 , wherein the trigger assembly comprises a trigger claim 1 , a trigger base claim 1 , a trigger axle and a handle.3. The gauge assembly of claim 1 , wherein the push rod moves vertically up and down within the gauge assembly.4. The gauge assembly of claim 1 , wherein the push rod moves vertically up and down within a channel assembly.5. The gauge assembly of claim 1 , wherein the bearing housing assembly provides lateral and longitudinal support to the push rod.6. The gauge assembly of claim 1 , wherein the indicator comprises a digital readout.7. The gauge assembly of claim 1 , wherein the indicator is operatively coupled claim 1 , communicatively coupled or a combination thereof with a computer system.8. The gauge assembly of claim 1 , wherein the indicator is operatively coupled claim 1 , communicatively coupled or a combination thereof with a computer system through a wireless ...

Steerable Earth Boring Assembly Having Flow Tube with Static Seal

A steerable earth boring assembly which includes an annular collar and a drive shaft with a drill bit, where the shaft pivots with respect to the collar. An upstream portion of the shaft inserts into an orientation sleeve which resides in the collar. An axial bore is obliquely formed through the sleeve, and in which the upstream portion inserts. Rotating the sleeve causes precession of the upstream portion, thereby pivoting the drill bit obliquely to the collar. Selective rotation of the sleeve orients the drill bit into a designated orientation for forming a deviated wellbore. Included in the assembly is a flow tube with an end in sealing contact with the drive shall. 1. A steerable earth boring assembly comprising:an annular collar that has an end in selective engagement with a drill string;an annular flow tube disposed in the collar that is in fluid communication with an annulus in the drill string;a drive shaft coupled with the collar and that is pivotable with respect to the flow tube;a bore axially formed through the drive shaft that selectively receives an earth boring bit and that is in fluid communication with the flow tube; anda sealing element that defines a static seal between the flow tube and drive shaft.2. The steerable earth boring assembly of claim 1 , wherein the bore has a diameter that increases with distance away from the profile to define a shroud portion claim 1 , and wherein the flow tube inserts into the shroud portion claim 1 , so that when the drive shaft pivots an inner diameter of the bore within the shroud portion is spaced away from an outer surface of the flow tube.3. The steerable earth boring assembly of claim 1 , wherein the sealing element continues to block a flow of fluid when the drive shaft pivots with respect to the collar.4. The steerable earth boring assembly of claim 1 , wherein the sealing element comprises an elastomeric O-ring that circumscribes the flow tube.5. The steerable earth boring assembly of claim 1 , further ...

SYSTEM AND METHOD FOR MANAGING BATTERIES FOR USE IN A DOWNHOLE DRILLING APPLICATION

The present disclosure is directed at methods, systems, and techniques for managing batteries for use in a downhole drilling application. The system includes a power bus, pairs of battery terminals for connecting to batteries, switching circuitry that connects and disconnects the batteries to the power bus, data collection circuitry that obtains battery parameters obtained during system operation, and a controller that controls the switching circuitry and receives the battery parameters. A control line connects the controller to the switching circuitry and a data line connects the controller to the data collection circuitry, with the control and data lines being distinct such that control and data signals are not multiplexed with each other. 1. A battery management system for use in a downhole drilling application , the battery management system comprising:(a) a power bus;(b) pairs of battery terminals, wherein each of the battery terminals is for connecting to a battery;(c) switching circuitry operable to electrically connect the power bus to and to disconnect the power bus from any one or more of the pairs of battery terminals electrically connected in parallel;(d) data collection circuitry operable to obtain battery parameters of batteries connected to the pairs of battery terminals;(e) a controller operable to control the switching circuitry and to receive the battery parameters from the data collection circuitry; and(f) a control line communicatively connecting the controller to the switching circuitry and a data line, distinct from the control line, communicatively connecting the controller to the data collection circuitry.2. The system of wherein there are multiple control lines claim 1 , and the controller is configured to use each of the control lines to control whether only one of the pairs of battery terminals is connected to or disconnected from the power bus.3. The system of wherein there are multiple data lines claim 1 , and the controller is ...

System and method for downhole sensing

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.

Tool string failure control in a bottom hole assembly

A system for remediating a bus sectioning events, such as a bus failure or controlled sectioning, comprises a plurality of nodes coupled together by a bus in a tool string used in a bottom hole assembly (BHA). Each node comprises a bus switch configured to isolate the node from a section of the bus. Upon a bus sectioning event, a first sub-tool string and a second sub-tool string are created on either side of the bus section to be isolated, each of which independently operate in parallel. Communication between the first and second sub-tool buses is established through respective nodes connected to each sub-tool bus that comprise a wireless communication transceiver configured to convey signals along the tool string. Alternatively or additionally, each of the sub-tool buses has a node with telemetry for communicating with the surface. Accordingly, each of the sub-tool busses continues independently operating normally.

DOWNHOLE INTERVENTION OPERATION OPTIMIZATION

Methods and systems for generating intervention programs for a downhole formation including collecting mud-logging data during a drilling operation, wherein the drilling operation forms a borehole through the formation, generating zone characterization of one or more zones along the borehole based on the collected mud-logging data, defining targeted zones of the one or more zones along the borehole, generating a treatment characterization for each targeted zone based on the collected mud-logging data, and generating an intervention treatment design based on the targeted zones and associated treatment characterizations. 1. A method for generating an intervention program for a downhole formation , the method comprising:collecting mud-logging data during a drilling operation, wherein the drilling operation forms a borehole through the formation;generating zone characterization of one or more zones along the borehole based on the collected mud-logging data;defining targeted zones of the one or more zones along the borehole;generating a treatment characterization for each targeted zone based on the collected mud-logging data; andgenerating an intervention treatment design based on the targeted zones and associated treatment characterizations.2. The method of claim 1 , further comprising performing an intervention operation based on the intervention treatment design.3. The method of claim 2 , wherein the intervention operation is one of an acidizing operation claim 2 , a fracturing operation claim 2 , or a non-acid mud removal treatment.4. The method of claim 1 , wherein each zone within the formation has a unique geologic property and wherein the treatment characterization is based on the geologic property of the respective targeted zone.5. The method of claim 4 , wherein the geologic property comprises as least one of porosity claim 4 , permeability claim 4 , density claim 4 , rock property claim 4 , and fluid property.6. The method of claim 1 , wherein the zone ...

METHOD FOR INSTALLING FIBER ON PRODUCTION CASING

A method of assembling an optical fiber cable on production casing includes positioning the optical fiber cable against a production casing at a hole of a well site, and affixing the optical fiber cable against the production casing by applying an adhesive to the production casing to secure the optical fiber cable against the production casing. The method further includes applying pressure to the adhesive to adhesively bond the optical fiber cable to the production casing along a length of the production casing while the production casing is being run-in-hole. 1. A method of assembling an optical fiber cable on production casing , the method comprising:positioning the optical fiber cable against a production casing at a hole of a well site;affixing the optical fiber cable against the production casing by applying an adhesive to the production casing to secure the optical fiber cable against the production casing; andapplying pressure to the adhesive to adhesively bond the optical fiber cable to the production casing along a length of the production casing while the casing is being run-in-hole.2. The method of claim 1 , wherein the adhesive comprises an adhesive tape.3. The method of claim 2 , wherein the affixing comprises wrapping the adhesive tape radially over the optical fiber cable and the production casing in a series of radial bands spaced apart from each other at pre-determined intervals along the length of the production casing.4. The method of claim 2 , wherein the affixing comprises rolling the adhesive tape linearly over the optical fiber cable and the production casing.5. The method of claim 2 , wherein the production casing is run-in-hole at a predetermined speed claim 2 , and the affixing comprises rolling the adhesive tape linearly over the optical fiber cable and the production casing along the length of the casing at a speed matching the speed at which the casing is run-in-hole.6. The method of claim 2 , wherein the affixing comprises wrapping the ...

SYSTEM AND METHOD OF NON-LINEAR PROBABILISTIC FORECASTING TO FOSTER AMPLIFIED COLLECTIVE INTELLIGENCE OF NETWORKED HUMAN GROUPS

Systems and methods for amplifying the collective intelligence of networked human groups engaged in collaborative forecasting of future events having two possible outcomes. During a real-time session a computing device for each user displays a forecasting prompt and a dynamic user interface which includes a user-manipulatable marker moved by the user between a first limit and a second limit, where the position of the marker defines a forecasted probability of each possible outcome. The display also includes a first reward value and a second reward value, both of which are interactively responsive to the marker position. During a first time period, users manipulate the markers. After the first time period, a perturbation stimulus is displayed. During a second time period, users again manipulate the markers. After the second time period, a final group forecast is calculated based on the data collected during the first and second time periods. 1. A system for amplifying a collective intelligence of a networked human group engaged in real-time probabilistic forecasting of a future event having a first possible outcome and a second possible outcome , the system comprising:a plurality of computing devices, each including a graphical display, a user interface, a collaboration application running on the computing device, and configured for network communication; and [ a user-manipulatable marker that can be moved by the user across a range of positions between a first limit and a second limit, the position of the marker with respect to each of the two limits defining the forecasted probability of each of the two possible outcomes of the future event,', 'a first reward value visually associated with the first possible outcome, the first reward value interactively responsive to the position of the user manipulatable marker, and', 'a second reward value visually associated with the second possible outcome, the second reward value interactively responsive to the position of the ...

