КОРРЕКЦИЯ ГЛУБИНЫ

Изобретение относится к способу определения глубины расположения спущенного в скважину на кабеле оборудования. Техническим результатом является коррекция глубины, измеренной по кабелю на поверхности, для получения истинной глубины устройства. Способ включает определение длины кабеля, спущенного в скважину, на поверхности, деление кабеля в скважине на серию элементов. Причем каждый элемент в серии задают как часть кабеля, для которого натяжение рассматривается как эффективно постоянная величина. Затем определяют натяжение в каждом элементе кабеля в скважине, растяжение кабеля в скважине для определенного натяжения во всех элементах и определяют глубину оборудования по длине кабеля, спущенного в скважину с поверхности, и определенному растяжению кабеля в скважине. 8 з.п. ф-лы, 1 табл., 4 ил.

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

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

Способ разработки залежи сверхвязкой нефти

Изобретение относится к нефтедобывающей промышленности, в частности, к разработке залежей высоковязкой нефти или битумов с нефтенасыщенной толщиной менее 10 м. Технический результат - увеличение охвата разработкой залежи, повышение нефтеотдачи продуктивного пласта. В способе разработки залежи сверхвязкой нефти 1, включающем бурение вертикальной скважины 2, исследование фильтрационно-емкостных свойств вскрытых бурением пластов, выделение битумонасыщенных и водонасыщенных пропластков, после выделения водонасыщенных и нефтенасыщенных пропластков определяют уровень водонефтяного контакта ВНК 3. После этого в вертикальную скважину 2 спускают колонну труб 4 до глубины на 10 м ниже ВНК 3 и производят ее цементирование с образованием искусственного забоя. Далее производят установку нижнего клина-отклонителя в направлении бурения нижних боковых стволов 5, 5', вырезают окно. Производят бурение от 2 до 4 нижних боковых горизонтальных стволов 5, 5' длиной 50-100 м, причем таким образом, чтобы нижние ...

ПРЕОБРАЗОВАНИЕ ОЦЕНОК ЗАПАСОВ В МОДЕЛИ ПЛАСТА В СТАНДАРТНЫЙ ФОРМАТ ДЛЯ ДИНАМИЧЕСКОГО СРАВНЕНИЯ

Изобретение относится к системе и способу преобразования оценок запасов в модели пласта в стандартный формат. Техническим результатом является повышение точности определения геологического объема. Способ включает преобразование в последовательную форму оценок запасов, замкнутой триангулированной решетки и сетки мощности пласта, каждое из которых отражает модель пласта, в байтовый массив с помощью компьютерного процессора, сжатие байтового массива и преобразование сжатого байтового массива в печатную строку. 3 н. и 17 з.п. ф-лы, 10 ил.

УСТРОЙСТВО И СПОСОБЫ ВЫПОЛНЕНИЯ ОПЕРАЦИЙ В СТВОЛЕ СКВАЖИНЫ С ИСПОЛЬЗОВАНИЕМ СКВАЖИННЫХ ИНСТРУМЕНТОВ С ПЕРЕМЕЩАЮЩИМИСЯ СЕКЦИЯМИ

... 1. Способ выполнения операций отбора проб и отбора кернов, согласно которому ! спускают скважинный инструмент на каротажном кабеле в ствол скважины, проходящий в подземный пласт; ! закрепляют скважинный инструмент в стволе скважины, выдвигая фиксирующую опору из скважинного инструмента в контакт со стенкой ствола скважины на первом месте работ в стволе скважины; ! выполняют операцию отбора проб или образцов пластовой текучей среды с использованием инструмента отбора проб, связанного с первой секцией, при этом операцию отбора проб или образцов выполняют на втором месте работ в стволе скважины, когда скважинный инструмент остается закрепленным в стволе скважины на первом месте работ, и при этом второе место работ разнесено с первым местом работ в направлении, параллельном продольной оси скважинного инструмента; и ! перемещают первую секцию скважинного инструмента и вторую секцию скважинного инструмента так, что первая секция скважинного инструмента переводится от второго места работ в направлении ...

АВТОНОМНЫЙ КОНТРОЛЬ ГЛУБИНЫ ДЛЯ СКВАЖИННОГО ОБОРУДОВАНИЯ

... 1. Способ слежения за местоположением инструмента в буровой скважине, включающий этапы: ! (а) получения первого изображения скважины, используя устройство формирования изображения, связанное с инструментом; ! (b) получения второго изображения скважины, используя устройство формирования изображения по истечении выбранного периода времени; ! (c) согласования первого изображения со вторым изображением путем смещения одного из первого и второго изображений; ! (d) определения величины смещения; и ! (e) сравнения величины смещения с опорным расстоянием для определения расстояния перемещения инструмента. ! 2. Способ по п.1, в котором опорным расстоянием является опорная длина в устройстве формирования изображения. ! 3. Способ по п.1, повторяющий этапы (a)-(e). ! 4. Способ по п.3, включающий также выполнение скважинной операции, когда расстояние перемещения инструмента соответствует выбранному критерию. ! 5. Способ по п.4, в котором выполнение скважинной операции запускается автоматически без вмешательства ...

СПОСОБ КОНТРОЛЯ ГЛУБИНЫ СПУСКА БУРИЛЬНОЙ КОЛОННЫ

Изобретение относится к нефтегазовой промышленности, точнее к способу контроля глубины спуска бурильной колонны. Предложенный способ включает определение разности измеренных значений высотных отметок между первым положением датчика и вторым положением датчика на основании данных измерений, выполненных при помощи устройства измерения высотных отметок, определение разности калибровочных значений высотных отметок между указанными первым и вторым положениями на основании данных измерений, выполненных датчиком с использованием маркеров, размещенных на заданных высотных отметках, и калибровку устройства измерения высотных отметок на основании по меньшей мере частично соотношения между разностью измеренных значений высотных отметок и разностью калибровочных значений высотных отметок. Технический результат заключается в повышении эффективности способа контроля глубины спуска бурильной колонны. 3 н. и 19 з.п. ф-лы, 16 ил.

Механический каверномер с ручным приводом для взрывных скважин

Изобретение относится к области средств для измерения диаметров и глубины взрывных скважин при взрывном рыхлении крепких горных пород. Техническим результатом является снижение трудоемкости и повышение производительности при подъеме-опускании и удержании каверномера на заданной глубине скважины, обеспечение возможности осуществления общего измерения глубины скважины и точной величины изменения диаметра скважины при изменениях диаметра как в меньшую, так и в большую сторону, упрощение конструкции и снижение массы опускаемого в скважину каверномера. Механический каверномер с ручным приводом для взрывных скважин, состоящий из стержня, подвешенного на метрической металлической ленте для замера глубины скважины, на нижнем конце стержня закреплены проушины, в которых шарнирно установлены два мерных рычага, шарнирно соединенные тягами с подвижной втулкой, свободно насаженной на стержень, а на втулке закреплен конец метрической металлической ленты для замера диаметра скважины. При этом каверномер ...

ВНУТРИСКВАЖИННЫЙ КОНТРОЛЬ УРОВНЯ ЖИДКОСТИ В СКВАЖИНАХ ПО ДОБЫЧЕ УГЛЕВОДОРОДОВ

... 1. Устройство для контроля уровня жидкости в стволе скважины по добыче углеводородов путем мониторинга уровня жидкости внутри скважины, содержащее: ! (a) внутрискважинный измеритель уровня жидкости и ! (b) сигнальное устройство, соединенное с измерителем уровня жидкости и выполненное с возможностью воздействовать на насос для регулирования текущего выпуска им жидкости на основе уровня жидкости, в стволе скважины, измеренного указанным измерителем уровня жидкости. ! 2. Устройство по п.1, в котором мониторинг уровня жидкости внутри ствола скважины осуществляется физически. ! 3. Устройство по п.1, в котором измеритель уровня жидкости содержит: ! (a) опорную конструкцию и ! (b) поплавок, соединенный с опорной конструкцией, так что он имеет возможность перемещаться вертикально вверх и вниз вдоль опорной конструкции, а его положение определяется уровнем жидкости внутри скважины. ! 4. Устройство по п.3, в котором сигнальное устройство содержит: ! (a) верхнее целевое устройство, соединенное с поплавком ...

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

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

УСТРОЙСТВО ДЛЯ ИЗМЕРЕНИЯ ГЛУБИНЫ СКВАЖИНЫ И СКОРОСТИ БУРЕНИЯ БУРОВОГО СТАНКА

Полезная модель относится к горной промышленности, а именно к станкам шарошечного бурения, и используется для контроля параметров в процессе бурения. Технической задачей является создание более совершенной и универсальной конструкции устройства, которое обеспечивает повышение точности измерения глубины скважины и точности измерения скорости бурения, долговечность и надежность от проскальзывания заявляемого устройства. Технический результат достигается тем, что устройство для измерения глубины скважины и скорости бурения бурового станка размещено в мачте на верхней опоре блока механизма подачи с обводным колесом для тягового элемента, содержащее жестко закрепленное на обводном колесе приводное колесо, связанное с возможностью передачи измерения с энкодером, приводное колесо находится в зацеплении с мерным колесом, снабженным выходным валом, соединенным через упругую муфту с валом энкодера. Приводное и мерное колесо выполнены в виде зубчатых колес. Наряду с вышеперечисленным в полной мере ...

Verfahren und Vorrichtung zum Anzeigen der sich aendernden Laenge eines belasteten, durch eine Laengenmessvorrichtung hindurchlaufenden Kabels

Methods and apparatus for determination of parameters related to a coiled tubing string

System and method for stick-slip correction

A method of processing downhole measurement data includes: receiving formation measurement data generated by a downhole tool during a logging-while drilling operation over a selected time period; receiving a measured depth corresponding to the selected time period based on data taken at a surface location; receiving tool rotation data generated by measurements of a rotational rate of the downhole tool taken by a downhole sensor during the selected time period; calculating a new depth of the tool as a function of time over the selected time period based on a relationship between the tool rotation data and the measured depth; and correcting an original depth of the measurement data with the new depth.

Data logging

Methods of locating mutiple wellbores

Depth determination

Well monitoring

Tubular assembly and method of deploying a downhole device using a tubular assembly

Determining a depth correction for a logging tool in a well

A method of determining a depth correction for a logging tool 1 that is moved, while suspended from a cable 11, along a well 2, the method being of the type in which a measurement of tool depth is performed at the surface at successive instants (by counting pulses associated with winding of the cable), the tool comprising at least two sensors suitable for measuring a characteristic of the well at each of said instants said two sensors being offset longitudinally in the displacement direction of the tool. The method comprises, at each of said instants: determining a first value for tool velocity by intrinsic measurement, e.g. derived from the output of an accelerometer 17; determining a second value of the velocity by correlation between information received from said two sensors; and combining the first and second velocity values to determine a depth correction to be applied to said surface depth measurement. ...

Data compression using two-dimensional transformations

A method is disclosed for compressing a frame of data representing parameter values, a time at which each parameter value was recorded, and an orientation (azimuth) of a sensor at the time each parameter value was recorded. Generally the method includes performing a two-dimensional transform on the data in the orientation domain and in a domain related to the recording time. In one embodiment, the method includes calculating a logarithm of each parameter value. In one embodiment, the 2-D transform includes generating a Fourier transform of the logarithm of the parameter values in the azimuthal domain, generating a discrete cosine transform of the transform coefficients in the time domain. This embodiment includes quantizing the coefficients of the Fourier transform and the discrete cosine transform. One embodiment of the method is adapted to transmit resistivity measurements made by an LWD instrument in pressure modulation telemetry so that while-drilling images of a wellbore can be generated ...

Bed boundary detection and invasion profiling with uncompensated electromagnetic wave resistivity sensors

A resistivity tool (800) associated method includes measuring the phase shift of an electromagnetic signal at different locations. Preferably, this is accomplished by a resistivity tool (800) having three receivers (R1, R2, R3). The difference of the phase shifts at the different locations indicates with precision the depth in a borehole of a bed boundary. The preferred resistivity tool also yields improved radial resolution.

Determining the depth of equipment suspended on a stretched cable

A method of determining the depth of equipment in an underground borehole, the equipment being suspended in the borehole by means of a cable extending from the surface into the well, comprises: determining the amount of cable introduced into the well at the surface; dividing the cable in the borehole into a series of elements; determining the tension in each element of the cable in the borehole; determining the stretch of the cable in the borehole for the determined tension in all elements; and determining the depth of the equipment from the determined amount of cable introduced into the well from the surface and from the determined stretch of the cable in the borehole. The method can be used for correcting a depth measurement or determining an error in a depth measurement made on the cable at the surface by determining a correction factor using the methodology described above. The correction or error determination can be applied directly to log data as well as to the depth measurement.