DOWNHOLE COMMUNICATION

A wellbore communication system () comprises a downhole tool () having a downhole transmitter (), a sensing element () located at surface and coupled to a surface receiver (), and an insulated slickline () having an electrically conductive core surrounded by an insulating coating. The slickline is attached to the downhole tool and coupled to the downhole transmitter. The sensing element is capacitively coupled to the slickline so as to permit movement of the slickline relative thereto and so as to an electric field to extend from the core of the slickline through the insulating coating to the sensing element for transmission of information from the downhole transmitter to the surface receiver via the slickline and the sensing element. 1. A wellbore communication system comprising:a downhole tool having a downhole transmitter;a sensing element located at surface and coupled to a surface receiver; andan insulated slickline having an electrically conductive core surrounded by an insulating coating,wherein the slickline is attached to the downhole tool and coupled to the downhole transmitter, and the sensing element and the slickline are capacitively coupled so as to permit relative movement therebetween and so as to permit an electric field to extend from the core of the slickline to the sensing element through the insulating coating of the slickline for transmission of information from the downhole transmitter to the surface receiver via the slickline and the sensing element.2. (canceled)3. A wellbore communication system according to claim 1 , wherein the sensing element defines a surface profile which is substantially complementary to and disposed towards an outer surface of the slickline.4. A wellbore communication system according to claim 1 , wherein the sensing element defines a generally concave surface profile which is disposed towards an outer surface of the slickline.5. A wellbore communication system according to claim 1 , wherein the sensing element at ...

ACOUSTICALLY ENHANCED OPTICAL CABLES

Methods and apparatus to control the acoustic properties of optical cables used as in-well oil and gas probes for acoustic monitoring, such as distributed acoustic sensing (DAS). One example aspect provides a solid path for the acoustic wave to propagate from an outside armor layer of the cable to the sensing optical waveguide embedded therein. Another example aspect offers ways to spatially dispose the optical sensing elements to create response delays indicative of the propagation speed and/or direction of an acoustic wave. Yet another example aspect provides ways to utilize additional spectral interrogation to increase ultimate spatial resolution. Yet another example aspect provides ways to locally vary the acoustic properties along the length of the cable. 1. An optical cable comprising:a tube;an optical waveguide disposed in the tube; andone or more solid structures disposed between an inner surface of the tube and an outer surface of the optical waveguide, the one or more solid structures being configured to form at least a portion of a solid path for acoustic waves to travel from an environment outside the tube to the optical waveguide.2. The optical cable of claim 1 , wherein the one or more solid structures contact the optical waveguide.3. The optical cable of claim 1 , wherein the one or more solid structures are attached to the inner surface of the tube at one or more locations along a length of the tube.4. The optical cable of claim 3 , wherein the one or more solid structures are attached to the inner surface of the tube via at least one of solder or an adhesive.5. The optical cable of claim 1 , wherein the one or more solid structures comprise a strip of material having a plurality of bends.6. The optical cable of claim 5 , wherein the plurality of bends are periodic for at least a portion of the strip.7. The optical cable of claim 6 , wherein the plurality of bends have a first periodicity for a first portion of the strip and a second periodicity for ...

SENSING DRILL BIT WEAR UNDER DOWNHOLE CONDITIONS

Methods and systems are described for drilling a wellbore. A method includes: sensing electrical resistance of an insulated conductor extending from a surface of a drill bit to a sensor inside the drill bit; calculating drill bit dimensions based on the sensed electrical resistance; and transmitting sensed electrical resistance, calculated drill bit dimensions, or both uphole to a system for controlling drilling operations. 1. A method for drilling a wellbore , the method comprising:sensing electrical resistance of an insulated conductor extending from a surface of a drill bit to a sensor inside the drill bit;calculating drill bit dimensions based on the sensed electrical resistance;correlating a rate of penetration with drill bit dimensions; andtransmitting sensed electrical resistance, calculated drill bit dimensions, or both uphole to a system for controlling drilling operations.2. (canceled)3. The method of claim 1 , further comprising calculating lost time associated with reductions in drill bit dimensions.4. The method of claim 3 , further comprising comparing the lost time associated with reductions in drill bit dimensions with non-productive time associated with replacing the drill bit.5. The method of claim 1 , further comprising calculating time until drill bit replacement is required based on a rate of reduction of drill bit dimensions.6. The method of claim 1 , further comprising updating a drilling plan based on the calculated drill bit dimensions.7. The method of claim 1 , further comprising providing calculated drill bit dimensions as input to a drilling automation algorithm.8. A system for drilling wellbores claim 1 , the system comprising: an electrical resistance sensor disposed inside the drill bit;', 'two insulated conductors extending from a surface of the drill bit to the sensor;', 'an onboard computer operable to calculate drill bit dimensions based on electrical resistance measured by the electrical resistance sensor; and', wherein the data ...

Distributed nondestructive structural defects detection in slickline cables

In some embodiments, a distributed nondestructive inspection method for slickline cable structural defect detection transmits a light pulse along an optical waveguide in the slickline cable. A reflected light signal is 5 received from the optical waveguide in response to the light pulse. Defects can then be determined in the slickline cable based on variations in scattering intensity, phase shift, specific spectral signature, power spectral density, strain amplitude, and/or transmission loss of the reflected light signal as compared to the light pulse.

Ultra-slim nuclear magnetic resonance tool for oil well logging

NMR properties of earth formations are determined using a logging device movable in a borehole. The logging device includes a magnet assembly to generate a static magnetic field and an antenna expandable from the surface of the magnet assembly into the borehole toward the borehole wall to increase the magnetic dipole moment of the antenna. The logging device can be lowered or raised through a drill pipe with the magnet assembly being configured to generate no magnetic field while the device is conveyed within the drill pipe. The logging device may also include a side-looking sensor to acquire fast relaxation component of the NMR signals.

Systems and Methods for Wellbore Logging to Adjust for Downhole Clock Drift

A method for logging a wellbore includes positioning a downhole tool having a downhole clock in the wellbore, logging the wellbore with the downhole tool, transmitting a surface signal from a wellbore surface to the downhole tool, and receiving the surface signal at the downhole tool. The method also includes transmitting a downhole signal from the downhole tool to the surface, receiving the downhole signal at the wellbore surface, and determining clock drift based on an arrival time of the surface signal at the downhole tool and an arrival time of the downhole signal at the wellbore surface. 1. A method for logging a wellbore , the method comprising:positioning a downhole tool comprising a downhole clock in the wellbore;logging the wellbore with the downhole tool;transmitting a surface signal from a wellbore surface to the downhole tool;receiving the surface signal at the downhole tool;transmitting a downhole signal from the downhole tool to the surface;receiving the downhole signal at the wellbore surface;determining clock drift based on an arrival time of the surface signal at the downhole tool and an arrival time of the downhole signal at the wellbore surface.2. The method of claim 1 , wherein transmitting the surface signal comprises performing transmission of a data sequence from the wellbore surface to the downhole tool using at least one of mud-pulse telemetry claim 1 , electromagnetic telemetry claim 1 , and acoustic telemetry.3. The method of claim 1 , wherein transmitting the downhole signal comprises transmitting a data sequence from the downhole tool to the wellbore surface using at least one of mud-pulse telemetry claim 1 , electromagnetic telemetry claim 1 , and acoustic telemetry.4. The method of claim 1 , wherein transmitting the surface signal and transmitting the downhole signal comprise transmitting using a symmetric communication channel.5. The method of claim 1 , further comprising transmitting the downhole signal at a given time after the ...

Data Transmission In Drilling Operation Environments

Apparatus, systems, and methods may operate to transmit a data signal along a transmission line extending lengthwise along a drill string, the transmission line comprising an outer conductive path provided by a tubular wall of a drill pipe that extends along the drill string; and an internal conductive path extending along an interior passage that is bounded by a radially inner cylindrical surface of the drill pipe and along which drilling fluid is conveyed, the inner conductive path being substantially insulated from the outer conductive path. Additional apparatus, systems, and methods are described. 133-. (canceled)34. A system comprising:a drill string that extends along at least part of a wellbore, the drill string comprising drill pipe sections that are connected together end-to-end in series, with each drill pipe section having a tubular wall that is of electrically conductive material and that defines an interior passage extending along the drill string to convey drilling fluid, the drill string providing a signal transmission line that comprises:an outer conductive path formed by the tubular walls of the drill pipe sections, and a first electrode proximate one end of the one of the drill pipe sections,', 'a second electrode proximate an opposite end of the one of the drill pipe sections, and', 'a conductive strip electrically connecting the first and second electrodes, with a width of the conductive strip being larger than a width of either the first electrode or the second electrode, wherein the width is measured along a longitudinal direction of the drill string, and a length of the conductive strip being smaller than a length of either the first electrode or the second electrode, wherein the length is measured around a circumference of the drill string; and, 'an internal conductive path extending along the interior passage, the internal conductive path being substantially electrically insulated from the outer conductive path, with each one of the drill ...

Utility Mapping and Data Distribution System and Method

A system and method of mapping underground utilities and other subsurface objects involves one or more of acquiring utility location data using a number of different detectors and sensors, processing the multiple detector/sensor output data to produce mapping data, storing the mapping data in a database, and providing access to and use of the stored mapping data by subscribing users on a usage fee basis. 1. A method , comprising:providing a three-dimensional geographic reference model comprising at least data for existing utilities within a subsurface volume of interest;receiving a plurality of disparate data sets generated by a plurality of disparate sensors configured to evaluate the subsurface volume of interest, the disparate data sets comprising disparate sensor data and associated geographic location data;fusing the disparate data sets to produce fused data representative of one or more utilities detected within the subsurface volume of interest;updating the geographic reference model to include the one or more detected utilities; andgenerating a three-dimensional map of the existing and detected utilities within the subsurface volume of interest using the geographic reference model.2. The method of claim 1 , wherein the three-dimensional map indicates the geographical position and a depth of at least the detected utilities within the subsurface volume of interest.3. The method of claim 1 , wherein the three-dimensional map indicates the geographical position and a depth of the existing and detected utilities within the subsurface volume of interest.4. The method of claim 1 , further comprising displaying or generating a report of the three-dimensional map.5. The method of claim 1 , further comprising:displaying the three-dimensional map; anddisplaying data associated with one or more of the disparate sensors or one or more of the detected utilities.6. The method of claim 1 , further comprising:receiving ground-truth data for one or more of the detected ...

METHODS FOR DETERMINING A VOLUME FRACTION OF WATER AND WATER SALINITY IN ORGANIC SHALE RESERVOIRS USING MULTI-FREQUENCY DIELECTRIC WELL LOGGING MEASUREMENTS

The subject disclosure relates to a method for determining a volume fraction of water and water salinity in organic shales and other geological formations. The method includes a knowledge of complex formation permittivity at several frequencies and minimizes or excludes dependency on external parameters, such as the permittivity of the formation mineral phase. 1. A method for characterizing a geological formation , comprising:using a downhole logging device to perform multifrequency electromagnetic measurements of the formation;determining a plurality of complex permittivities of the formation at a plurality of frequencies from the multifrequency electromagnetic measurements;determining a plurality of complex permittivities of water in the formation at the plurality of frequencies from the multifrequency electromagnetic measurements; anddetermining a value of at least one formation parameter from the plurality of complex permittivities of the formation and the plurality of complex permittivities of water in the formation, wherein the at least one formation parameter is selected from the group consisting of water-filled porosity of the formation, water salinity, water saturation, tortuosity of water-filled pore space, and combinations thereof.2. The method of claim 1 , wherein:the plurality of complex permittivities of the formation, the plurality of complex permittivities of water in the formation and the value of the at least one formation parameter are determined by a processor.3. The method of claim 1 , wherein:the formation comprises organic shale; andthe value of the at least one formation parameter is determined from the plurality of complex permittivities of the formation and the plurality of complex permittivities of water in the formation without determining or providing as input information characterizing mineralogy and hydrocarbon content including kerogen of the formation.4. The method of claim 1 , wherein:the at least one formation parameter comprises ...

Measurement of Torque with Shear Stress Sensors

In some examples, a downhole torque measurement tool comprises a first surface of a structure and a second surface of the structure. The second surface is facing the first surface and a shear stress sensor is positioned on the first surface. A flexible coupling is positioned between the shear stress sensor and the second surface, and the flexible coupling is coupled to the first and second surfaces. 14-. (canceled)5. The tool of claim 9 , wherein the flexible coupling is selected from the group consisting of: silicone rubber; urethane rubber; natural rubber; styrene-butadiene rubber; butylrubber; and combinations thereof.68-. (canceled)9. A downhole torque measurement tool claim 9 , comprising:a lower cylindrical sub having a box end and a pin end;an upper cylindrical sub having a box end, a pin end and an inner bore with an inner surface extending between the box end and the pin end,wherein the box end of the upper cylindrical sub is connected to the pin end of the lower cylindrical sub;wherein the lower cylindrical sub comprises an outer cylindrical shaft having a hollow cavity extending parallel to a longitudinal axis of the outer cylindrical shaft and an inner cylindrical shaft positioned within the hollow cavity and extending parallel to the longitudinal axis of the outer cylindrical shaft, the first and second shafts each having a common end coupled together and forming a unitary structure at the box end of the lower cylindrical sub; andwherein the inner cylindrical shaft has an extended end that extends a length greater than a length of the outer cylindrical shaft at the pin end of the lower cylindrical sub such that the extended end of the inner cylindrical shaft extends into the bore of the upper cylindrical sub and forms an annular space;a flexible coupling positioned within the annular space and at least partially encircling the extended end of the inner cylindrical shaft, the flexible coupling coupled to the extended end of the inner cylindrical shafts; ...

Reducing Disturbance During Fiber Optic Sensing

Reducing disturbance during fiber optic sensing. An in-well fiber optic sensing system includes a device insulated to be disturbance-resistant. The device is in a fiber optic communication path between a source and a target configured to be received in a well. The device is configured to receive a parameter sensing signal transmitted from the source to the target and produce a reference signal. The fiber optic sensing system includes a signal interrogation system connected to the device in the fiber optic communication path. The signal interrogation system is configured to receive the reference signal from the device and to receive a response signal from the target in response to the parameter sensing signal. The response signal represents the parameter of interest. The signal interrogation system is configured to determine the parameter of interest based, in part, on the reference signal and the response signal.

SYSTEM AND CONSOLE FOR MONITORING DATA STREAM QUALITY IN DRILLING AND PRODUCTION OPERATIONS AT A WELL SITE

A well advisor system and console for monitoring and managing monitoring and managing data stream quality in well drilling and production operations. The system may be accessed through one or more workstations, or other computing devices, which may be located at a well site or remotely. The system is in communication with and receives input from various sensors. It collects real-time sensor data sampled during operations at the well site. The system processes the data, and provides nearly instantaneous numerical and visual feedback through a variety of graphical user interfaces (“GUIs”), which are presented in the form of an operation-specific console. A plurality of data checks are dynamically run on the data streams to determine the presence and quality of the data, and data quality indicators are presented on the various consoles and dashboards. 1. A system for monitoring data stream quality at a well-site , comprising:a plurality of sensors to sample or detect parameters related to drilling or production operations in a well, said plurality of sensors comprising surface sensors or downhole sensors or a combination thereof;one or more computing devices adapted to receive parameter information in real time from said plurality of sensors, said one or more computing devices each further comprising a processor or microprocessor, said processor or microprocessor adapted to process the received parameter information to calculate derived parameters, and to perform one or more data quality checks on the received parameter information or the derived parameters; anda visual display, coupled to said one or more computing devices, for displaying some or all of the received parameter information and said derived parameters, and for displaying one or more indicators of data quality states based on the one or more data quality checks.2. The system of claim 1 , wherein the visual display of some or all of the received parameter information and said derived parameters claim 1 , ...

SELF-POWERED ACTIVE VIBRATION AND ROTATIONAL SPEED SENSORS

Self-powered active sensing systems (SASS) for use in downhole drilling environments are disclosed. Sensor devices of the SASS can include a self-powered rotational speed sensor including a ring structure attached around a drill string. The ring rotates within a groove formed in an outer housing. Bearings on the ring are arranged to contact moveable members extending from the housing into the groove thereby causing the moveable member to generate an electrical signal representing rotational speed. The SASS can include a vibration sensor having a ring spring mounted within a housing. Spherical bearings on the outer surface of the ring are configured to contact screens that are mounted to the housing and that generate a signal representing movement of the bearing/ring from vibration. Multiple SASS units configured to wirelessly transmit sensor data can be placed along a drill string providing a distributed self-powered system for measuring downhole parameters. 1. A self-powered active sensing system for use in a downhole drilling environment , the system comprising: [ a bearing extending from an outer surface of the first structure;', 'a housing disposed about the first structure and the portion of the drill string, wherein the housing includes:', 'an interior wall that defines a hollow central opening of a sufficient diameter for the drill string to extend therethrough, wherein the interior wall is shaped to define an annular groove extending circumferentially about the central opening, wherein the ring is housed at least partially within the annular groove and rotatable relative to the housing, and', 'a moveable member housed within a recess formed in the interior wall and that extends into the annular groove, wherein the moveable member opposes the bearing, wherein upon rotation of the first structure relative to the housing, the bearing is configured to contact the moveable member and wherein the moveable member is configured to translate into the recess as a ...

FIBER DEPLOYMENT SYSTEM AND COMMUNICATION

A flow assembly is deployed downhole in a casing for a cementing operation. The flow assembly has a spool with an optical cable. As cement is pumped downhole and through the flow assembly, a dart attached to the optical cable on the spool is dragged with the flow of cement. Cement flow is stopped based on signals along the optical cable that the dart is at a desired location downhole. 1. A method comprising:providing an optical fiber coiled about a bobbin at a first location in a wellbore in a subsurface formation, wherein a first end of the optical fiber is communicatively coupled to a data processing system;pumping a first fluid through the wellbore, wherein a second end of the optical fiber is dragged through the wellbore via the pumped first fluid; andmonitoring, with the data processing system, a first wellbore condition based on a signal transmitted via the optical fiber at least while the optical fiber is dragged through the wellbore.2. The method of claim 1 , further comprising:wherein pumping the first fluid through the wellbore comprises pumping the second end of the optical fiber to a second location in the wellbore, and wherein the second end of the optical fiber engages with float equipment at the second location.3. The method of claim 2 , further comprising pumping a second fluid through the wellbore claim 2 , wherein pumping the first fluid comprises pumping the first fluid in a first direction and wherein pumping the second fluid comprises pumping the second fluid in a second direction opposite the first direction.4. The method of claim 3 , wherein pumping the second fluid comprises a reverse cementing operation.5. The method of claim 3 , wherein pumping the second fluid comprises pumping the second fluid with use of a crossover tool.6. The method of claim 1 , wherein the second end of the optical fiber is coupled with a drag member and wherein the drag member is dragged through the wellbore via the pumped first fluid.7. The method of claim 1 , ...