Using sensors to determine the correct depth for lateral drilling

A method of determining a desirable depth for drilling a horizontal well within an oil reservoir includes the steps of deploying data sensors (120, 124, 128) at discrete depths in a subsurface formation penetrated by a wellbore (104); gathering formation pressure data for the discrete depths and determining the depth of a reservoir from the gathered data. Once the correct depth has been identified, the wellbore, or a lateral bore depending from the wellbore, can be steered into the reservoir. The sensors (124) are deployed in the formation from a drill collar (132) on a drill string (103) by a piston (328) that is exposed to hydraulic pressure which is communicated to piston chamber (332) from a hydraulic system (334).

Harvesting vibration for downhole power generation

Autonomous depth control for wellbore equipment

Creep determination technique

LINEAR EXTRAPOLATIVE FILTER

Device for determining the position of a moving part and drilling machine including such a device

A device for determining the position of a moving part, particularly to a device containing a sensor carried by the moving part and designed to supply two out-of-phase signals, each assuming alternately the value 0 or 1 as the sensor is carried in one or the other direction. The device also has means of supplying pulses (ZD), each of which corresponds to one step forward on the part of the sensor, when the sensor moves in one direction, means of supplying other pulses (ZC), each of which corresponds to said step forward, when the sensor moves in the other direction, an up-down counting unit, means of transmitting the second pulses to an upcounting input belonging to the up-down counting unit, means of transmitting the first pulses to a downcounting input belonging to the up-down counting unit when the unit is not at zero and of blocking the downcounting input to said first pulses when the up-down counting unit is at zero, and means of transmitting said first pulses to a consuming device ...

DEVICE FOR DETERMINING THE POSITION OF A MOVING PART AND DRILLING MACHINE INCLUDING SUCH A DEVICE

Power generation downhole by use of vibration

To operate downhole devices power is generated by the conversion of vibrational energy to electrical energy. Various methods of achieving this are disclosed but one involves the relative movement between a winding / coil 602 and a magnetic material 610. A flow diverter (fig 3-11) may be used to alter fluid flow and create turbulence thereby increasing vibration. Another embodiment involves dispersing wireless tags (19A, 19B) in the well to measure well properties and using vibrational energy transferred to the tags to activate them.

Method for logging earth formations

Downhole measurement while drilling system and method

A method of measuring while drilling includes positioning at least one sensor downhole; and transmitting sensed data while drilling from the at least one sensor to surface without storing the sensed data downhole and system.

Downhole tool for measuring accelerations

A downhole tool 130 for measuring accelerations at a location within a borehole 11 with an accelerometer 2 (fig 2), the tool being rotatable and comprising a plurality of accelerometers 2 configured to measure acceleration in a respective direction and arranged so at least a component of the measured acceleration is normal to the longitudinal direction, a first device 3/34 (fig 2) which measures rotational speed of the tool and a processor unit 370 which relates the acceleration measured by each accelerometer to the true acceleration to the true acceleration at that accelerometer by a respective scaling term and a respective offset and combines the measured accelerations and the tool rotational speed to re-calibrate the scaling terms as the tool rotates. The tool may further include a gyroscope 3 (fig 2) to measure the tool rotational speed, and my include magnetometer 4 (fig 2) to measure the earths magnetic field. The tool may further comprise a processor unit which filters the measured ...

Sensor arrangement

A sensor arrangement for use in a wellbore, comprising a sensor housing 28, a first sensor 30 and a second sensor 32, that are both sensitive to the same downhole parameter, are housed in the housing 28 and are spaced apart by a fixed distance in the axial direction of the housing 28, and a control unit 38, to monitor the outputs of the first 30 and second 32 sensors to ascertain information relating to position and movement. The downhole parameter may comprise temperature information. Both sensors may be thermoelectric generators or thermal cameras operable. Each sensor may comprise a plurality of individual sensors. The pair of sensors may together form a panoramic infrared camera and the control unit 38 may undertake image processing techniques to track thermal features of images taken by the panoramic cameras. Distance information may be used to determine axial velocity or rate of penetration (ROP) of the housing and sensor measurement outputs may confirm completion of procedural survey ...

Rare earth alloys as borehole markers

A magnetic marking method includes drilling a borehole and marking a position along an uncased section of the borehole with a magnetic marker comprising a magnetic rare earth alloy. A magnetic marker for open hole use includes an unconsolidated mass of high remanence, magnetized material that comprises a magnetic rare earth alloy. The magnetic marker for open hole use also includes a suspension fluid suited for conveying the magnetized material through a drill string bore into an open borehole. A magnetic marker for a casing terminus includes a magnet comprising a magnetic rare earth alloy and an attachment mechanism that secures the magnet to a casing shoe. Such magnetic markers for open hole use or a casing terminus can be used for borehole intersection operations.

Mining.

In the analysis of rock ahead of a working face a probe is pushed along a borehole formed in any desired direction in the rock and data produced by the probe is logged for later analysis, or for in-situ analysis. The probe may produce multiple logs. The data logged includes lithological information on the rock and the angular direction of the borehole. The presence of fluids, such as noxious gases, in the borehole can simultaneously be detected.

WELL PIPE OBJECT DEPTH INDICATOR

A downhole positioning system

Improvements in or relating to aided inertial navigation systems

Position tracking for proppant conveying strings

Locating multiple wellbores

Depth and speed correction of logging data

Downhole interventionless depth correlation

Active magnetic ranging while drilling

A magnetic ranging system for use with a drilling assembly in a borehole in a formation, the drilling assembly including a drill string, a drill bit and a bottomhole assembly (BHA) connected to the drill bit, the BHA including a measurement-while-drilling (MWD) system, a bi-directional MWD telemetry interface, and a steerable component, may comprise at least one ranging magnetometer incorporated into the BHA. The ranging magnetometer may be configured to collect ranging measurements from behind the drill bit and the ranging magnetometer may be configured to transmit measurement data. The magnetic ranging system may include at least two ranging magnetometers, with one ranging magnetometer positioned above the MWD system and one ranging magnetometer positioned below the MWD system.

Determination of representative elemental length based on subsurface formation data

A method and system for forming Representative Elemental Length (REL) of well data. The method may comprise inputting log data from a borehole in a formation into an information handling system, identifying an initial length of the REL section and divide the log data into a plurality of REL investigation sections that are of substantially equal length, calculating an average value of a formation property for each of the plurality of REL investigation sections, and selecting a maximum value and a minimum value of the REL investigation sections. The method may further comprise checking the maximum value and the minimum value are stable, deriving the formation property for each of the REL sections as an output, and forming a model of the formation from each of the REL sections. The system may comprise a downhole device, configured to take measurements of a formation, and an information handling system.

High definition drilling rate of penetration for marine drilling

High definition drilling rate of penetration for marine drilling

Method and apparatus for measuring the depht of a tool in a borehole.

Device of measurement of the displacement of a circulating head of a chechmate of drilling

Method and system for performing operations and for improving production in wells.

Process and device to measure the depth of a tool descended in a drilling by means of a cable.

ARRANGEMENT FOR SEIZING THE LAENGSVERSCHIEBUNG OF A CABLE

AUTONOMOUS BOREHOLE NAVIGATION DEVICE

SURGICAL CARTRIDGE WITH A STRUCTURE FOR THE BLOW-OUT OF BLISTERS

ANORDNUNG ZUM ERFASSEN DER LAENGSVERSCHIEBUNG EINES KABELS

Monitoring, auditing and/or determining depth of or in a borehole

A system and method for determining a depth in a drill hole associated with a drilling operation include means and steps for: determining a value for at least one constant parameter and/or a value for at least one variable parameter of a drill rig and/or the drill hole of the associated drilling operation, and calculating the depth in the drill hole from the at least one value constant parameter and/or variable parameter. The constant parameter(s) and/or the variable parameter(s) can be recorded relating to a specific drill rig and/or drill hole. The constant parameter(s) can include one or more of chosen constant stick up distance and/or of a bottom hole assembly length. The variable parameter(s) can include one or more of rod length, rod added or removed out of each run, and/or rod stick up. Entered or recorded data can be progressively tracked and a time record for one or more events generated relating to the drilling operation. The system and method can be implemented in a device having ...

Depth correlation device for fiber optic line

A correlation system is provided to allow association of readings from a cable (30) that is supported by a string (12) but that is coiled around or has slack in one or many locations to a specific location along the string itself. Heat sources (14) can be placed along the string to periodically or continuously give off heat that can be detected by a cable such as a fiber optic. The location of the sources along the string is known and the location along the cable is determined from the location on the cable where the heat generated by the source is sensed. One or more sources can be used and correlation can be by periodic sampling or in real time. The sources may by powered locally or from the surface.

Surgical cassette with bubble breaking structure

Method and apparatus for determining depth of drill cuttings

System and method for formation detection and evaluation

Provided are a system and method for identifying planned markers while drilling a borehole. In one example, the method includes obtaining a plan containing planned markers that each corresponds to a baseline marker from an existing well. Each of the baseline markers corresponds to a waveform from a log file obtained from the existing well and is associated with a waveform representation of the corresponding waveform. Each of the planned markers is associated with an estimated true vertical depth (TVD) value. A second log file corresponding to the borehole is obtained that contains waveforms representing formation information detected within the borehole. The second log file is scanned for a planned marker based on the estimated TVD value and the waveform representation of the baseline marker corresponding to the planned marker. At least one match may be identified and reported for the planned marker.

Predictive vibration models under riserless condition

Systems and methods provide a mechanism to provide enhanced features for riserless drilling. Various embodiments may include wellbore analysis to predict and quantify vibrations for riserless conditions. Additional apparatus, systems, and methods are disclosed.

Systems and methods for optimizing drilling operations using transient cuttings modeling and real-time data

Systems and methods for optimizing drilling results may be based on, inter alia, (1) real-time data collected during drilling, (2) a transiently modeled cuttings distribution along the wellbore, and optionally (3) a theoretical change to one or more operational parameters. In some instances, methods may include drilling a wellbore penetrating a subterranean formation while circulating a drilling fluid; gathering real-time data about the drilling; calculating a cuttings distribution along the wellbore based on the real-time data using a transient model; calculating an equivalent circulating density profile along the wellbore based on (1) real-time data collected during drilling, (2) a transiently modeled cuttings distribution along the wellbore, and optionally (3) a theoretical change; and changing at least one operational parameter based on a comparison of the equivalent circulating density profile to a fracture gradient of the subterranean formation.

Subsea dummy run elimination assembly and related method

A system and method to determine and adjust positioning of a subsea test tree ("SSTT") within a blowout preventer ("BOP"), the system including an SSTT, at least one sensing mechanisms to detect the position of one or more BOP rams and a fluted hanger. Once the assembly is deployed, the ram positions are detected and the position of the fluted hanger is adjusted while deployed to accordingly adjust the spacing between the SSTT and the fluted hanger, thereby eliminating the need of a dummy run. Another system and method improves a dummy run by providing a lightweight joint and dummy hanger deployed on a line (e.g., wireline, slickline, etc.). Through the use of a line and the lightweight of the joint and dummy hanger, the dummy run operation is conducted quickly and efficiently.

Apparatus and method for depth referencing downhole tubular strings

APPARATUS AND METHOD FOR DEPTH REFERENCING DOWNHOLE TUBULAR STRINGS An apparatus (100) for depth referencing tubular strings in a wellbore. The apparatus (100) includes a depth reference coupling (102) having a profile (112) that is positioned in a first tubular string. The first tubular string has a predetermined length between the depth reference coupling (102) and a predetermined reference point. The apparatus (100) also includes an indicator assembly (118) having a mating profile (128) operable to engage the profile (112) of the depth reference coupling (102) that is positioned in a second tubular string. In operation, the second tubular string is run in the first tubular string until the mating profile (128) of the indicator assembly (118) engages the profile (112) of the depth reference coupling (102), thereby enabling reliable depth referencing of the tubular strings.

Apparatus and method for depth referencing downhole tubular strings

APPARATUS AND METHOD FOR DEPTH REFERENCING DOWNHOLE TUBULAR STRINGS An apparatus (100) for depth referencing tubular strings in a wellbore. The apparatus (100) includes a depth reference coupling (102) having a profile (112) that is positioned in a first tubular string. The first tubular string has a predetermined length between the depth reference coupling (102) and a predetermined reference point. The apparatus (100) also includes an indicator assembly (118) having a mating profile (128) operable to engage the profile (112) of the depth reference coupling (102) that is positioned in a second tubular string. In operation, the second tubular string is run in the first tubular string until the mating profile (128) of the indicator assembly (118) engages the profile (112) of the depth reference coupling (102), thereby enabling reliable depth referencing of the tubular strings.

Determining and displaying reserve estimates for a reservoir

Systems and methods for determining and displaying reserve estimates for a reservoir by generating a table and, optionally, a report and/or a graph for the reserve estimates and predefined identification properties that uniquely describe the reserve estimates.