DOWNHOLE SENSOR APPARATUS AND RELATED SYSTEMS, APPARATUS, AND METHODS

A downhole sensor apparatus may include a structure securing a circuit board. The structure may be configured to be inserted into a recess in a tool on a drill string. The downhole sensor apparatus may include one or more sensors coupled to the circuit board and a cap over the structure. The downhole sensor apparatus may further include a data port electrically coupled to the circuit board and configured to transmit data from the sensors to an external device. The downhole sensor apparatus may include a threaded element configured to thread into complementary threads in the recess in the tool. The downhole sensor apparatus may be configured to operate in an idle condition. The downhole sensor apparatus may compare readings from at least two sensors to threshold downhole conditions and begin normal operation when the readings from the at least two sensors meet or exceed the threshold downhole conditions. 1. A downhole sensor apparatus comprising:a structure carrying a circuit board, the structure configured to be inserted into a recess in a tool on a drill string;one or more sensors coupled to the circuit board;a cap over the structure;a data port disposed through the cap, the data port electrically coupled to the circuit board and configured to transmit data from the one or more sensors to an external device; anda securing element configured to engage a complementary feature in the recess in the tool, the securing element configured to secure the structure to the tool.2. The downhole sensor apparatus of claim 1 , wherein the cap comprises the securing element.3. The downhole sensor apparatus of claim 1 , wherein the cap comprises a ridge proximate a base of the cap.4. The downhole sensor apparatus of claim 3 , wherein the securing element comprises a locking ring separate from the structure and the cap claim 3 , wherein the locking ring is configured to contact the ridge of the cap and secure the cap and the structure to the tool.5. The downhole sensor apparatus of ...

SWITCH DEVICE WITH NON-ADDRESSABLE SCHEME FOR WELLBORE OPERATIONS

A non-addressable switch device that is part of a chain of switch devices in a gun string, the non-addressable switch device including a first switch configured to make an electrical connection between an electrical line and another non-addressable switch device of the chain of switch devices; a second switch configured to make an electrical connection between a detonator and the electrical line; and a processor Pconnected to the first and second switches and configured to close and open the first and second switches. The processor Pis configured to not use a digital address, and the processor Pis configured to perform one of plural functions based on a corresponding pulse received along the electrical line. 1. A non-addressable switch device that is part of a chain of switch devices in a gun string , the non-addressable switch device comprising:a first switch configured to make an electrical connection between an electrical line and another non-addressable switch device of the chain of switch devices;a second switch configured to make an electrical connection between a detonator and the electrical line; and{'sub': 'A', 'a processor Pconnected to the first and second switches and configured to close and open the first and second switches,'}{'sub': 'A', 'wherein the processor Pis configured to not use a digital address, and'}{'sub': 'A', 'wherein the processor Pis configured to perform one of plural functions based on a corresponding pulse received along the electrical line.'}2. The non-addressable switch device of claim 1 , wherein the corresponding pulse is a frequency pulse having a unique frequency.3. The non-addressable switch device of claim 1 , wherein the processor is configured to receive plural pulses claim 1 , each pulse being associated with a different function and a unique frequency.4. The non-addressable switch device of claim 1 , wherein the processor is configured to automatically enter a sleep mode when the first switch is closed.5. The non- ...

Method and Apparatus for Looking Ahead of the Drill Bit

A system for looking ahead of a drill bit includes a plane wave generator (PWG) tool deployed downhole inside a wellbore for formation evaluation and generation of reflection data, a power source providing electric power to the PWG tool for the formation evaluation and the generation of the reflection data, a surface control system receiving the reflection data from the PWG tool and generating image data of a subsurface rock formation based on the received reflection data, and a wireline that electrically couples the PWG tool to the power source and communicatively couples the PWG tool to the surface control system. The PWG tool includes a beam forming network (BFN) architecture and a plurality of antenna elements mounted to a base of the PWG tool to transmit and receive electromagnetic signals. 1. A system for looking ahead of a drill bit , comprising:a plane wave generator (PWG) tool configured for being deployed downhole inside a wellbore for formation evaluation and generation of reflection data;a power source configured to provide electric power to the PWG tool for the formation evaluation and the generation of the reflection data;a surface control system configured to receive the reflection data from the PWG tool and generate image data of a subsurface rock formation based on the received reflection data; anda wireline that electrically couples the PWG tool to the power source and that communicatively couples the PWG tool to the surface control system;wherein the PWG tool includes a beam forming network (BFN) architecture and a plurality of antenna elements mounted to a base of the PWG tool and configured to transmit and receive electromagnetic signals.2. The system according to claim 1 , wherein:the base of the PWG tool is a cylindrical base and a space between the plurality of antenna elements on the base is filled with microwave absorbent material,the plurality of antenna elements are mounted on the cylindrical base as a circular array of a plurality of ...

ELASTIC ADAPTIVE DOWNHOLE ACQUISITION SYSTEM

A method can include performing an operation using a system where the operation depends on a decision made via a digital decision model stored in memory of the system; responsive to a decision state of the digital decision model, transmitting a request to update the digital decision model; and responsive to the request, receiving an updated digital decision model, where the updated digital decision model includes at least one new decision state that improves performance of the operation of the system. 1. A method comprising:performing an operation using a system wherein the operation depends on a decision made via a digital decision model stored in memory of the system;responsive to a decision state of the digital decision model, transmitting a request to update the digital decision model; andresponsive to the request, receiving an updated digital decision model, wherein the updated digital decision model comprises at least one new decision state that improves performance of the operation of the system.2. The method of wherein the digital decision model comprises a regression tree model.3. The method of wherein the system is moving in an environment claim 1 , wherein the operation comprises a sensing operation that acquires sensor measurements of samples in the environment while the system is moving claim 1 , wherein the digital decision model depends on a signal to noise ratio of the sensing operation claim 1 , and wherein the signal to noise ratio changes responsive to physical changes in the environment that occur responsive to the system moving in the environment.4. The method of comprising selecting claim 1 , based on the decision state claim 1 , a flag from a plurality of different flags stored in the memory claim 1 , wherein the request corresponds to the selected flag claim 1 , wherein the decision state comprises a terminal state of the digital decision model claim 1 , and wherein the at least one new decision state of the updated digital decision model ...

ANTENNA FOR DOWNHOLE COMMUNICATION USING SURFACE WAVES

An assembly can include a casing string with an outer surface. The assembly can also include an antenna for wirelessly communicating data by generating a surface wave that propagates along an interface surface. The antenna can be positioned coaxially around the casing string. The antenna can include a cylindrically shaped conductor that is positionable coaxially around an outer surface of a casing string for generating a magnetic field component of the surface wave that is non-transverse to a direction of propagation of the surface wave along the interface surface. The antenna can also include a pair of conductive plates positioned at an angle to the cylindrically shaped conductor for generating an electric field component of the surface wave. 1. An assembly comprising:a casing string with an outer surface; and a cylindrically shaped conductor that is positionable coaxially around the outer surface of the casing string for generating a magnetic field component of the surface wave that is non-transverse to a direction of propagation of the surface wave along the interface surface; and', 'a pair of conductive plates positioned at an angle to the cylindrically shaped conductor for generating an electric field component of the surface wave., 'an antenna for wirelessly communicating data by generating a surface wave that propagates along an interface surface, the antenna positioned coaxially around the casing string and comprising2. The assembly of claim 1 , wherein the antenna is operable to generate the electric field component such that the electric field component is non-transverse to the direction of propagation of the surface wave along the interface surface.3. The assembly of claim 2 , wherein the interface surface is between the casing string and a cement sheath.4. The assembly of claim 1 , wherein the angle is 0 degrees or 90 degrees.5. The assembly of claim 1 , wherein the antenna is operable to generate the surface wave responsive to receiving a signal with a ...

Plug Tracking Using Through-The-Earth Communication System

A system for tracking an object in oil and gas wellbore operations wherein a releasable object carrying a first signal system is released into tube system associated with a wellbore. The first signal system communicates with one or more second signal systems positioned along the travel path of the object; along the surface of the formation; and/or throughout the wellbore. First signal system and the second signal system may communicate by RF signals. First signal system and any second signal systems positioned on the surface communicate by through-the-earth or very low frequency signals. A global positioning system may be utilized in conjunction with any second signal systems on the surface to identify the absolute location of the object in the underground wellbore. The first signal system carried by the object may be a piezoelectric system disposed to transmit a signal when the object experiences a predetermined pressure.

Method of detecting presence of rfid tags and determining properties of surrounding environment in subterranean formation

A disclosed subsurface detection system includes a first communication device positioned in a borehole and configured to scan a plurality of frequencies in at least a portion of an annulus surrounding an exterior of a tubing including the casing string in the borehole or an interior of the tubing including the casing string. The plurality of frequencies include a first frequency corresponding to a first type of RFID tag and a second frequency corresponding to a second type of RFID tag. The first communication device is further configured to detect a response to the scan from an RFID tag of the first type or the second type in the portion of the annulus or the interior of the tubing. The system further includes a processor configured to receive communication of the detected response from the first communication device, and based on the detected response, determine one or more characteristics of an environment around the corresponding RFID tag (e.g., an intrinsic impedance of a fluid material in the environment).

TUBULAR COMPONENT FOR DRILL STEM CAPABLE OF BEING CABLED, AND METHOD FOR MOUNTING A CABLE IN SAID COMPONENT

A tubular component for a drill stem that can be cabled includes a first end zone, a second end zone, a sheath, the sheath extends between the first end zone and the second end zone, and a liner fixed in a bore of the first end zone. The liner includes at least one take-up chamber for a cable disposed in the sheath. 118-. (canceled)19. A tubular component for a drill stem that can be cabled , comprising:a first end zone;a second end zone;a sheath extending between the first end zone and the second end zone;a cable disposed at least in part in the sheath; anda liner, the liner being fixed in a bore of the first end zone and including at least one take-up chamber for the cable,a length of the cable being greater than a distance between the first and the second end zone such that the take-up chamber is capable of storing an excess length of the cable.20. A component according to claim 19 , further comprising a second supplemental liner fixed in a bore of the second end zone claim 19 , the second supplemental liner also including at least one take-up chamber for the cable.21. A component according to claim 20 , in which the cable is defined such that the excess length of cable capable of being stored in the take-up chamber of the liner has a dimension that differs from that of an excess length of cable capable of being stored in the take-up chamber of the second supplemental liner.22. A component according to claim 19 , in which the take-up chamber has an axial length which is at least twice claim 19 , or at least three times claim 19 , smaller than the excess length of the cable.23. A component according to claim 19 , in which an outside of the cable includes a retaining stopper to calibrate a length of the cable coming from at least one side of the sheath.24. A component according to claim 19 , in which the liner is traversed by an elongate channel that allows the sheath and/or the cable to pass from the chamber to terminal surfaces of the liner.25. A component ...

INTEGRATED CENTERLINE DATA RECORDER

A system includes a sensor carrier and an integrated data recorder. The sensor carrier includes an outer sub body and an inner sub body. The inner sub body is coupled to the outer sub body by a support leg. The inner sub body includes a recess formed therein. The sensor carrier includes a flow path defined as the space between the outer sub body, the inner sub body, and the support leg. The integrated data recorder is positioned within the recess of the inner sub body such that the integrated data recorder is substantially at the centerline of the sensor carrier. The integrated data recorder includes a sensor package including one or more drilling dynamics sensors, a processor, a memory module, and an electrical energy source. 1. A system comprising: an outer sub body;', 'an inner sub body, the inner sub body coupled to the outer sub body by a support leg, the inner sub body having a recess formed therein; and', 'a flow path defined as the space between the outer sub body, the inner sub body, and the support leg; and, 'a sensor carrier, the sensor carrier including a sensor package, the sensor package comprising one or more drilling dynamics sensors;', 'a processor, the processor in data communication with the one or more drilling dynamics sensors;', 'a memory module, the memory module in data communication with the one or more drilling dynamics sensors; and', 'an electrical energy source, the electrical energy source in electrical communication with the memory module, the one or more drilling dynamics sensors, and the processor., 'an integrated data recorder positioned within the recess of the inner sub body such that the integrated data recorder is substantially at the centerline of the sensor carrier, the integrated data recorder including2. The system of claim 1 , wherein the electrical energy source comprises a rechargeable or non-rechargeable battery.3. The system of claim 2 , wherein the electrical energy source further comprises an energy harvesting device.4 ...

Modulated Opto-Acoustic Converter

An opto-acoustic subsystem is provided. The subsystem includes an optical transmitter and an actuator device. The optical transmitter can be positioned at a surface of a wellbore. The actuator device can be positioned in the wellbore and can respond to a modulated electrical signal generated from a modulated optical signal received from the optical transmitter by outputting a modulated acoustical signal into an environment of the wellbore.

METHOD AND APPARATUS FOR STRESS MAPPING OF PIPELINES AND OTHER TUBULARS

A stress mapping system and method is operable to determine and map stresses along a conduit. The system includes a tool movable along a conduit and having at least one sensing device for sensing characteristics of the conduit, and a processor operable to process an output of the at least one sensing device. Responsive to processing of the output by the processor, the processor is operable to determine stresses at a surface of the conduit. Responsive to the processing of the output of the at least one sensing device, and responsive to a determination of a location or position of the tool along the conduit, the system generates a map of determined stresses along the conduit. The map of determined stresses provides a visual representation of the stresses determined at and along the surface of the conduit. 1. A stress mapping system operable to determine and map stresses along a conduit , said stress mapping system comprising:a tool movable along a conduit and having at least one sensing device for sensing characteristics of the conduit;wherein said tool includes a position determining device operable to determine the position of said tool as said tool moves along the conduit;a processor operable to process an output of said at least one sensing device;wherein, responsive to processing of the output by said processor, said processor is operable to determine stresses at a surface of the conduit;wherein, responsive to said processing of said output of said at least one sensing device, and responsive to determination of the position of said tool along said conduit, said system generates a map of determined stresses along the conduit; andwherein the map of determined stresses provides a visual representation of the stresses determined at and along the surface of the conduit.2. The stress mapping system of claim 1 , wherein said tool comprises at least one module with each module having at least one sensing device.3. The stress mapping system of claim 1 , wherein said tool ...

System and Method for Communicating Along a Casing String Including a High Magnetic Permeability Substrate

A communication assembly is described that when placed around a string casing in a wellbore transmits data along a pipe string from the wellbore to, for example, the surface of the well. The assembly includes a high magnetic permeability substrate to eliminate signal loss to the casing string thereby enhancing the signal and improving data transmission.

GENERATOR FOR LATEROLOG TOOL

A method and apparatus for generating a low distortion sinusoidal signal with controllable amplitude for use with downhole tools, such as an array laterolog. In preferred embodiment, a signal-generating digital-to-analog converter is provided to produce a sinusoidal or other waveform at full scale. An amplitude-controlling digital-to-analog converter provides a voltage reference for the signal-generating digital-to-analog converter. The tandem combination of two digital-to-analog converters allows the generation of low distortion signals, even at low amplitudes. The amplitude-controlling digital-to-analog converter is provided digital codes by the downhole tool system processor. A high-speed dedicated controller provides digital codes to the signal-generating digital-to-analog converter, which relieves the system processor from the intensive task of providing signal generating codes, thereby freeing processor bandwidth for other system tasks. 1. A downhole tool comprising:a housing having an electrode;first and second digital-to-analog converters disposed in said housing and each having a digital input, a reference input, and an analog output, said analog output of said first digital-to-analog converter being operatively coupled to said reference input of said second digital-to-analog converter, said analog output of said second digital-to-analog converter being operatively coupled to said electrode; andcontrol circuitry coupled to the digital inputs of said first and second digital-to-analog converters.2. The downhole tool of wherein:said control circuitry includes a controller coupled to the digital input of said second digital-to-analog converter for determining a frequency and a shape of a waveform characterizing a signal produced by said second digital-to-analog converter; andsaid control circuitry includes a processor coupled to the digital input of said first digital-to-analog converter for controlling a voltage applied to the reference input of said second ...

SENSORED ELECTRONIC VALVE FOR DRILLING AND WORKOVER APPLICATIONS

Systems and methods for controlling a flow of fluid within a subterranean well includes a sensored electronic valve assembly having a one way valve member operable to allow a flow of fluids in a first direction through the one way valve member and to prevent the flow of fluids in a second direction through the one way valve member. An electronic circuit includes a battery having a battery life of a predetermined time and a command center. A sensor can detect a valve open signal and to deliver the valve open signal to the command center. An opening device is operable to move the one way valve member to a valve open position upon receipt of an engagement signal from the command center. The opening device is inoperable after the predetermined time. The one way valve member is operable to function as a one way valve after the predetermined time. 1. A system for controlling a flow of fluid within a subterranean well with a sensored electronic valve assembly , the system including:a completion system having a tubular string extending into the subterranean well; a one way valve member operable to allow a flow of fluids in a first an uphole direction through the one way valve member and to prevent the flow of fluids in a downhole direction through the one way valve member;', 'an electronic circuit including a battery and a command center, the battery having a battery life of a predetermined time;', 'a sensor operable to detect a valve open signal and to deliver the valve open signal to the command center; and', 'a battery powered opening device operable to move the one way valve member to a valve open position upon receipt of an engagement signal from the command center within the predetermined time only, the battery powered opening device being inoperable after the predetermined time; where, 'the sensored electronic valve assembly located within the tubular string and havingthe one way valve member is operable to function as a one way valve after the predetermined time, ...