A perforating gun

A well tool (60) includes a perforating gun (108), a sealing element (130), at least one pressure sensor (150), a detector (132), a controller (152), and an anchor (134). The perforating gun (108) perforates the wellbore tubular in response to a firing signal. The sealing element (130) is connected to the perforating gun (108) and generates a pressure differential thereacross. The at least one pressure sensor (150) is associated with the sealing element (130) and detects a surface transmitted pressure signal. The detector (132) detects at least one marker (70) positioned along the wellbore (12) and which includes a perforating marker (70) associated with a perforating depth. The controller (152) is in signal communication with the at least one pressure sensor (150) and the detector (132) and is configured to transmit the firing signal to the perforating gun (108) only after: (i) the at least one pressure sensor (150) detects the surface transmitted pressure signal, and (ii) the detector ...

Equi-pressure geosteering

Method and system for performing operations and for improving production in wells

APPARATUS FOR CARRYING OUT SUBSEA WIRELINE OPERATIONS

Methods and computer executable instructions for marking a downhole elongate line and detecting same

Arrangement for measuring the position of a feed beam in a rock drilling apparatus and/or measuring the position of a rock drill

APPARATUS AND METHOD FOR DOWNHOLE WELL EQUIPMENT AND PROCESS MANAGEMENT,IDENTIFICATION, AND ACTUATION

A method for actuating or installing downhole equipment in a wellbore using non-acoustic signals (e.g. radio frequency signals) to locate, inventory, install, or actuate one downhole structure in relation to another downhole structure is shown in Figure 3. The method comprises the steps of: (a) providing a first downhole structure (12) that comprises a non-acoustic (e.g., radio frequency) identification transmitter unit (28) that stores an identification code and transmits a signal corresponding to the identification code; (b) providing a second downhole structure (32) that comprises a non- acoustic receiver unit (34) that can receive the signal transmitted by the non- acoustic identification transmitter unit, wherein one of the first downhole structure and the second downhole structure is secured at a given location in a subterranean wellbore, and the other is moveable in the wellbore; (c) placing the second downhole structure in close enough proximity to the first downhole structure so ...

METHOD OF AND APPARATUS FOR MINING ANALYSIS

SYSTEM AND METHOD FOR CORRECTING ERRORS IN DEPTH FOR MEASUREMENTS MADE WHILE DRILLING

... ²²²A method and system is disclosed for automatically correcting for depth errors ²in measurements taken from a drillstring during the drilling phase of the ²construction of a hydrocarbon wellbore. The correction is based on a stress ²profile which in turn is based on the states of the drilling rig, drill string ²description length spec, borehole description trajectory, friction factor and ²weight on bit.² ...

METHOD FOR IMPROVING DRILLING DEPTH MEASUREMENTS

A method for determining a depth of a wellbore is disclosed. The method includes determining change in a suspended weight of a drill string from a first time to a second time. A change in axial position of the upper portion of the drill string between the first time and the second time is determined. An expected amount of drill string compression related to the change in suspended weight is corrected for movement of a lower portion of the drill string between the first time and the second time. A position of the lower portion of the drill string is calculated from the change in axial position and the corrected amount of drill string compression. In one embodiment, the correcting includes estimating drill bit movement by determining an axial motion of the drill string at the earth's surface between two times having a same suspended weight of the drill string.

A METHOD AND APPARATUS FOR DETERMINING A GEOPHYSICAL CHARACTERISTIC OF A BOREHOLE

A device and method for determining a geophysical characteristic of a borehole using at least one logging device is provided, wherein the at least one logging device includes at least one sensing device. The method includes associating the at least one sensing device with the borehole, wherein the at least one sensing device includes a sensing device measurement length. The method also includes operating the at least one sensing device to generate borehole data responsive to a borehole portion disposed essentially adjacent the sensing device measurement length, wherein the borehole data includes start time of scan, location of the at least one sensing device at start time of scan, stop time of scan and location of the at least one sensing device at stop time of scan. Furthermore, the method includes correlating the borehole data to determine the geophysical characteristic.

APPARATUS AND METHODS TO PERFORM OPERATIONS IN A WELLBORE USING DOWNHOLE TOOLS HAVING MOVABLE SECTIONS

Apparatus and methods to perform operations in a wellbore using down-hole tools having movable sections are described. In one described example, a downhole tool for use in a wellbore includes a first extendable anchor to contact a wall of the well-bore to fix the tool at a location in the wellbore. The downhole tool also includes a first tool of the downhole tool to perform a first operation at the location in the wellbore, and a second tool of the downhole tool spaced from the first tool and to perform a second operation. Additionally, the downhole tool includes an extendable member to move the second tool to the location while the anchor is in contact with the wall of the wellbore to perform the second operation after the first operation.

METHOD OF AND APPARATUS FOR MINING ANALYSIS

The analysis of rock ahead of a working face in an underground mine. A plurality of boreholes are formed in predetermined directions in rock ahead of a rock face in the mine, at least one of the boreholes being at an angle to the other boreholes. A probe is located in each borehole and is caused to move along the borehole and data obtained from the probe which relates to the rock is logged in a recorder. Logged data may be used for later analysis, or for in-situ analysis. The probe may produce multiple logs. The data logged includes lithological information on the rock and the angular direction of the borehole. The presence of fluids, such as noxious gases, in the borehole can simultaneously be detected.

METHOD OF DETERMINING THE DEPTH OF OCCURRENCE OF A CHEMICALLY REACTIVE BED

The method of determining the depth of occurrence of a chemically reactive bed in the course of drilling a well, as proposed in the present invention resides in the fact that the redox potential of the drilling mud situated in the well, is measured, the walls of the well are stripped of the mud cake, and an additional portion of the drilling mud is prepared, whose redox potential differs, as to value and direction, from that of the drilling mud situated in the well, Then the thus prepared additional drilling mud portion is injected into the well until the drilling mud that has been situated therein previously, is expelled completely, whereupon the circulation of the additional drilling mud portion is suspended for a period of time, wherein relaxation of the ion-exchange processes between the chemically aggressive bed and the additional drilling mud portion occurs. After that the circulation of the additional drilling mud portion resumes, while the time interval between the resumption of ...

DIGITAL CORE WORKFLOW METHOD USING DIGITAL CORE IMAGES

A method for registration and correction of downhole core depth information using digital core images. Digital core images are employed during depth registration, with top and base depths for a selected interval being determined by field data and a digital ruler which calculates an actual interval length based on the digital core image. Correction of the top and base depths is enabled by side- by-side display of the digital core image interval and corresponding well logging data, which displayed information can be manipulated by a user to provide more accurate depth information. The method further allows for shale volume calculations and facies interpretation, again employing the digital core images.

METHOD FOR CORRECTING WELL LOG DATA FOR EFFECTS OF CHANGES IN INSTRUMENT VELOCITY (CABLE YO-YO)

A method for correcting data measured by a well logging instrument (3) for effects of cable (2) yo-yo. The data are first preprocessed to reduce magnitude of spatial frequency components in the data occurring within a bandwidth of axial accelaration of the logging instrument (3) which corresponds to the cable (2). Then eigenvalues of a matrix are shifted, over depth intervals where the smallest absolute value one of the eigenvalues changes sign, by an amount such that the smallest absolute value eigenvalue does not change sign. The matrix forms part of a system of linear equations by which the measurements made by the instrument are converted to values of a property of interest of earth formations. Artifacts which may remain in the data after the step of preprocessing are substantially removed by the eigenvalue shifting.

DEVICE FOR THE DETERMINATION OF A MOBILE COMPONENT'S POSITION, AND DRILLING APPARATUS MAKING USE OF SAID DEVICE

MODEL-BASED PARAMETER ESTIMATION FOR DIRECTIONAL DRILLING IN WELLBORE OPERATIONS

Examples of techniques for model-based parameter and state estimation for directional drilling in a wellbore operation are provided. In one example implementation according to aspects of the present disclosure, a computer-implemented method includes receiving, by a processing device, measurement data from the wellbore operation. The method further includes performing, by the processing device, an online estimation of at least one of a parameter to generate an estimated parameter and a state to generate an estimated state, the online estimation based at least in part on the measurement data. The method further includes generating, by the processing device, a control input to control an aspect in the wellbore operation based at least in part on the at least one of the estimated parameter and the estimated state. The method further includes executing a control action based on the control input to control the aspect of the wellbore operation.

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 ...

BLAST HOLE MEASUREMENT AND LOGGING

Provided is a blast hole measurement and logging apparatus (10) which generally comprises a housing (12) configured to operatively house a solid-state LiDAR sensor array (14) configured to transmit and steer pulses of light (18) into a blast hole (8) by shifting a phase of said pulses through the array to compile volumetric data of said sensor's field-of-view. Also included is a processor (22) configured to receive the volumetric data from the LiDAR sensor (14), said volumetric data indicative of an internal volume of the blast hole (8) which is useable in calculating an explosive charge according to a blast plan, the processor (22) configured to store and/or transmit the volumetric data.

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.

ELECTRONIC SYSTEM FOR MONITORING DRILLING CONDITIONS RELATING TO OIL AND GAS WELLS

HOLE DEPTH SENSING

A method of sensing and transmitting hole depth information comprises monitoring, at the surface, the extension of the hole as drilling progresses, determining when the hole depth has extended by a predetermined distance, and sending an increment signal to a telemetry device.

SYSTEM AND METHOD FOR MEASURING DEPTH AND VELOCITY OF INSTRUMENTATION WITHIN A WELLBORE USING A BENDABLE TOOL

An apparatus and method for measuring depth, velocity, or both depth and velocity of instrumentation within a wellbore is provided. The apparatus includes a downhole portion movable within the wellbore in a direction generally parallel to the wellbor e. The apparatus further includes a first acceleration sensor mounted at a first position within the downhole portion. The first acceleration sensor generates a first signal indicative o f a first acceleration in a first direction generally parallel to the wellbore at the first positio n. The apparatus further includes a second acceleration sensor mounted at a second position within the downhole portion. The second acceleration sensor generates a second signal indicative of a second acceleration in a second direction generally parallel to the wellbore at the second position. The apparatus further includes a bend sensor generating a third signal indicative of an amount of bend of at least a portion of the downhole portion.

SURGICAL CASSETTE WITH BUBBLE BREAKING STRUCTURE

METHOD AND SYSTEM FOR MONITORING THE INCURSION OF PARTICULATE MATERIAL INTO A WELL CASING WITHIN HYDROCARBON BEARING FORMATIONS INCLUDING GAS HYDRATES

A method and system for monitoring any incursion of particulate matter from a gas hydrate formation into a well casing used for the production of the gas hydrate and determining the degree of incursion of particulate material within the distal end of the well casing.

DOWNHOLE DEPTH COMPUTATION METHODS AND RELATED SYSTEM

A method for determining depth in a wellbore uses inertial navigation in conjunction with a database having one or more measured parameters correlate d with depth. The measured parameter may be the lengths of stands (14) formi ng a drill string, prior survey data relating to a naturally occurring featu re such as formation lithology, or data relating to a human made feature suc h as collars in a casing string. The downhole processor (24) may use acceler ometer measurements to calculate a measured depth of a BHA (24) and access t he database to retrieve a predicted depth that corresponds with one or more sensor measurements (e.g., motion indicating the addition of a stand to a dr ill string). Thereafter, if the downhole processor determines that the predi cted depth is in agreement with the calculated depth, the processor stores t he predicted depth and / or associates the predicted depth with directional surveys taken along the wellbore.

HIGH RESOLUTION CONTINUOUS DEPTH POSITIONING IN A WELL BORE USING PERSISTENT CASING PROPERTIES

Continuous measurement indicia between casing collars of a pipe segment of a well bore casing is obtained from signals obtained by sensing innate, persistent and unaltered characteristics, e.g. magnetic permeability, of the pipe segment along its length, and using the signals to perform a downhole function, e.g. a gravity measurement, at an indicated location.

METHOD AND APPARATUS FOR SUBSEA WELL PLUG AND ABANDONMENT OPERATIONS

The invention provides a method and apparatus for performing a plug and abandonment operation on a subsea well. A wellhead interface module (20) is located on a wellhead (13), which accommodates a volume of wellbore fluid in fluid communication with the wellbore. A system control module (80) receives a signal from a sensor (27) in a chamber (23) of said wellhead interface module and is configured to derive volume data relating to a change in volume of wellbore fluid in the chamber and compares the derived volume data with a volume change expected due to the removal of tubing from the wellbore. In embodiments of the invention, this enables a change in wellbore conditions to be characterised, for example a fluid influx or a fluid loss, from the volume data. The method may comprise providing wellbore fluid to the chamber by means of a flow control package (40) to replace fluid which enters the wellbore to occupy the volume vacated by the tubing, and/or removing or adding fluid in fluid influx ...

CONVERTING RESERVE ESTIMATES IN A RESERVOIR MODEL TO A STANDARD FORMAT FOR DYNAMIC COMPARISON

Systems and methods for converting reserve estimates in a reservoir model to a standard format for dynamic comparison by storing them with a sealed triangulated mesh and a thickness grid as a printable string in one or more Processing History fields.