Downhole Sensor System Using Resonant Source

A well telemetry system supplies power to downhole sensor nodes employed for obtaining telemetry data in oil wells. The nodes are held in the cement that lines the well and surround the casing. At the surface, an AC power unit is connected to the casing and geological structure that surrounds the cement. Power to nodes is supplied using an AC resonant circuit that generates standing waves of electrical power on the casing. Power from the standing waves is delivered to the nodes which are located at antinodes of the standing wave. The nodes are held in cement that surround the casing, with one of their two electrodes connected to the casing and the other connected to the cement or to geological structure. 1. A downhole node for a well , comprising:a node housing set in cement, surrounding casing of the well;a power electrode extending from the node housing to the casing; anda ground electrode extending from the node housing to the cement and/or surrounding geologic structure.2. The node of claim 1 , wherein the node comprises node circuitry including a tuned filter for receiving power via the power electrode and being grounded via the ground electrode.3. The node of claim 1 , wherein the node comprises node circuitry including a bridge circuit for rectifying power transmitted via the casing.4. The node of claim 1 , wherein the node comprises node circuitry including a regulated supply for conditioning the power transmitted via the casing.5. The node of claim 1 , wherein the node comprises node circuitry including a Zener diode connected between the power electrode and ground electrode for protecting the node from over voltage.6. The node of claim 1 , further comprising an insulating cover over the casing.7. The node of claim 1 , wherein the insulating cover is a layer of plastic.8. The node of claim 7 , wherein the insulating cover is a paint layer.9. The node of claim 1 , wherein the power electrode is connection to the casing is protected with a glass-to-metal seal ...

Systems and Methods for Fracture Mapping via Frequency-Changing Integrated Chips

Systems and methods for fracture mapping may utilize frequency changing to aid in providing high-resolution mapping. Integrated chips may be injected into a well and dispersed into a formation. A downhole tool that provides a transmitter and receiver may be positioned in the well. The transmitter may transmit electromagnetic (EM) signals into the formation. The dispersed integrated chips may receive the transmitted EM signal and return a frequency-changed signal to the receiver of the downhole tool. Utilizing the returned frequency changed signal, the system is able to determine the locations of the integrated chips that have been dispersed into the formation and provide fracture mapping. In another variation, the integrated chips may communicate with each other to provide fracture mapping.

Downhole Surveying

A drillstring first tube portion () for connection to further tube portions () of a drillstring via respective connection means has a side wall () including non ferromagnetic material, and at least one downhole survey device () mounted directly or indirectly on or within the side wall. The survey device has at least one survey instrument to obtain survey data, a power source () and wireless communication means () to wirelessly receive and/or transmit survey data within or on the side wall. A method of conducting a downhole survey of drilling using such an apparatus is also disclosed, as well as a method of obtaining data gathered downhole. The survey device and a core orientation device () may communicate wirelessly, such as when passing each other. 1. A drillstring first tube portion for connection to further tube portions of drillstring via respective connection means , the first tube portion having a side wall including non ferromagnetic material , and at least one downhole survey device mounted directly or indirectly on or within the side wall , the survey device including at least one survey instrument to obtain survey data a power source and wireless communication means to wirelessly receive and/or transmit survey data.2. The first tube portion according to claim 1 , the first tube portion being an elongate tube claim 1 , wherein the side wall extends from the survey device a distance to each of opposite first and second ends of the first tube portion to isolate the survey device from significant magnetic effects of steel portions of the drillstring.3. The first tube portion according to claim 1 , including non ferromagnetic second and third tube portions each configured to releasably connect to a respective one of the two opposite ends of the first tube portion and to releasably connect to a remainder of the drillstring.4. The first tube portion as claimed in claim 1 , wherein the survey device includes instrumentation to measure azimuth and inclination of ...

SYSTEMS AND METHODS FOR GROUND FAULT IMMUNE DATA MEASUREMENT SYSTEMS FOR ELECTRONIC SUBMERSIBLE PUMPS

Provided are systems and methods for ground fault immune data measurement system for electric submersible pumps. A data measurement system coupled to the ESP includes a surface unit coupled to a 3-phase power cable for providing power to a 3-phase motor of the ESP and a downhole unit coupled to the motor of the ESP and located downhole in a well. The downhole unit includes sensor and is configured to generate frequency modulated carrier signals for carrying the sensor data to the surface unit. Each of the frequency modulated carrier signals carries identical sensor data and is modulated to a different frequency. The carrier signals are shunted across the motor windings of the ESP motor and onto the 3-phase power cable via a capacitive coupling. Additionally, another carrier signal carrying control data may be transmitted from the surface unit to the downhole unit. 1. A data measurement system coupled to an electric submersible pump (ESP) , the system comprising:a surface unit coupled to a 3-phase power cable, the 3-phase power cable coupled to a 3-phase motor of the ESP; a plurality of sensors;', 'a processor coupled to the sensors and configured to receive the sensor data; and', 'a modulator coupled to the processor and configured to generate at least three frequency modulated carrier signals for carrying the sensor data to the surface unit, each of the plurality of frequency modulated carrier signals carrying identical sensor data and modulated to a unique frequency;, 'a downhole unit coupled to the motor of the ESP and located downhole in a well, the downhole unit comprisingwherein the downhole unit is capacitively coupled to motor windings of the motor of the ESP and configured to transmit the at least three carrier signals across the capacitive coupling and to the surface unit via the 3-phase power cable.2. The data measurement system of claim 1 , wherein the surface unit comprises:a demodulator configured to demodulate the at least three carrier signals; anda ...

Telemetry System and Method of Operating the Same

Methods and related apparatus pertaining to downhole and surface telemetry, such as a method in which a telemetry system is provided with a communication path formed with an electrically conductive transport medium coupled across a plurality of downhole nodes. Such method includes operating on the communication path with a multi-drop system that provides telemetry to the downhole nodes in a wellbore, including employing modulation in a master-slave arrangement using binary differential phase shift keying or differential quadrature phase shift keying. 1. A method , comprising:providing a telemetry system with a communication path formed with an electrically conductive transport medium coupled across a plurality of downhole nodes;operating on the communication path with a multi-drop system that provides telemetry to the downhole nodes in a wellbore, including employing modulation of a tone in a master-slave arrangement using binary differential phase shift keying or differential quadrature phase shift keying, wherein the telemetry system supports a plurality of downhole functions, and wherein multiple downhole nodes access the communication path without the use of switches.2. The method of claim 1 , further comprising line equalization to compensate for attenuation characteristics of the communication path.3. The method of claim 1 , further comprising identifying on demand each downhole node using a unique node identifier4. The method of claim 1 , further comprising providing a control-type application type claim 1 , wherein a user-initiated command is transmitted from a surface acquisition system to a downhole node to perform a specific downhole action.5. The method of claim 4 , wherein the specific downhole action includes sending a value to surface.6. The method of claim 1 , further comprising providing a second application type which provides surface control for a wellbore perforation addressable switch employing an encoded signal.7. The method of one of claim 1 , ...

Rig telemetry system

A drillstring communications system includes one or more pipe segments, a communication sub coupled to the pipe segment that includes a communication sub antenna, and a leaky feeder antenna in communication with the communication sub antenna.

Apparatus And Method Of Concentric Cement Bonding Operations Before And After Cementation

Method and apparatus for deploying at least one repeatable signal to empirically measure cement bonding before and after operating a tool string assembly comprising a selectively arrangeable tool assembly of a downhole drive tool usable for operating a downhole placement tool with shaft and axial displacement member extendable and retractable therefrom to radially deploy and operate at least one conduit and downhole coupling tool for placing cement and at least one inner conduit proximally concentrically within a surrounding bore, wherein said drive coupling tool is further usable for transmitting or receiving, through a conductance well element into a memory tool, to measure cement bonding about said surrounding bore before and after concentrically cleaning and coupling cement to at least one conduit and surrounding bore. 11118412121288810. A method ( , A-AT) of using at least one logging signal () to empirically measure cement bonding after using an apparatus ( , A-AT) associated with a tool string ( , A-AT) to concentrically dispose at least one inner conduit within a surrounding bore () to provide concentric cementation and cement bonding before and after cementation , said method comprising the steps of:{'b': 8', '3', '3', '3', '2', '2', '2', '6', '7, 'conveying at least one selectively arrangeable tool string () assembly comprising at least one selectively actuatable downhole drive tool (, A-AT), at least one downhole placement tool (, A-AT) having at least one shaft () and an axial displacement member () extendable and retractable from said at least one shaft, and at least one cutting or displacing tool;'}actuating said at least one selectively actuatable downhole drive tool to operate said at least one downhole placement tool to place said at least one cutting or displacing tool within said at least one inner conduit;actuating said at least one cutting or displacing tool to cut or displace said at least one inner conduit proximally concentrically within said ...

Fluidic Modulators and Along String Systems

A well system includes a first fluidic modulator (FM) located at the bottom of the tubular string and a repeater fluidic modulator (FM) located in the tubular string between the first FM and the surface, the repeater FM including a body forming a flow aperture between an inlet and an outlet, the flow aperture providing a constriction to a fluid flowing axially through the tubular string, and a moveable portion operable to alter the flow aperture. To create a modulated pressure pulse the moveable portion may be for example radially shifted in the flow aperture, rotated in the flow aperture, or the rotation of the moveable portion in the flow aperture may be controlled. 1. A well system , comprising:a tubular string extending from a surface into a wellbore;a first fluidic modulator (FM) located at a bottom of the tubular string; anda repeater fluidic modulator (FM) located in the tubular string between the first FM and the surface, the repeater FM comprising a body forming a flow aperture between an inlet and an outlet, the flow aperture providing a constriction to a fluid flowing axially through the tubular string; anda moveable portion operable to alter the flow aperture.2. The well system of claim 1 , wherein the moveable portion is operable to a full open position whereby the moveable portion is substantially removed from the flow aperture.3. The well system of claim 1 , wherein the moveable portion comprises a geometric shape whereby a circumferential portion of the flow aperture is covered when the moveable portion is positioned in the flow aperture.4. The well system of claim 1 , wherein the moveable portion is radially moveable to alter the flow aperture.5. The well system of claim 1 , wherein the moveable portion is rotated to alter the flow aperture.6. The well system of claim 1 , comprising a drive mechanism to radially shift the moveable portion to alter the flow aperture.7. The well system of claim 1 , comprising a drive mechanism to radially shift the ...

DYNAMIC STRAIN DETECTION FOR CABLE ORIENTATION DURING PERFORATION OPERATIONS

A method of perforating a wellbore is provided. The method includes generating a shockwave that propagates throughout said wellbore by firing a perforation device at a perforating direction, and measuring the shockwave at a fiber optic cable in the wellbore using the fiber optic cable. The method further includes determining an orientation of the fiber optic cable relative to the perforating direction based on the shockwave and the perforating direction, and changing the perforating direction based on the orientation of said the optic cable for a subsequent perforation of the wellbore to minimize damage to the fiber optic cable during the subsequent perforation. The fiber optic cable is an existing cable that has been deployed before the method starts. 1. A method of perforating a wellbore , comprising:generating a shockwave that propagates throughout said wellbore by firing a perforation device at a perforating direction;measuring said shockwave at a fiber optic cable in said wellbore using said fiber optic cable, said fiber optic cable being an existing cable;determining an orientation of said fiber optic cable relative to said perforating direction based on said shockwave and said perforating direction; andchanging said perforating direction based on said orientation of said fiber optic cable for a subsequent perforation of said wellbore to minimize damage to said fiber optic cable during said subsequent perforation.2. The method of further comprising placing said perforation device inside said wellbore.3. The method of claim 2 , wherein said placing includes placing said perforation device at a distal end of a casing in said wellbore for an initial perforation.4. The method of claim 3 , wherein said placing includes moving said perforation device to a different location inside said wellbore for said subsequent perforation.5. The method of claim 1 , wherein said changing includes orienting said perforation device to be 90 degrees from said orientation of said ...

INSTRUMENTED BRIDGE PLUGS FOR DOWNHOLE MEASUREMENTS

A system includes a first instrumented bridge plug positionable in a downhole wellbore environment. The first instrumented bridge plug includes an acoustic source for transmitting an acoustic signal. The system also includes a second instrumented bridge plug positionable in the downhole wellbore environment. The second instrumented bridge plug includes an acoustic sensor for receiving a reflected acoustic signal originating from the acoustic signal. The reflected acoustic signal being usable to interpret wellbore formation characteristics of the downhole wellbore environment. 1. A system , comprising:a first instrumented bridge plug positionable in a downhole wellbore environment, the first instrumented bridge plug comprising an acoustic source for transmitting an acoustic signal; anda second instrumented bridge plug positionable in the downhole wellbore environment, the second instrumented bridge plug comprising an acoustic sensor for receiving a reflected acoustic signal originating from the acoustic signal, the reflected acoustic signal being usable to interpret formation characteristics of the downhole wellbore environment.2. The system of claim 1 , wherein the second instrumented bridge plug comprises:an acoustic source to transmit a first set of acoustic signals to one or more additional instrumented bridge plugs; anda transmission signal generator to generate a transmission signal representative of the reflected acoustic signal.3. The system of claim 2 , further comprising:an interpretation module to interpret the formation characteristics using the reflected acoustic signal received by the acoustic sensor, wherein the transmission signal generator transmits the transmission signal to the interpretation module as an acoustic signal to a surface of a wellbore.4. The system of claim 1 , further comprising:an interpretation module to interpret the formation characteristics using the reflected acoustic signal received by the acoustic sensor; andan optical fiber ...

DEDICATED SUB FOR LOOK-AHEAD APPLICATIONS

A drilling system and a method of drilling a wellbore in an earth formation. A first antenna is disposed at a first location near a drill string. A second antenna is disposed at a second location of the drill string. The first antenna has a first specific moment. One of the first antenna and the second antenna is operated as a transmitter that transmits a transmitted signal, and the other is operated as a receiver that receives a received signal in response to the transmitted signal. The processor determines a property of an earth formation from the received signal. 1. A method of drilling a wellbore through an earth formation , comprising:disposing a first antenna at a first location of a drill string;disposing a second antenna at a second location of the drill string, wherein the first antenna has a first specific moment smaller than a second specific moment of the second antenna;operating one of the first antenna and the second antenna as a transmitter to transmit a transmitted signal; andoperating the other of the first antenna and the second antenna as a receiver to receive a received signal in response to the transmitted signal;determining a property of the earth formation from the received signal.2. The method of claim 1 , wherein at least one of the first specific moment and the second specific moment is specific magnetic moment.3. The method of claim 1 , wherein at least one of the first specific moment and the second specific moment is a specific electric moment.4. The method of claim 1 , wherein the drill string further comprises a drill bit and the distance of the first antenna to the drill bit is smaller than the distance of the second antenna to the drill bit.5. The method of claim 4 , wherein the first specific moment is one of: (i) half of the second specific moment; (ii) less than half of the second specific moment; (iii) less than 1/10of the second specific moment; (iv) less than 1/100of the second specific moment; and (v) less than 1/1000of the ...

Communication Using a Spacer Fluid

Disclosed are systems and methods for transmitting commands from a surface to downhole electronic equipment using pills of a spacer fluid. One method of communicating down a wellbore may include providing a flow of a first fluid along a flow path, introducing a series of one or more pills of a second fluid into the flow of the first fluid at a first point along the flow path, and detecting the series of one or more pills of the second fluid at a second point along the flow path, the second point being separated from the first point. In certain embodiments, a series of brine pills may be introduced into a flow of a drilling fluid.

DOWNHOLE TENSION SENSING APPARATUS

Apparatus and method of sensing tension downhole, such as a measurement tool for coupling between opposing first and second portions of a tool string conveyable within a wellbore. The measurement tool may include a tension-bearing member, a load cell connected along the tension-bearing member and operable to generate information indicative of tension applied to the measurement tool, and electronic equipment communicatively connected with the load cell. The electronic equipment may be operable to record the information generated by the load cell and/or transmit the information generated by the load cell to a wellsite surface from which the wellbore extends. 130-. (canceled)31. An apparatus comprising: a sensor operable to generate information;', record the information; and/or', 'transmit the information to surface equipment located at a wellsite surface from which the wellbore extends;, 'electronic components electrically connected with the sensor and operable to, permit passage to the perforating tool of electrical power having a first polarity transmitted from the surface equipment to electrically power the perforating tool; and', 'prevent passage to the perforating tool of electrical power having a second polarity opposite of the first polarity transmitted from the surface equipment; and, 'a first rectifier operable to, permit passage to the electronic components of the electrical power having the second polarity transmitted from the surface equipment to electrically power the electronic components; and', 'prevent passage to the electronic components of electrical power having the first polarity transmitted from the surface equipment., 'a second rectifier operable to], 'a measurement tool for coupling between first and second portions of a tool string conveyable within a wellbore that extends into a subterranean formation, wherein the second tool string portion comprises a perforating tool, and wherein the measurement tool comprises32. The apparatus of wherein the ...

Detecting Downhole Sand Ingress Locations

A method of detecting sand inflow into a wellbore is disclosed. The method can include obtaining a sample data set, detecting a broadband signal within the sample data set, comparing the broadband signal with a signal reference, determining that the broadband signal meets or exceeds the signal reference, and determining the presence of sand inflow into the wellbore based on determining that the broadband signal meets or exceeds the signal reference. The sample data set can be a sample of an acoustic signal originating within a wellbore comprising a fluid, and the broadband signal at least includes a portion of the sample data set at frequencies above 0.5 kHz.

Downhole fiber optic wet mate connections

A wet mate connection can include two connector assemblies, each connector assembly including at least one connector and a protective barrier displaceable between closed and open positions, and one connector assembly including an engagement device that displaces the protective barrier of the other connector assembly from the closed position to the open position in response to engagement between the connector assemblies. A method of making a connection between lines in a well can include installing a connector assembly, then installing another connector assembly, each connector assembly including a connector and an alignment profile, then axially compressing the connector assemblies, thereby opening protective barriers for the respective connectors, operatively connecting the connectors, and engaging the alignment profiles, thereby maintaining rotational alignment of the connectors. A system for use with a well can include a wet mate optical connection made between packers of the respective connector assemblies.

INDIRECT DETECTION OF BENDING OF A COLLAR

A drilling system includes an internal assembly comprising a chassis, a flow diverter, or both, and a strain gauge coupled to the chassis, the flow diverter, or both, in which the strain gauge is configured to output a signal associated with a strain deformation of the internal assembly. The drilling system also includes a drill collar coupled to the internal assembly, in which the internal assembly extends along the drill collar, and the drill collar encloses the internal assembly of the internal assembly such that a strain deformation of the drill collar causes the strain deformation of the internal assembly. 1. A drilling system , comprising: a chassis; and', 'a strain gauge coupled to the chassis, the strain gauge being configured to output a signal associated with a strain deformation of the internal assembly; and, 'an internal assembly comprisinga drill collar coupled to and enclosing the internal assembly such that a strain deformation of the drill collar causes the strain deformation of the internal assembly.2. The drilling system of claim 1 , the chassis enclosing an instrumentation device of the drilling system.3. The drilling system of claim 2 , the drilling system including a drill bit coupled to the drill collar claim 2 , and the chassis including a flow diverter configured to direct fluid moving through the drilling system and toward the drill bit claim 2 , away from the instrumentation device.4. The drilling system of claim 3 , the flow diverter being a lower flow diverter positioned in a near-bit position or an upper flow diverter positioned near a power generation turbine.5. The drilling system of claim 3 , the instrumentation device including an electronics board within the chassis claim 3 , the electronics board is being coupled to the strain gauge configured to receive the signal from the strain gauge indicative of the strain deformation of the internal assembly.6. The drilling system of claim 5 , the electronics board being configured to operate ...