DETERMINING DEPTH OF LOSS ZONES IN SUBTERRANEAN FORMATIONS

Methods of locating a loss zone in a wellbore in a subterranean formation including determining a calculated wellhead pressure, calculating a wellhead pressure differential, calculating a flow rate loss, estimating a loss zone depth, determining a modified calculated wellhead pressure, and calculating a modified wellhead pressure differential until the modified wellhead pressure differential corresponds to a loss zone location in the wellbore.

Датчик уровня

Техническое решение относится к акустическим методам измерения и контроля и предназначено для определения уровня жидкости в скважинах, в том числе нефтедобывающих.Технический результат вышеприведенной задачи достигается за счет создания датчика уровня, состоящего из корпуса, с одного торца которого расположена муфта и преобразователь акустического сигнала в электрический, а с другого - механический клапан для создания зондирующего акустического сигнала, отличающийся тем, что в датчике уровня размещен контроллер с радиоканалом для передачи данных и NFC-метка. РОССИЙСКАЯ ФЕДЕРАЦИЯ (19) RU (11) (13) 193 245 U1 (51) МПК E21B 47/04 (2012.01) G01F 23/00 (2006.01) ФЕДЕРАЛЬНАЯ СЛУЖБА ПО ИНТЕЛЛЕКТУАЛЬНОЙ СОБСТВЕННОСТИ (12) ОПИСАНИЕ ПОЛЕЗНОЙ МОДЕЛИ К ПАТЕНТУ (52) СПК E21B 47/04 (2019.05); G01F 23/00 (2019.05) (21)(22) Заявка: 2019106194, 04.03.2019 (24) Дата начала отсчета срока действия патента: (73) Патентообладатель(и): Общество с ограниченной ответственностью "МГТ ПРОЕКТ СПБ" (RU) Дата регистрации: 21.10.2019 (45) Опубликовано: 21.10.2019 Бюл. № 30 1 9 3 2 4 5 R U (54) ДАТЧИК УРОВНЯ (57) Реферат: Техническое решение относится к акустическим методам измерения и контроля и предназначено для определения уровня жидкости в скважинах, в том числе нефтедобывающих. Технический результат вышеприведенной задачи достигается за счет создания датчика уровня, состоящего из корпуса, с одного торца Стр.: 1 которого расположена муфта и преобразователь акустического сигнала в электрический, а с другого - механический клапан для создания зондирующего акустического сигнала, отличающийся тем, что в датчике уровня размещен контроллер с радиоканалом для передачи данных и NFC-метка. U 1 U 1 Адрес для переписки: 195256, Санкт-Петербург, пр. Науки, 53, кв. 86, для Корытовской Г.Ю. 1 9 3 2 4 5 (56) Список документов, цитированных в отчете о поиске: RU 13391 U1, 10.04.2000. RU 2282718 C1, 27.08.2006. RU 2163293 C1, 20.02.2001. RU 17727 U1, 20.04.2001. RU 2654370 C1, 17.05.2018. US 4793178 A1, 27.12. ...

System and method for measuring depth and velocity of instrumentation within a wellbore using a bendable tool

An apparatus and method for measuring depth, velocity, or both depth and velocity of instrumentation within a wellbore is provided. The apparatus includes a downhole portion movable within the wellbore in a direction generally parallel to the wellbore. The apparatus further includes a first acceleration sensor mounted at a first position within the downhole portion. The first acceleration sensor generates a first signal indicative of a first acceleration in a first direction generally parallel to the wellbore at the first position. The apparatus further includes a second acceleration sensor mounted at a second position within the downhole portion. The second acceleration sensor generates a second signal indicative of a second acceleration in a second direction generally parallel to the wellbore at the second position. The apparatus further includes a bend sensor generating a third signal indicative of an amount of bend of at least a portion of the downhole portion.

System and method of improved depth of cut control of drilling tools

According to some embodiments of the present disclosure, a method of configuring a depth of cut controller (DOCC) of a drill bit comprises determining a desired minimum depth of cut for a radial swath of the drill bit. The method additionally comprises identifying a cutting edge of a cutting element located on the drill bit. The cutting edge is located within the radial swath and a cutting zone of the cutting element. The method further comprises identifying cutting elements that each include at least a portion located within the radial swath. The method also comprises determining a radial position and an angular position of a depth of cut controller (DOCC) for placement on the bit face based on the cutting edge of the cutting element. The method additionally comprises determining an axial position of the DOCC based on each portion of the cutting elements located within the radial swath.

Apparatus and Method for Detecting and Quantifying Leakage in a Pipe

The present invention is directed toward a method and an apparatus to investigate and quantify a leakage rate for a fluid (FG, FL) between a first pipe and a second pipe, the first pipe being surrounded by at least a portion of the second pipe, where the pipes are arranged in a well in a ground and where a measuring arrangement including a flow meter and a pressure meter is put into fluid communication with an annulus (B) defined by the first pipe and the second pipe, where fluid (FG) in the gaseous phase is conveyed through the measuring arrangement, as the annulus (B) is used as a separation chamber for gas (FG) and liquid (FL).

System and method for completion optimization

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

Electromagnetic depth/orientation detection tool and methods thereof

Methods and systems for depth and radial orientation detection are provided. Methods for determining the depth or radial orientation of one or more downhole components include the steps of providing a target mass and a using a detection device for detecting the depth and/or orientation of the target mass. In some cases, the target mass is an electromagnet. In certain embodiments, the target mass is a magneto-disruptive element that is detected with a magnetic flux leakage tool. In this way, the target mass acts as a depth or radial orientation marker. Where the target mass is situated downhole in a known radial relationship to another downhole component, the radial orientation of the other downhole component may be deduced once the radial orientation of the target mass is determined. Advantages include higher accuracies and reduced health, safety, and environmental risks.

Apparatus and Method for Galvanically Removing From or Depositing Onto a Device a Metallic Material Downhole

In one aspect, a method of performing a wellbore operation is disclosed that in one embodiment may include: deploying a device in the wellbore containing a conductive fluid, wherein the device is configured to disintegrate upon application of electrical current thereto; and applying current to the device in the wellbore using a tool to controllably disintegrate the device. In another aspect, an apparatus for use downhole is provided that in one embodiment may include a device placed at a selected location in a wellbore, wherein the device is made from a material that disintegrates when electric current is induced in to device and a tool placed proximate to the device configured to induce electric current into the device to cause the device to disintegrate.

System and method for surface steerable drilling

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

SYSTEM AND METHOD OF CONFIGURING DRILLING TOOLS UTILIZING A CRITICAL DEPTH OF CUT CONTROL CURVE

According to some embodiments of the present disclosure, a method of determining a critical depth of cut of a drill bit comprises selecting a radial swath associated with an area of a bit face of a drill bit. The method further comprises identifying a plurality of cutting elements disposed on the bit face that each include at least a portion located within the radial swath. The method also comprises identifying a depth of cut controller (DOCC) disposed on the bit face and configured to control a depth of cut of the portions of the plurality of cutting elements located within the radial swath. The method additionally comprises calculating a critical depth of cut associated with the radial swath and DOCC based on a depth of cut associated with each portion of the plurality of cutting elements located within the radial swath and controlled by the DOCC. 1. A method of determining a critical depth of cut of a drill bit comprising:selecting a radial swath associated with an area of a bit face of a drill bit;identifying a plurality of cutting elements disposed on the bit face that each include at least a portion located within the radial swath;identifying a depth of cut controller (DOCC) disposed on the bit face and configured to control a depth of cut of the portions of the plurality of cutting elements located within the radial swath; andcalculating a critical depth of cut associated with the radial swath and DOCC based on a depth of cut associated with each portion of the plurality of cutting elements located within the radial swath and controlled by the DOCC.2. The method of claim 1 , further comprising configuring the DOCC according to the calculated critical depth of cut.3. The method of claim 1 , further comprising:calculating an axial underexposure between the DOCC and each of the portions of the plurality of cutting elements located within the radial swath; andcalculating the depth of cut associated with each portion of the plurality of cutting elements located ...

System and method of configuring drilling tools utilizing a critical depth of cut control curve

According to some embodiments of the present disclosure, a method of determining a critical depth of cut of a drill bit comprises selecting a radial swath associated with an area of a bit face of a drill bit. The method further comprises identifying a plurality of cutting elements disposed on the bit face that each include at least a portion located within the radial swath. The method also comprises identifying a depth of cut controller (DOCC) disposed on the bit face and configured to control a depth of cut of the portions of the plurality of cutting elements located within the radial swath. The method additionally comprises calculating a critical depth of cut associated with the radial swath and DOCC based on a depth of cut associated with each portion of the plurality of cutting elements located within the radial swath and controlled by the DOCC.

Apparatus and method for obtaining information from drilled holes for mining

Apparatus and method for obtaining information from drilled holes for mining A mobile vehicle ( 11 ) is operated autonomously to approach a hole ( 13 a ) from which information is to be obtained. An onboard perception system ( 17 ) detects the exact location of the hole and an onboard sensor ( 26 ) is deployed from the vehicle into the hole. Perception system ( 17 ) comprises a number of scanners ( 23 ) carried by a mounting ( 24 ) fitted to the rear of the vehicle. A downhole sensor unit ( 18 ) movable along a swinging arm ( 19 ) carries downhole sensors selectively lowerable into the hole by operation of cable reels within the unit ( 18 ).

METHOD AND SYSTEM OF CALCULATING A FAULT THROW

Calculating a fault throw. At least some embodiments are methods of determining an underground surface or horizon including: identifying an occluded zone residing between a first and second faults, the occluded zone not penetrated by an actual borehole, and the first and second faults intersect an expected location of the surface; calculating a fault throw for the first fault; and calculating the underground surface using the fault throw. Calculating the fault throw may include: calculating a first pseudo depth at a first end of the first fault, the calculating the first pseudo depth using at least one actual depth value that resides across the first fault from the first end; calculating a second pseudo depth at a second end of the first fault, the second end distinct from the first end; and determining the fault throw using the first and second pseudo depths. 1. A method comprising: identifying an occluded zone residing between a first and second faults, the occluded zone not penetrated by an actual borehole, and the first and second faults intersect an expected location of the surface;', calculating a first pseudo depth at a first end of the first fault, the calculating the first pseudo depth using at least one actual depth value that resides across the first fault from the first end;', 'calculating a second pseudo depth at a second end of the first fault, the second end distinct from the first end; and', 'determining the fault throw using the first and second pseudo depths;, 'calculating a fault throw for the first fault by, 'calculating the underground surface using the fault throw for the first fault and the actual depth values from actual boreholes., 'determining an underground surface using a plurality of actual depth values from actual boreholes, the determining comprising2. The method of wherein calculating the first pseudo depth further comprises interpolating the first pseudo depth using a plurality of actual depth values claim 1 , wherein each actual ...

System and Method for Measuring Well Flow Rate

The present invention discloses an improved system for measurement of the liquid flow rate and totalized liquid production of a producing well. In the method of the present invention, liquid production rate in a pumping well is determined by calculation based upon wellbore geometry and continuously monitoring the depth of the fluid level within the wellbore. It is applicable to any pump lifted well where it is possible to shut the pump off periodically. Accuracy is enhanced with this method by properly accounting for pump leakage and where pump leakage is either known or can be estimated within reasonable limits or where it is measured during the pump shut off cycle.

WELL MONITORING

Downhole water level detecting apparatus for detecting the level of water in a formation in the region of a well installation. The detecting apparatus includes a transmitter for applying electrical signals to a signaling loop at a first location. The signaling loop includes a downhole metallic structure of the well installation and an earth return. The detecting apparatus also includes a detector for monitoring electrical signals in the signaling loop, and an evaluation unit arranged for determining a level of water in the formation relative to the downhole metallic structure in dependence on the monitored signals. 1. Downhole water level detecting apparatus for detecting the level of water in a formation in the region of a well installation , the detecting apparatus comprising a transmitter for applying electrical signals to a signalling loop at a first location , which signalling loop comprises downhole metallic structure of the well installation and an earth return , a detector for monitoring electrical signals in the signalling loop , and an evaluation unit arranged for determining a level of water in the formation relative to the downhole metallic structure in dependence on the monitored signals.2. Downhole water level detecting apparatus according to in which the detector comprises a receiver for receiving signals from the signalling loop at a second location and the evaluation unit is arranged for determining a level of water in the formation relative to the downhole metallic structure in dependence on the received signal strength.3. Downhole water level detecting apparatus according to in which the detector is arranged to measure signals claim 1 , in the metallic structure between two spaced contacts claim 1 , where at least one of the two spaced contacts is disposed at or in the region of the first location.4. Downhole water level detecting apparatus according to in which the transmitter is arranged to inject signals into tubing of the well installation.5. ...

WELLHEAD WATER LEVEL SENSOR

A module gathers information about the level of water in a water well and sends the information to a database. A sensor tracks the level of water in the well, how it changes over time, and the pace of recharge including the rate of water replenishment from the groundwater source. The system can be programmed to send alerts to interested parties when certain thresholds are reached. 1. A well head water level sensing device for use in a water well having a casing pipe and a well head attached to the casing pipe above a ground level , the water well further including a pump for pumping water to the ground level , the device comprising:a sensing array positioned on the well head and including a signal generator, tunable listening device, at least one calibration sensor, clock, at least one listening sensor, a memory, at least one communication circuit, and a power source;wherein the signal generator and tunable listening device determine the resonant frequency of the water well;wherein the memory stores data collected by the calibration sensor and the listening sensor; andwherein the at least one communication circuit is in communication with a remote network and is configured to transmit the data stored in the memory to the remote network.2. The well head water level sensing device of claim 1 , wherein the calibration sensor senses temperature and humidity.3. The well head water level sensing device of wherein the power source includes a battery.4. The well head water level sensing device of wherein the power source further includes at least one photovoltaic cell.5. A method of sensing water level in a residential water well having a casing pipe and a well head attached to the casing pipe above a ground level claim 5 , the water well further including a pump for pumping water to the ground level claim 5 , the method comprising:providing a well head water level sensing array including a signal generator, tunable listening device, at least one calibration sensor, clock, ...

PUMPJACK TORQUE FILL ESTIMATION

The fill of a downhole pump of a pumpjack or other system may be estimated based on a dynamically changing a reference torque or force curve and actual torque or force measurements during at least a portion of a pump stroke. Using various techniques, the reference curve may dynamically change over time to take into account slowly changing operating conditions. Moreover, the reference curve and/or the measurements may be adjusted to ensure that the estimated and/or reported pump fill does not exceed 100 percent of pump capacity. 1. A method for estimating pump fill , comprising:receiving data representing a series of torque or force measurements through a portion of a stroke of a pump;determining, by a computer, a reference torque or force curve based on a previous reference curve and the series of torque or force measurements; anddetermining, by the computer, an estimated pump fill of the pump based on the reference curve and the series of measurements.2. The method of claim 1 , further comprising determining a peak measurement of the series of measurements claim 1 , wherein determining the reference curve comprises determining a peak of the reference curve based on a peak of the previous reference curve and the peak measurement.3. The method of claim 2 , wherein determining the peak of the reference curve comprises determining the peak of the reference curve based on a difference between the peak of the previous reference curve and the peak measurement.4. The method of claim 1 , further comprising:determining a first area represented by the series of measurements; anddetermining a second area represented by the reference curve,wherein determining the estimated pump fill comprises determining the estimated pump fill based on a difference between the first and second areas.5. The method of claim 1 , further comprising:determining whether any portion of the determined reference curve has values smaller than a corresponding subset of the series of measurements; andfor ...

Borehole Array for Ranging and Crosswell Telemetry

An example method includes polling a plurality of reference nodes distributed along one or more reference wells. The method also includes steering a bottomhole assembly in another well based at least in part on information obtained from said polling. A related system includes a plurality of reference nodes distributed along one or more reference wells. The system also includes a bottomhole assembly in another well. The system also includes a surface controller. The surface controller polls the plurality of reference nodes to obtain position information regarding the bottomhole assembly and directs a steering module of the bottomhole assembly based on the obtained position information.

SYSTEM AND METHOD FOR DETECTING STRUCTURAL INTEGRITY OF A WELL CASING

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

METHOD AND DEVICE FOR DEPTH POSITIONING DOWNHOLE TOOL AND ASSOCIATED MEASUREMENT LOG OF A HYDROCARBON WELL

A depth positioning method to position a production logging tool () and a measurement log in a hydrocarbon well () in production obtained by means of the tool, the depth positioning method comprises: 1. A depth positioning method to position a production logging tool and a measurement log in a hydrocarbon well in production obtained by means of said tool , the depth positioning method comprises:generating a set of magnetic measurements of a depth portion of the hydrocarbon well from a first passive magnetic sensor along the depth portion of the hydrocarbon well, the set of magnetic measurements comprising magnitude and/or direction measurements of the magnetic field that forms a characteristic magnetic field pattern representative of a surrounding magnetic environment of the hydrocarbon well all along the depth portion;comparing said set of magnetic measurements to another set of magnetic measurements, the other set of magnetic measurements being a reference set of magnetic measurements generated either by a same or similar passive magnetic sensor deployed and run in the hydrocarbon well earlier, or by a second passive magnetic sensor spaced from the first passive magnetic sensor from a defined distance deployed and run in the hydrocarbon well simultaneously; anddetermining the maximum of correlation between the set of magnetic measurements and the reference set of magnetic measurements, said maximum being related to identifiable characteristic magnetic field pattern over a part of the depth portion.2. The depth positioning method of claim 1 , when the reference set of magnetic measurements is generated by the same or similar passive magnetic sensor deployed and run in the hydrocarbon well earlier claim 1 , further comprising:determining a depth shift between the two set of magnetic measurements by determining the maximum of correlation in a sliding depth window;calculating a corrected depth log; andcorrecting a depth positioning scale of a measurements log taken by ...

REMOVING WATER DOWNHOLE IN DRY GAS WELLS

A tool having a downhole conveyance, a first packer, a second packer, a pump, and a first and second sensor. The pump defines a plurality of inlets and an outlet, wherein the plurality of inlets is aligned with a first plurality of holes in the downhole conveyance, and the outlet oriented in a direction longitudinally opposite the first plurality of holes and the second plurality of holes. The second sensor is longitudinally separated further away from the first plurality of holes than the first sensor and configured to activate the pump when a water level is detected. The first sensor is configured to deactivate the pump when the water level is detected. 1. A tool , comprising:downhole conveyance defining a first plurality of holes and a second plurality of holes longitudinally separated from the first plurality of holes;a first packer affixed to an outer surface of the downhole conveyance and longitudinally separated further from the first plurality of holes than the second plurality of holes;a second packer affixed to the outer surface of the downhole conveyance and longitudinally separated further from the second plurality of holes than the first plurality of holes;a pump define a plurality of inlets and an outlet, wherein the plurality of inlets is aligned with the first plurality of holes, and the outlet oriented in a direction longitudinally opposite the first plurality of holes and the second plurality of holes; anda first sensor and a second sensor affixed to the outer surface and located between the first plurality of holes than the second plurality of holes, the second sensor longitudinally separated further away from the first plurality of holes than the first sensor and configured to activate the pump when a water level is detected, and the first sensor configured to deactivate the pump when the water level is detected.2. The tool of claim 1 , wherein the downhole conveyance is a production string.3. The tool of claim 1 , wherein the first packer and ...

Managed Pressure Drilling System and Method

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

Down-hole Liquid Level Control for Hydrocarbon Wells

This invention provides for an apparatus that controls a liquid level down-hole of a hydrocarbon producing well by physically monitoring the liquid level down-hole having a down-hole liquid level measurer and a signal device connected to the liquid level measurer that causes a pump to adjust its current liquid output based on the liquid level down-hole as measured by the down-hole liquid level measurer. 1. An apparatus that controls a liquid level down-hole of a hydrocarbon producing well by monitoring the liquid level down-hole in the well comprising:(a) a down-hole liquid level measurer lowered into the well and supported by pipe having a float that can travel vertically up and down a caged support structure wherein the float is exposed; and(b) a signal device connected to the liquid level measurer that causes a pump to adjust the pumps current liquid output based on the liquid level down-hole as measured by the down-hole liquid level measurer.2. An apparatus as recited in wherein monitoring the liquid level down-hole in the well is done physically.3. An apparatus as recited in wherein the float can move vertically up and down and horizontally.4. An apparatus as recited in wherein the signal device comprises:(a) a top target connected to the float;(b) a bottom target connected to the float;(c) an upper sensing device connected to an upper support structure so that when the liquid level down-hole causes the float to rise vertically, the top target engages the upper sensing device thereby initiating an increase in the amount of liquid removed from the well; and(d) a lower sensing device connected to a lower support structure so that when the liquid level down-hole causes the float to descend vertically, the lower target engages the lower sensing device thereby initiating a decrease in the amount of liquid removed from the well.5. An apparatus as recited in wherein the support structure is a guide that allows the float to move with a surface of the liquid level ...

DETERMINING A TECHNICAL LIMIT FOR A DRILLING OPERATION USING A MACHINE LEARNING ALGORITHM

A system can determine an accurate technical limit for a wellbore drilling operation using machine learning. A computing device can receive real-time data of the wellbore drilling operation; apply a machine-learning algorithm to the real-time data to determine a lost connection of the wellbore drilling operation; apply the machine-learning algorithm to determine correlations between the real-time data and historic drilling reports; and determine the technical limit for the wellbore drilling operation based on the correlations. 1. A system comprising:a processing device; and receive real-time data of a wellbore drilling operation;', 'apply a machine-learning algorithm to the real-time data to determine a lost connection of the wellbore drilling operation;', 'apply the machine-learning algorithm to determine correlations between the real-time data and historic drilling reports; and', 'determine a technical limit for the wellbore drilling operation based on the correlations., 'a memory device that includes instructions executable by the processing device for causing the processing device to2. The system of claim 1 , wherein the memory device further includes instructions executable by the processing device for causing the processing device to determine a total minimal connection claim 1 , an invisible lost time claim 1 , a conventional non-productive time claim 1 , a perfect well time claim 1 , or a combination thereof for the wellbore drilling operation based on the technical limit.3. The system of claim 2 , wherein the memory device further includes instructions executable by the processing device for causing the processing device to output a command to cause an adjustment of the wellbore drilling operation based on the invisible lost time.4. The system of claim 3 , wherein the technical limit varies during the wellbore drilling operation based on a depth of a wellbore.5. The system of claim 4 , wherein the memory device further includes instructions executable by ...

WELLBORE ANALYSIS USING TM01 AND TE01 MODE RADAR WAVES

A method of wellbore analysis using TM01 and TE01 modes of radar waveforms can include transmitting, at a first time, a radar waveform from a wellhead into a tubing disposed in a wellbore positioned in a reservoir. The radar waveform is either a TM01 mode or a TE01 mode waveform. The tubing includes a fluid, and the surface of the wellbore includes the wellhead. At a second time, a reflected waveform generated by reflecting the transmitted radar waveform on a fluid surface of the fluid is received at the wellhead. A fluid level of the fluid is determined based on the time difference between the first time and the second time, and on a transmission speed of the radar waveform from the wellhead to the fluid surface. The fluid level is a distance between the wellhead and the fluid surface of the fluid. 1. A method , comprising:transmitting, at a first time and from a wellhead, a radar waveform into a tubing disposed in a wellbore positioned in a reservoir, wherein the radar waveform is at least one of a TM01 mode or TE01 mode waveform, the tubing comprising a fluid, and the surface of the wellbore comprising the wellhead;receiving, at a second time and at the wellhead, a reflected waveform generated by reflecting the transmitted radar waveform on a fluid surface of the fluid;determining a time difference between the first time and the second time; anddetermining a fluid level of the fluid based on the time difference and on a transmission speed of the radar waveform from the wellhead to the fluid surface, wherein the fluid level is a distance between the wellhead and the fluid surface of the fluid.2. The method of claim 1 , wherein the fluid comprises a hydrocarbon liquid.3. The method of claim 1 , wherein the radar waveform is a TM01 mode waveform having a frequency above 3 GHz.4. The method of claim 1 , wherein the radar waveform is a TE01 mode waveform having a frequency above 4 GHz.5. The method of claim 1 , wherein the tubing extends from the surface of the ...

METHOD AND APPARATUS FOR DETERMINING OIL-GAS-WATER INTERFACE BASED ON FORMATION PRESSURE EQUIVALENT DENSITY

The present invention provides a method and an apparatus for determining an oil-gas-water interface based on the formation pressure equivalent density. The method comprises determining working parameters of the wireline modular formation tester based on the acquired conventional logging data of a block to be studied; acquiring a series of formation pressure and corresponding depth data based on the working parameter; computing formation pressure equivalent densities at different depths based on the formation pressure and the corresponding depth data; drawing a crossplot of the formation pressure equivalent density and the depth according to the formation pressure equivalent density and the corresponding depth data at the different depths; and determining the oil-gas-water interface according to the position of breaking point of the formation pressure equivalent density on the crossplot of the formation pressure equivalent density and the depth. 1. A method for determining an oil-gas-water interface based on formation pressure equivalent density , wherein the method comprises the steps of:acquiring conventional logging data of an oilfield well to be studied;analyzing the conventional logging data and determining the working parameters of the wireline modular formation tester;acquiring a series of formation pressure and corresponding depth data, wherein the formation pressure and the corresponding depth data are obtained by the wireline modular formation tester performing a test under the working parameters;computing formation pressure equivalent densities at different depths according to the formation pressure and the corresponding depth data;drawing a crossplot of the formation pressure equivalent density and the depth according to the formation pressure equivalent density and the corresponding depth data at the different depths; anddetermining the oil-gas-water interface according to the position of the breaking point of the formation pressure equivalent density on ...