WELLBORE DISTRIBUTED SENSING USING FIBER OPTIC ROTARY JOINT

A system includes an optical fiber integrated into a conveyance subsystem that is positionable downhole in a wellbore. The system also includes a backscattering sensor system positionable to monitor temperature and optical fiber strain along the optical fiber using backscattered light signals received from the optical fiber. Further, the system includes a fiber optic rotary joint positionable to optically couple the optical fiber with the backscattering sensor system to provide an optical path for the backscattered light signals to reach the backscattering sensor system. 1. A system , comprising:an optical fiber integrated into a conveyance subsystem that is positionable downhole in a wellbore;a backscattering sensor system positionable to monitor temperature and optical fiber strain along the optical fiber using backscattered light signals received from the optical fiber; anda fiber optic rotary joint positionable to optically couple the optical fiber with the backscattering sensor system to provide an optical path for the backscattered light signals to reach the backscattering sensor system.2. The system of claim 1 , further comprising a reel positionable to store at least a portion of the conveyance subsystem during deployment of the conveyance subsystem downhole within the wellbore.3. The system of claim 1 , wherein the backscattering sensor system is positionable to monitor the temperature and the optical fiber strain along the optical fiber while the conveyance subsystem is deployed into or removed from the wellbore.4. The system of claim 1 , further comprising:a downhole tool attached to a downhole end of the conveyance subsystem, wherein the backscattering sensor system is positionable to monitor the temperature and the optical fiber strain along the optical fiber during operation of the downhole tool.5. The system of claim 4 , wherein the downhole tool comprises a wireline logging tool claim 4 , a perforating tool claim 4 , a wellbore completion tool claim ...

SUBSURFACE MEASUREMENT COMPRESSION AND RECONSTRUCTION

An apparatus includes a subsurface sensor in a borehole to provide a measurement series, a first processor, and a machine-readable medium having program code. The program code causes the apparatus to obtain the measurement series and generate a combination of functions based on the measurement series, wherein the combination of functions includes a subset of functions from a basis function library. The system also generate a set of values and communicates the set of values to a second processor, wherein the set of values includes a function identifier and corresponding function weight. The second processor is to generate a set of reconstructed measurement series based on the set of values and determine at least one of a formation property, a fluid property, and a well status based on the set of reconstructed measurement series. 1. An apparatus comprising:a subsurface sensor for use in a borehole to provide a measurement series;a first processor to receive the measurement series; and obtain the measurement series,', 'generate a combination of functions based on the measurement series using the first processor, wherein the combination of functions comprises a subset of functions from a library of basis functions,', 'generate a set of values, wherein the set of values comprises a function identifier and corresponding function weight for at least one function from the combination of functions,', 'communicate the set of values to a second processor at a different location from the first processor, the second processor to generate a set of reconstructed measurement series based on the set of values and determine at least one of a formation property, a fluid property, and a well status based on the set of reconstructed measurement series., 'a machine-readable medium having program code to cause the apparatus to,'}2. The apparatus of claim 1 , wherein the program code to communicate the set of values to the second processor comprises program code to:determine whether the ...

TRANSLATABLE EAT SENSING MODULES AND ASSOCIATED MEASUREMENT METHODS

A system of translatable electro acoustic technology (EAT) modules for deployment along an oil or gas wellbore casing comprises: a wireline/slickline optical distributed acoustic sensing (DAS) cable deployed from the surface into the casing and connected to a surface interrogator; a tractor attached to the downhole end of the wireline/slickline optical distributed acoustic sensing (DAS) cable; and one or more EAT sensing modules that can be coupled to or decoupled from the wireline/slickline optical distributed acoustic sensing (DAS) cable at pre-selected locations and can either be coupled to or decoupled from the casing of the wellbore or be allowed to reposition along the wellborn casing, wherein the one or more EAT sensing modules can conduct multiple measurements and communicate the results via the wireline/slickline optical distributed acoustic sensing (DAS) cable to the surface interrogator. 1. A system of translatable electro acoustic technology (EAT) modules for deployment along an oil or gas wellbore casing comprising:a. a wireline/slickline optical distributed acoustic sensing (DAS) cable deployed from the surface into the casing and connected to a surface interrogator;b. a tractor attached to the downhole end of the wireline/slickline optical distributed acoustic sensing (DAS) cable;c. one or more EAT sensing modules that can be coupled to or decoupled from the wireline/slickline optical distributed acoustic sensing (DAS) cable at pre-selected locations and can either be coupled to or decoupled from the casing of the wellbore or be allowed to reposition along the wellbore casing; andd. wherein the one or more EAT sensing modules can conduct multiple measurements and communicate the results via the wireline/slickline optical distributed acoustic sensing (DAS) cable to the surface interrogator system.2. The system of translatable electro acoustic technology (EAT) modules for deployment along an oil or gas wellbore casing of wherein one or more of the EAT ...

BACKWARD WHIRLING REDUCTION

Backward whirling reduction is provided. In one possible implementation a system for reducing backward whirling includes a drill, a bottom hole assembly associated with the drill, and at least one backward whirling disruptor associated with the bottom hole assembly. In another possible implementation, information from a computer simulation associated with a behavior of the bottom hole assembly during a simulated drilling operation is accessed. Then a first section of the bottom hole assembly exhibiting backward whirling during the simulated drilling operation is identified and the bottom hole assembly is modified to include one or more backward whirling disruptors to at least reduce the backward whirling during the simulated drilling operation. 1. A system for reducing backward whirling , the system comprising:a drill;a bottom hole assembly associated with the drill; andat least one backward whirling disruptor associated with the bottom hole assembly.2. The system of claim 1 , wherein the at least one backward whirling disruptor includes one or more of:at least one eccentricity associated with at least one portion of the bottom hole assembly disrupting a symmetry of the at least one portion of the bottom hole assembly;at least one mass imbalance associated with at least one portion of the bottom hole assembly; andtwo or more stabilizers of different outside diameters located at different positions on the bottom hole assembly.3. The system of claim 2 , wherein the at least one eccentricity includes at least one portion of the bottom hole assembly where a thickness of a wall of the bottom hole assembly is non uniform about a centerline of the bottom hole assembly.4. The system of claim 2 , wherein the at least one eccentricity includes at least one portion of the bottom hole assembly where equipment on the bottom hole assembly has a centerline nonconcentric with a centerline of the bottom hole assembly.5. The system of claim 4 , wherein the equipment includes one or ...

SENSING MAGNETIZED PORTIONS OF A WELLHEAD SYSTEM TO MONITOR FATIGUE LOADING

A wellhead assembly having a tubular magnetized in at least one selected location, and a sensor proximate the magnetized location that monitors a magnetic field from the magnetized location. The magnetic field changes in response to changes in mechanical stress of the magnetized location, so that signals from the sensor represent loads applied to the tubular. Analyzing the signals over time provides fatigue loading data useful for estimating structural integrity of the tubular and its fatigue life. Example tubulars include a low pressure housing, a high pressure housing, conductor pipes respectively coupled with the housings, a string of tubing, a string of casing, housing and tubing connections, housing and tubing seals, tubing hangers, tubing risers, and other underwater structural components that require fatigue monitoring, or can be monitored for fatigue. 1. A method of monitoring a wellhead component comprising:a. sensing a magnetic field that intersects a portion of a tubular that is in the wellbore and that forms part of a wellhead assembly;b. identifying variations in the magnetic field that are from loads applied to the tubular; andc. estimating fatigue loading on the tubular based on the applied loads.2. The method of claim 1 , wherein a selected portion of the tubular is magnetized.3. The method of claim 2 , wherein the magnetized portion of the tubular resembles an oval shape.4. The method of claim 3 , wherein the oval shape with an elongate side oriented in a direction selected from the group consisting of parallel with an axis of the wellbore claim 3 , oblique with an axis of the wellbore claim 3 , and perpendicular with an axis of the wellbore.5. The method of claim 1 , wherein the step of sensing comprises providing a sensor in the magnetic field and monitoring an output of the sensor.6. The method of claim 5 , wherein the sensor is part of a sensor system that comprises a plurality of sensors connected by a sensing line claim 5 , and wherein the ...

Apparatus and method for drill pipe transmission line connections

An apparatus for communicating a signal downhole includes a drill pipe configured to be rotated to drill the borehole and a tube under axial tension and secured in the drill pipe, wherein the axial tension occurs at least with the drill pipe not under axial tension. The apparatus further includes a connector sleeve sealed to an end of the tube and configured to secure the tube under the axial tension to the drill pipe and to provide a sealing surface for a connector to seal to. The apparatus further includes a transmission line configured to communicate the signal. The transmission line is disposed in the tube and has a length greater than the length of the tube and extending past the connector sleeve.