RISK ASSESSMENT-BASED DESIGN METHOD FOR DEEP COMPLEX FORMATION WELLBORE STRUCTURE

A risk assessment-based design method for a deep complex formation wellbore structure includes: (1) preliminarily determining casing layers and setting depths; (2) calculating to obtain the risk coefficients of each layer of casing; (3) analyzing and coordinating, according to the principle that a shallow casing shares more risks and a deep casing shares less risks, the risks of each layer of casing: determining whether the risk coefficients of each layer of casing are greater than a safety threshold value K; checking the setting depth: if the safety coefficient of an ith-layer casing satisfies R>K, selecting a casing layer with the minimum safety coefficient from upper casing layers, and deepening the setting depth h of the casing layer; and (4) repeating the steps (2) to (3) until the casing risk coefficients of each layer of casing are less than the safety threshold value K. 1. A risk assessment-based design method for a deep complex formation wellbore structure , comprising:(1) preliminarily determining casing layers and a setting depth;(2) calculating risk coefficients of each layer of casing;(3) analyzing and coordinating, according to a principle that a shallow casing shares more risks and a deep casing shares less risks, the risks of each layer of casing:determining whether the risk coefficients of each layer of casing are greater than a safety threshold value K;{'sub': 'Ni', 'checking the setting depths: if a safety coefficient of an ith-layer casing satisfies R>K, selecting a casing layer with the minimum safety coefficient from upper casing layers, and deepening the setting depth h of the casing layer; and'}(4) repeating (2) to (3) until the risk coefficients of each layer of casing are less than the safety threshold value K.2. The risk assessment-based design method for the deep complex formation wellbore structure according to claim 1 , wherein the method for preliminarily determining the casing layers and the running depths in (1) at least comprises:(1 ...

DOWNHOLE STINGER GEOTECHNICAL SAMPLING AND IN SITU TESTING TOOL

Offshore system for delivering geotechnical tools to seafloor is described. The system includes a carrier tube that includes an upper end and a lower end, wherein the carrier tube is characterized by an outer diameter and an inner diameter and wherein the inner diameter of the carrier tube defines a hydraulic cylinder; a landing sub shaped or installed at or near the upper end of the carrier tube, wherein inner diameter of the landing sub is smaller than the inner diameter of the carrier tube; a drill bit shaped or installed at or near the lower end of the carrier tube; an extension tube extending upward from the upper end of the carrier tube; an upward seal that seals top portion of the extension tubes; a compression system for introducing compressed fluid under the upward seal; a fixed rod that runs through the hydraulic cylinder; a hydraulic piston disposed in the hydraulic cylinder, wherein the hydraulic piston is moveable along the fixed rod; one or more shear pins configured to restrict displacement of the hydraulic piston until a sufficient fluid pressure is built up; and an inner tube disposed between the carrier tube and the hydraulic piston, wherein lower portion of the inner tube includes a cone penetrometer that is ballistically inserted into the soil during downward displacement of the hydraulic piston. 1. An offshore system for in situ testing of soil comprising:a) a carrier tube comprising an upper end and a lower end, wherein the carrier tube is characterized by an outer diameter and an inner diameter and wherein the inner diameter of the carrier tube defines a hydraulic cylinder;b) a landing sub shaped or installed at or near the upper end of the carrier tube, wherein inner diameter of the landing sub is smaller than the inner diameter of the carrier tube;c) a drill bit shaped or installed at or near the lower end of the carrier tube;d) a series of extension tubes extending upward from the upper end of the carrier tube;e) an upward seal that seals ...

Submersible Pump Monitoring

In order to address the above noted problems, embodiments of the present invention use distributed acoustic sensing to monitor the fluid level in an ESP activated well so as to monitor the condition and performance of the ESP. Embodiments of the invention use the ESP as an acoustic source in order to monitor the annulus fluid level within the well and to monitor the frequency of the ESP. Additionally, embodiments of the present invention may use distributed acoustic sensing to monitor the flow rates of the production fluid above and below the ESP to determine the pump's efficiency. In particular, some embodiments utilise one or more optical fibers to measure the acoustic waves generated by the ESP, wherein the fiber cabling has already been deployed along the length of the well. As such, the present invention is a non-invasive, in-situ method for monitoring the condition and performance of an ESP. 1. A method of in-well fluid level detection comprising using an optical fiber distributed acoustic sensor to measure the propagation of acoustic waves within fluid in a well to determine the location of a fluid interface within the well , wherein the acoustic waves are generated by a submersible pump when in operation.2. (canceled)3. A method according to claim 1 , wherein measuring the propagation of acoustic waves includes detecting one or more reflections of an acoustic wave.4. A method according to claim 1 , wherein measuring the propagation of acoustic waves includes measuring the speed of sound of the acoustic waves.5. A method according to claim 4 , wherein determining the location of the fluid interface in the well comprises detecting a change in the speed of sound measurements.6. A method according to claim 1 , wherein determining the location of the fluid interface in the well comprises measuring the propagation of acoustic waves from a known location claim 1 , optionally of the submersible pump claim 1 , to the fluid interface whereby to determine the distance ...

TUNNEL DETECTION METHOD AND SYSTEM

The present invention provides a system and method for detecting underground tunnels by using bentonite-slurry. 1. A system for detecting underground tunnels , comprising:a) at least one bentonite-slurry filled essentially-vertical moat;b) at least one detection device associated with each of said at least one moat; andc) at least one control system connected to all of said at least one detection devices,wherein when an underground tunnel is expanded to traverse any of said at least one moat, said bentonite-slurry drains into said underground tunnel and the detection device associated with said moat alerts that the bentonite-slurry has drained thus signaling the existence of an underground tunnel in the location of the moat.2. The system of claim 1 , wherein said essentially-vertical moats are dug along a bordering line either (i) at two essentially-parallel dashed lines with about 1 meter spacing between the lines claim 1 , and wherein the openings (un-dug section) in the first line are placed in front of the moats of the second line claim 1 , thereby creating a zipper-like line; or (ii) at a single line with a maximum of 1 meter interval between each moat.3. (canceled)4. The system of claim 1 , wherein said at least one detection device measures any one of the following parameters of the bentonite-slurry fill: level/volume claim 1 , viscosity claim 1 , content claim 1 , conductivity claim 1 , height claim 1 , movement claim 1 , position or any combination thereof.5. The system of claim 1 , wherein said at least one control system sends out an alert in response to any change in the measured parameters of a detection device indicating the presence of a newly dug tunnel in the area of the detection device.68-. (canceled)9. The system of claim 1 , further comprising a guide at the top of said at least one moat claim 1 , wherein said guides are optionally formed when paving a road-like structure along the bordering line.10. (canceled)11. The system of claim 1 , further ...

METHOD AND APPARATUS FOR SUBSEA WELL PLUG AND ABANDONMENT OPERATIONS

The invention provides a method and apparatus for performing a plug and abandonment operation on a subsea well. A wellhead interface module is located on a wellhead, which accommodates a volume of wellbore fluid in fluid communication with the wellbore. A system control module receives a signal from a sensor in the chamber and is configured to derive volume data relating to a change in volume of wellbore fluid in the chamber and compares the derived volume data with a volume change expected due to the removal of tubing from the wellbore. In embodiments of the invention, this enables a change in wellbore conditions to be characterised, for example a fluid influx or a fluid loss, from the volume data. The method may comprise providing wellbore fluid to the apparatus to replace fluid which enters the wellbore to occupy the volume vacated by the tubing, and/or removing or adding fluid in fluid influx/loss situations respectively.

Bore measuring tool

An apparatus for measuring a well bore wall comprises a casing connectable in line with a tool string having a central passage therethrough and extending between first and second ends and a plurality of longitudinally extending biasing elements extending longitudinally along the casing between first and second ends wherein each of the second end of the biasing elements is connected to the casing. The apparatus further comprises a sensor located along a midpoint of each of the biasing elements and an engagement body located within the central passage of the casing longitudinally displaceable therein between first and second positions, wherein the engagement body is connected to the first end of each of the biasing elements such that displacement of the engagement body within the central passage from the first to the second positions compresses and radially extends the biasing elements so as to engage the sensors against the well bore wall.

DEVICE FOR MEASURING SUSPENSION IN DRILLING FLUID AND THICKNESS OF SLIME AT THE BOTTOM OF PILE BOREHOLE

The present invention relates to a device for measuring a suspension in a drilling fluid and a thickness of slime at the bottom of a pile borehole, the device including: a data cable insertable into the pile borehole; a slime-meter probe connected to one end of the data cable in such a manner as to be descended to the interior of the pile borehole by the own weight thereof to measure the thickness of the slime at the bottom of the pile borehole; and a slime-meter outer part mounted on the outside of the slime-meter probe in such a manner as to be movable relatively to the slime-meter probe when reaches the bottom of the pile borehole. 1. A device for measuring a suspension in a drilling fluid and a thickness of slime at the bottom of a pile borehole , the device comprising:{'b': '300', 'a data cable insertable into the pile borehole;'}{'b': 200', '300, 'a slime-meter probe connected to one end of the data cable in such a manner as to be descended to the interior of the pile borehole by the own weight thereof to measure the thickness of the slime at the bottom of the pile borehole; and'}{'b': 100', '200', '200, 'a slime-meter outer part mounted on the outside of the slime-meter probe in such a manner as to be movable relatively to the slime-meter probe when reaches the bottom of the pile borehole.'}2200210. The device according to claim 1 , wherein the slime-meter probe has a probe tip disposed at the front end thereof to sense the changes in specific resistances from the contact with the slime at the bottom of the pile borehole.3400300300. The device according to claim 2 , further comprising a cable tension sensing part connected to the other end of the data cable to measure the tension of the data cable .4100. The device according to claim 3 , wherein the slime-meter outer part comprises:{'b': 110', '300', '200, 'a slime-meter outer body located to pass the data cable through the center thereof and to locate the slime-meter probe at the underside thereof; and'}{'b ...

HYBRID HYDRAULIC GAS PUMP SYSTEM

A hybrid hydraulic gas pump system includes a hydraulic gas pump installed on the lower end of a production tubular where the production tubular incorporates a gas lift system. The hydraulic gas pump may be operated using the same gas in the annular region as the gas lift system or may be operated using an independent supply line where the independent supply line is concentric with, or at least within, the production tubular. In some instances, the gas pump chamber may simply be an upper packer including a pickup tube, a check valve, and a pressurized gas supply line or other pressurized gas access mechanism along with a lower packer including a check valve. Each upper and lower check valve allows fluid to flow from below the packer to above the packer. 1. An artificial lift system comprising:a production tubular; 'wherein the gas lift system is attached to the production tubular;', 'a gas lift system having a gas lift mandrel, a gas lift valve; and a first gas supply; and'} 'wherein the hydraulic gas pump is attached to the production tubular.', 'a hydraulic gas pump having a first check valve, a second check valve, and a second gas supply; and'}2. The artificial lift system of wherein claim 1 , the first gas supply is provided via a primary annular region.3. The artificial gas lift system of claim 1 , wherein the first gas supply actuates the gas lift system.4. The artificial gas lift system of claim 1 , wherein the first gas supply reduces a density of a wellbore fluid.5. The artificial gas lift system of claim 1 , wherein the second gas supply is within the production tubular.6. The artificial gas lift system of claim 5 , wherein the second gas supply strokes the hydraulic gas pump.7. An artificial lift system comprising:a production tubular; 'wherein the gas lift system is attached to the production tubular;', 'a gas lift system having a gas lift mandrel, a gas lift valve; and an annular gas supply; and'} 'wherein the hydraulic gas pump is attached to the ...

METHOD FOR ORIENTING WHIPSTOCK FOR CASING EXIT IN VERTICAL AND NEAR VERTICAL WELLS USING XY MAGNETOMETERS

A system and method for orienting a tool in a near vertical wellbore. The system includes a tool string having a whipstock at an end thereof, at least two magnetometers oriented transverse to a longitudinal axis of the tool string, and a processor. A first set of magnetic measurements of the earths' magnetic field is obtained during rotation of the tool using a first of the at least two magnetometers and a second set of magnetic measurements of the earth's magnetic field is obtained during rotation using a second of the at least two magnetometers. The processor fits a curve to the first and second sets of magnetic measurements to determine a peak value, determines magnetic north from the determined peak value, determines a toolface orientation of the drill string with respect to the determined magnetic north, and anchors the whipstock at the selected depth and toolface orientation. 1. A method of orienting a tool in a near vertical wellbore , comprising:rotating the tool at a selected depth of the near vertical wellbore, the tool including at least two magnetometers oriented transverse to a longitudinal axis of the tool;obtaining, during rotation of the tool, a first set of magnetic measurements of the earth's magnetic field using a first of the at least two magnetometers and a second set of magnetic measurements using a second of the at least two magnetometers;fitting a curve to the first and second sets of magnetic measurements to determine a peak value;determining magnetic north from the determined peak value; andorienting the tool along a selected orientation based on the determined magnetic north.2. The method of claim 1 , further comprising conveying the tool to the selected depth using magnetic measurements of a casing in the wellbore obtained by the at least two magnetometers.3. The method of claim 1 , wherein orienting the tool further comprises determining a first orientation of the tool with respect to magnetic north claim 1 , determining an angular ...

RESONANT ACOUSTIC STRUCTURE FOR MEASURING WELL OR BOREHOLE DEPTH

A method and apparatus to measure the fluid depth in a well or borehole is described. The approach reduces the effects of acoustic noise occurring near the top of the well or borehole that can interfere with the fluid depth measurement. A resonant acoustic structure between an acoustic transducer and the well or borehole provides efficient coupling of spectrally narrow acoustic signals into the well or borehole, as well as providing a bandpass acoustic filter on the returning signal, to improve the signal to noise ratio of the desired acoustic reflection. 1. An apparatus for measuring the distance to an acoustically reflective surface in a well or borehole , comprised of:a substantially airtight housing containing an acoustic transducer to generate an acoustic signal and an acoustic detector to measure acoustic signals;a pipe having a diameter substantially smaller than the diameter of said housing, and fastened over an aperture in said housing;where said pipe fastened to an access port of a well or borehole, where said well or borehole has a diameter substantially larger than said pipe;where said acoustic generator produces an acoustic signal with a substantial fraction of energy in a range of frequencies that coincide with at least one resonant frequency of said pipe.21. The apparatus in claim [] where the transducer is selected from the list including but not limited to: an electromagnetic speaker , a piezoelectric disc , an electrostatic speaker , and a compressed air solenoid.31. The apparatus in claim [] where the pipe has a circular cross-section with a diameter in the range of 1 cm to 30 cm.41. The apparatus in claim [] where the pipe is comprised of a material selected from the list including but not limited to steel , cast iron , polyvinyl chloride , copper , brass , nylon , and fluorinated polymer , polyethylene or stainless steel.51. The apparatus in claim [] where the acoustic detector is selected from the list including but not limited to a condenser ...

METHOD AND SYSTEM FOR DETERMINING RELATIVE DEPTH OF AN ACOUSTIC EVENT WITHIN A WELLBORE

The present disclosure is directed at a method and system for determining relative depth of an acoustic event within a wellbore. The method includes obtaining two acoustic signals at two different and known depths in the wellbore, in which each of the acoustic signals includes the acoustic event; dividing each of the acoustic signals into windows; determining cross-correlations of pairs of the windows, in which each of the pairs includes one window from one of the acoustic signals and another window from the other of the acoustic signals that at least partially overlap each other in time; and determining the relative depth of the acoustic event relative to the two known depths from the cross-correlations. The acoustic event may represent, for example, fluid flowing from formation into the wellbore (or vice-versa) or fluid flowing across any casing or tubing located within the wellbore. 1. A method for determining relative depth of an acoustic event within a wellbore , the method comprising:(a) obtaining two acoustic signals at two different and known depths in the wellbore, wherein each of the acoustic signals includes the acoustic event;(b) dividing each of the acoustic signals into windows, each of which has a certain duration;(c) determining cross-correlations of pairs of the windows, wherein each of the pairs comprises one window from one of the acoustic signals and another window from the other of the acoustic signals that at least partially overlap each other in time; and(d) determining the relative depth of the acoustic event relative to the two known depths from the cross-correlations,wherein the acoustic event comprises fluid flowing from formation into the wellbore, fluid flowing from the wellbore into the formation, or fluid flowing across any casing or tubing located within the wellbore.2. A method as claimed in further comprising simultaneously measuring the acoustic event at the two different and known depths to generate the two acoustic signals.3. A ...

Determining Depth of Loss Zones in Subterranean Formations

A method includes injecting a treatment fluid through a tubular in a wellbore created in a subterranean formation, wherein the treatment fluid is to return through an annulus defined between the tubular and a wall of the wellbore. The method includes logging, during the injecting, measurements comprising at least one of an actual wellhead pressure; treatment fluid inlet density, inlet flow rate, outlet flow rate, and treatment fluid inlet viscosity. The method includes determining a loss zone location in the wellbore based on the measurements. 1. A method comprising:injecting a treatment fluid through a tubular in a wellbore created in a subterranean formation, wherein the treatment fluid is to return through an annulus defined between the tubular and a wall of the wellbore;logging, during the injecting, measurements comprising at least one of an actual wellhead pressure; treatment fluid inlet density, inlet flow rate, outlet flow rate, and treatment fluid inlet viscosity; anddetermining a loss zone location in the wellbore based on the measurements.2. The method of claim 1 , further comprising:determining a calculated wellhead pressure based on the measurements; andcalculating a wellhead pressure differential based on a difference between the calculated wellhead pressure and the actual wellhead pressure,wherein determining the loss zone location is based on the wellhead pressure differential.3. The method of claim 2 , further comprisingcalculating a flowrate loss based on a difference between the inlet flow rate and the outlet flow rate, wherein determining the loss zone location is based on the wellhead pressure differential.4. The method of claim 1 , wherein the treatment fluid comprises at least one of a non-aqueous fluid claim 1 , an aqueous fluid claim 1 , an aqueous-miscible fluid claim 1 , a water-in-oil emulsion claim 1 , and an oil-in-water emulsion.5. The method of claim 1 , wherein the tubular comprises at least one of a casing string claim 1 , a ...

TEMPERATURE-CORRECTED DISTRIBUTED FIBER-OPTIC SENSING

In distributed fiber-optic sensing within a borehole, the accuracy of correlating signal channels with depth along the borehole can be improved by taking the thermo-optic effect on the group velocity of light into account. In an example application, this allows, in turn, to more accurately localize acoustic sources via distributed acoustic sensing. Additional embodiments are disclosed. 1. A method comprising:coupling light into an optical fiber disposed in a borehole, and measuring a response signal comprising light backscattered at locations throughout a length of the optical fiber;determining a temperature profile along the borehole;based at least in part on the determined temperature profile and a wavelength of the light, determining a group velocity of the light as a function of at least one of the depth along the borehole or position along the optical fiber; andcomputationally correlating a plurality of channels within the measured response signal with respective depths along the borehole based at least in part on the determined group velocity.2. The method of claim 1 , wherein computationally correlating the plurality of channels with respective depths along the borehole comprises:computationally correlating the plurality of channels with respective positions along the optical fiber based at least in part on the determined group velocity; andcomputationally correlating positions along the optical fiber with respective depths along the borehole.3. The method of claim 2 , wherein computationally correlating the positions along the optical fiber with respective depths along the borehole is based on a length of a cable enclosing the optical fiber.4. The method of claim 3 , wherein computationally correlating the positions along the optical fiber with respective depths along the borehole comprises determining the length of the cable based at least in part on at least one of a temperature of the cable and an elongation of the cable under its own weight.5. The method ...

METHOD OF DETERMINING DEPTHS OF WELLBORE REFLECTORS

This disclose relates to a robust method for automatic real-time monitoring or post-job evaluation of hydraulic fracturing operations based on predictive deconvolution of the wellhead pressure oscillations. Described are a method and system for determining depth of wellbore reflectors, implemented by performing a wellbore operation producing a pressure wave and its reflections from the wellbore reflectors; registering a pressure wave and its reflections; preprocessing the registered pressure wave and its reflections with a bandwidth filter; transforming the registered pressure wave and its reflections from the frequency domain into time-frequency representation with Short Time Fourier Transform (STFT); applying of a predictive deconvolution filter to STFT representation; identifying of a reflected signal on a plot in coordinates “reflection time—physical time” and determining the reflection time for the signal reflected from the wellbore reflector; determining the depth of wellbore reflector by multiplying the reflection time by pressure wave speed. 1. A method of determining depth of wellbore reflectors by analyzing the pressure signal at wellhead , comprising:(a) performing a wellbore operation producing a pressure wave and its reflections from the wellbore reflectors;(b) registering a pressure wave and its reflections with a high-frequency pressure sensor at wellhead;(c) preprocessing the registered pressure wave and its reflections with a bandwidth filter;(d) transforming the registered pressure wave and its reflections from the frequency domain into time-frequency representation with Short Time Fourier Transform (STFT);(e) applying of a predictive deconvolution filter to STFT representation which produces the normalized intensity of wellbore reflectivity;(f) identifying of a reflected signal on a plot in coordinates “reflection time—physical time” and determining the reflection time for the signal reflected from the wellbore reflector;(g) determining the depth ...

MUD FLOW MONITORING DEVICES AND METHODS

A flow monitoring device for monitoring mud flow in a return line of a bore hole drilling operation, including a mounting bracket mounted to the return line with a viewing port for access to an interior of the return line. A light source illuminates, through the viewing port, a portion of the mud flow in an observation zone within the return line. A camera creates a plurality of images of the mud flow in the observation zone. A controller is configured to analyze the plurality images to: determine a level of the mud flow in the return line and the presence of at least one irregularity, track a movement of the irregularity across the plurality of images to determine a rate of movement of the irregularity, and calculate a flow rate of the mud flow through the return line based on the movement rate and the determined level. 1. A mud flow monitoring device for monitoring mud flow in a return line of a bore hole drilling operation , the flow monitoring device comprising:a mounting bracket mounted to the return line and having a viewing port for access to an interior of the return line;a light source configured to illuminate, through the viewing port, a portion of the mud flow in an observation zone within the return line;a camera configured to create a plurality of images of the mud flow in the observation zone; and determine a level of the mud flow in the return line and the presence of at least one irregularity,', 'track a movement of the irregularity across the plurality of images to determine a rate of movement of the irregularity, and', 'calculate a flow rate of the mud flow through the return line based on the movement rate and the determined level., 'a controller configured to analyze the plurality images so as to2. The mud flow monitoring device of claim 1 , further comprising a housing sized and shaped to enclose one or both of the light source and the camera.3. The flow monitoring device of claim 1 , wherein an operational axis of the light source and the ...

Fluid Distribution System for a Wellsite

A fluid distribution system for a wellsite. The fluid distribution system may include a remote controller, a remote pump fluidly coupled to the first piece of wellsite equipment, and a remote fluid tank fluidly coupled to the remote pump. The first piece of wellsite equipment may include a local fluid tank comprising a fluid level sensor, a fill valve fluidly coupled to the local fluid tank, and a local controller configured to actuate the fill valve in response to a fluid level of the local fluid tank and to transmit at least one of a fill valve position or the fluid level of the local fluid tank to the remote controller. The remote controller may be configured to start and stop the remote pump in response to the transmissions from the local controllers. 1. A fluid distribution system for a wellsite , the fluid distribution system comprising:a remote controller located outside of an area of the wellsite; a local fluid tank comprising a fluid level sensor,', 'a fill valve fluidly coupled to the local fluid tank, and', 'a local controller configured to actuate the fill valve in response to a fluid level of the local fluid tank and to transmit at least one of a fill valve position or the fluid level of the local fluid tank to the remote controller;, 'a first piece of wellsite equipment located inside the area of the wellsite, the first piece of wellsite equipment comprisinga remote pump fluidly coupled to the first piece of wellsite equipment and located outside of the area of the wellsite, wherein the remote controller is configured to start and stop the remote pump in response to the transmissions from the local controllers; anda remote fluid tank fluidly coupled to the remote pump and located outside of the area of the wellsite.2. The fluid distribution system of claim 1 , wherein:the fluid level sensor is a low fluid level sensor;the local fluid tank further comprises a high fluid level sensor; andthe local controller is configured to open the fill valve in ...

Method for Drilling Wellbores Utilizing Drilling Parameters Optimized for Stick-Slip Vibration Conditions

The present disclosure relates generally to the field of drilling operations. More particularly, the present disclosure relates to methods for drilling wells utilizing drilling equipment, more particularly drill string assemblies, and making adjustments to drilling parameters during the drilling operation based on analysis of the drilling data. Included are methods for the selection of modified drilling parameters to mitigate torsional vibration dysfunction.

DOWNHOLE DETECTION

There is disclosed an apparatus () for detecting and/or measuring a downhole feature (), such as a fluid/fluid interface, in a well (). The apparatus () comprises a first fluid and/or liquid permeable tube (). The first tube () is porous or (micro)perforated. The apparatus () comprises a second fluid and/or liquid impermeable tube (). The first and second tubes () are hollow, and therefore, provide first and second waveguides, respectively. 1. An apparatus for detecting a downhole feature in a well , the apparatus comprising a first tube which is fluid and/or liquid permeable.2. An apparatus as claimed in claim 1 , wherein:the well is an oil, gas and/or water well, and/orthe well is a production, injection/artificial lift, completed/sealed/pressurised, observation, injection, and/or disposal well.3. An apparatus as claimed in claim 1 , wherein:the first tube is porous or perforated; and/orthe first tube comprises an at least partially porous or perforated wall or side wall optionally comprising a plurality of pores, micropores, holes or slots.4. An apparatus as claimed in claim 1 , wherein the first tube comprises a polymeric or plastics material or a metallic material.5. An apparatus as claimed in claim 1 , wherein the apparatus comprises a second tube which is fluid and/or liquid impermeable claim 1 , optionally comprising a solid claim 1 , non-porous and/or non-perforated side wall.6. An apparatus as claimed in claim 5 , wherein the second tube comprises a polymeric or plastics material or a metallic material.7. An apparatus as claimed in claim 5 , wherein an end claim 5 , such as an upper or downstream end claim 5 , of the first tube is attached to or connected to an end claim 5 , such as a lower or upstream end claim 5 , of the second tube.8. An apparatus as claimed in claim 1 , wherein the first tube is hollow and/or a second tube is hollow claim 1 , the first tube and/or the second tube optionally providing respective first and second waveguides.9. An ...

METHOD FOR SLENDER TUBE, MULTI-LEVEL, SUBSURFACE BOREHOLE SAMPLING SYSTEM

Methods and systems for allowing the use of very small-diameter sample tubing, with a flexible borehole liner, in multi-level water sampling systems deployed in subsurface boreholes. Methods are disclosed for determining depth distances to a ground water table, in a borehole, without the need to lower a pressure transducer into a sampling tube. 1. A method for determining groundwater condition in a borehole beneath the earth's surface , comprising:defining a sleeve on a flexible liner;disposing in the sleeve at least a portion of a slender tube thereby to hold upon the liner at least the portion of the slender tube, the slender tube having a tube first end and a tube second end;defining a port in the liner;placing the slender tube in fluid communication with the port;everting the flexible liner into a borehole below the surface;situating the tube first end and the tube second end above a ground water table in the borehole;allowing ground water to flow from the port through the check valve into the slender tube;permitting the ground water to rise in the slender tube to a first level corresponding to the ground water table;closing the tube first end;changing a condition of a gas within the slender tube between the tube first end and the ground water in the slender tube to affect a change of a ground water level in the slender tube from the first water level to a second water level; anddetermining, from the condition of the gas or from the change of the ground water level in the slender tube, the depth of the ground water table.2. The method of claim 1 , wherein placing the slender tube in fluid communication with the port comprises:locating a check valve adjacent to and in fluid communication with the port; andplacing the slender tube in fluid communication with the check valve.3. The method of claim 1 , wherein situating the tube first end and the tube second end above a ground water table in the borehole further comprises situating the tube first end and the tube ...

STRIPPER DEVICE WITH RETRIEVAL MOUNTING PORTION AND METHOD OF USE

Described is a stripper device for a wellhead defining the terminus of an aliphatic hydrocarbon production well. The stripper device includes a lubricator assembly having a lubricator pipe in communication with the wellhead. The stripper device includes a dipper assembly traversing within the lubricator pipe and the well. A controller assembly provides instructions in a computer readable format to regulate the collection of liquid aliphatic hydrocarbons from the well with the dipper assembly. The stripper device includes a recovery assembly having a pivot element coupled to a lubricator pipe and to the wellhead. The pivot element renders the lubricator pipe to communicate with the wellhead in a first position and renders the lubricator pipe apart from the wellhead in a second position to expose the wellhead free of obstructions including those from the lubricator assembly. 120-. (canceled)21. A stripper device for a wellhead , the wellhead defining a terminus of an aliphatic hydrocarbon well , the aliphatic hydrocarbon well operating as a well , the stripper device comprising:a lubricator assembly having a lubricator pipe in communication with the wellhead and a dipper assembly traversing within the lubricator pipe and the well,a controller assembly for one or more of receiving and providing instructions in a computer readable format to regulate collection of liquid aliphatic hydrocarbons from the well with the dipper assembly,a recovery assembly having a pivot element operably coupled with the lubricator pipe and to the wellhead, such that the pivot element allows the lubricator pipe to communicate with the wellhead in a first position and renders the lubricator pipe apart from the wellhead in a second position to expose the wellhead free of obstructions including those from the lubricator assembly.22. The stripper device of further comprising a retrieval mounting portion operably coupled with the dipper assembly for fixedly receiving a variety of fishing neck ...

GROUNDWATER MONITORING SYSTEM AND METHOD

The present invention provides a groundwater monitoring system and method. The system in one aspect uses sound-based distance measurement techniques to measure groundwater level with one transducer generating an acoustic burst and another receiving it. At least one sonic transducer is installed in each of a processor-based controller and traveling probe. The system may use an accelerometer and the pressure sensor installed in the probe to measure groundwater thickness. While the probe moves upward or downward in the groundwater, water properties measured by sensors installed on the probe and corresponding depths of the measuring spots to the groundwater surface level measured by the pressure sensor are recorded. The system measures and saves data, including groundwater level, groundwater thickness, and a depth-related profile of water properties. In certain embodiments, the probe includes a microprocessor operable to control the transducer and sensors mounted thereto and effect two-way communication with the controller. 1. A groundwater monitoring system comprising:a borehole extending downwards through terra firma and defining a borehole head at grade;a controller disposed proximally to the borehole head and comprising programmable electronic circuitry having a processor;a rotatable cable drum positioned at the borehole head;a movable probe disposed in the borehole and operably coupled to the drum via a cable, the drum rotatable in a first direction to raise the probe and in a second direction to lower the probe in the borehole;a drive mechanism operable to rotate the drum in the first or second directions;a first sonic transducer mounted at the borehole head;a second sonic transducer mounted to the probe, the first and second sonic transducers in communication with the controller which is operable to measure a distance between the first and second transducers;one of the first or second transducers being a transmitter operable to emit an acoustic wave which is ...

Systems And Methods For Sensing A Fluid Level Within A Pipe

A system, method and device may be used to monitor fluid levels in a drill pipe in borehole. The system includes an electromagnetic (EM) generator to generate a traveling wave of electromagnetic energy to propagate along a linear path through the drill pipe towards a surface of the fluid, a detector to detect a portion of the electromagnetic wave reflected from the surface of the fluid and propagated through the drill pipe towards the detector, a processor to analyze detected signals to determine a level of the surface of the fluid. In an embodiment, the system includes a pump controller to control the operation of a pump located in the wellbore or at the mudline based on the fluid surface level.

Optimizing downhole data communication with at bit sensors and nodes

Data is communicated from sensors at a downhole location near a drill bit to surface equipment. Communication to the surface equipment may be direct or may pass through a series of nodes. The nodes in some cases are intelligently reconfigured to achieve desired data rates, achieve power management goals, and/or compensate for failed nodes.

A METHOD OF PERFORMING A REAMING OPERATION AT A WELLSITE USING REAMER PERFORMANCE METRICS

Methods of performing a reaming operation at a wellsite are disclosed. The method involves measuring surface drilling parameters (e.g., surface torque and surface weight on bit) from surface sensors positioned about a rig, measuring downhole drilling parameters (e.g., downhole weight on bit and downhole torque) from downhole sensors positioned about a downhole tool, generating weight on reamer from the measured surface weight on bit and the measured downhole weight on bit, generating frictional torque by detecting from the surface sensors when the drilling tool is in a rotating off bottom state and selecting a portion of the measured surface torque measured during the rotating off bottom state, generating torque on reamer from the frictional torque, the downhole torque parameters, and the surface torque parameters, and detecting reamer performance by monitoring changes in reamer performance metrics (e.g., reamer aggressiveness) including integrated torque on reamer with weight on reamer. 1. A method of performing a reaming operation at a wellsite , the wellsite having a rig with a drilling tool deployed from the rig and advanced into a subterranean formation to form a wellbore , an underreamer carried by the drilling tool to expand the wellbore , the method comprising:measuring surface drilling parameters comprising surface torque and surface weight on bit from surface sensors positioned about the rig;measuring downhole drilling parameters comprising downhole weight on bit and downhole torque from downhole sensors positioned about the drilling tool;generating weight on reamer from the measured surface weight on bit and the measured downhole weight on bit;generating frictional torque by detecting from the surface sensors when the drilling tool is in a rotating off bottom state and selecting a portion of the measured surface torque measured during the rotating off bottom state;generating torque on reamer from the frictional torque, the downhole torque, and the surface ...

SYNTHETIC CORROSION LOGS THROUGH SUBSURFACE SPATIAL MODELING

Systems and methods include a computer-implemented method for generating synthetic corrosion logs. Processed corrosion log data is generated from historical corrosion logs of previously-drilled wells. A subset of the historical corrosion logs is selected, including selecting metal loss points to use as seed points for generating a corrosion model. The corrosion model is generated using the seed points, including using spatial interpolation to fill gaps between seed points. The corrosion model is validated by iteratively comparing seed logs and test logs to the corrosion model to ensure that the corrosion model fits the seed points within a threshold. A confidence interval is computed for each target location of a target well as a function of synthetic values associated with the seed points. A synthetic log is generated for the target well using the corrosion model, the target locations, and corresponding confidence intervals at each depth level of the target well. 1. A computer-implemented method , comprising:generating processed corrosion log data from historical corrosion logs of previously-drilled wells;selecting a subset of the historical corrosion logs from the processed corrosion log data, including selecting metal loss points from the subset to use as seed points for generating a corrosion model;generating the corrosion model using the seed points, including using spatial interpolation to fill gaps between seed points;validating the corrosion model by iteratively comparing seed logs and test logs to the corrosion model to ensure that the corrosion model fits the seed points within a threshold;computing a confidence interval for each target location of a target well as a function of synthetic values associated with the seed points; andgenerating a synthetic log for the target well using the corrosion model, the target locations, and corresponding confidence intervals at each depth level of the target well.2. The computer-implemented method of claim 1 , wherein ...

Method and System for Collecting and Managing Remote Sensor Data

A system, method, and device for monitoring one or more sensors at a remote location. The system allows a user to register multiple sensors to the user's account. When the sensors are deployed at a remote location for measuring various properties of their surrounding environments, they collect data which is then transmitted to a server. The user may then monitor the data by connecting to the server via a client device, and receive alerts when the data satisfies certain conditions. 1. A method for remote sensing of at least one property , comprising:disposing a sensor device in a location for sensing the at least one property, the sensor device including at least one sensor connected to a control module, and a power source;implementing a control module sleep/wake cycle;using the control module to receive, during a wake portion of the sleep/wake cycle, at least one signal from the at least one sensor, the at least one signal corresponding to a reading of the at least one property;using the control module to set a communication interval with a server, wherein the control module communicates the at least one reading to the server;maintaining the communication interval according to the wake portion of the sleep/wake cycle when an amount of power available from the power source is at or above a threshold amount;increasing the communication interval by a selected number of sleep/wakes cycles according to an amount of power available from the power source below a threshold amount;maintaining the control module receiving the at least one signal from the at least one sensor during the wake portion of the sleep/wake cycle, such that two or more readings are communicated to the server during an increased communication interval;wherein remote sensing of the at least one property is maintained at a resolution determined by the sleep/wake cycle.2. The method of claim 1 , comprising turning on communications circuitry only during a communication interval.3. The method of claim 1 , ...

SYSTEM AND METHOD FOR ESTIMATING CUTTING VOLUMES ON SHALE SHAKERS

A system for monitoring the volume of cuttings exiting a shaker table is disclosed. The system comprises a shaker table configured to be adjusted based on information compiled by a processor and at least one camera configured to monitor said shaker table. The camera may be operably connected to the processor. The processor may be configured to identify drill cuttings and estimate the volume of the cuttings exiting the shaker table using machine vision techniques. 1. A system for monitoring volume of drilling cuttings , the system comprising:a shaker table;a processor; andat least one camera configured to monitor said shaker table, wherein the camera is operably connected to the processor and wherein the processor is configured to identify drill cuttings and estimate the volume of the cuttings.2. The system of claim 1 , wherein the angle of the shaker table is automatically adjusted based on information compiled by the processor.3. The system of claim 1 , wherein the speed of the shaker table is automatically adjusted based on information compiled by the processor.4. The system of claim 1 , further comprising distance sensing equipment operably connected to the processor.5. The system of claim 1 , further comprising at least one sensor for detecting a predetermined parameter of a well circulatory system.6. The system of claim 1 , further comprising a well flow-in sensor claim 1 , flow-out sensor claim 1 , and pit volume sensor operably connected to the processor.7. The system of claim 1 , further comprising a light source arranged and designed to illuminate the shaker table during diverse weather conditions and times of day.8. The system of claim 1 , further comprising at least two cameras configured to provide stereo vision.9. The system of claim 1 , further comprising at least two cameras configured to monitor the shaker table from significantly different angles.10. The system of claim 1 , further comprising a bit-depth sensor operably connected to the processor.11 ...

DEVICE FOR THE POSITIONING OF AN ELECTRONIC UNIT ON A GROUND DRILLING DEVICE

A device for the positioning of an electronic unit on a front-end section of a drill string of a ground drilling device, wherein the electronic unit is designed to determine at least one of the following pieces of information: location, height, position and direction, and wherein the device has a seat for the electronic unit and a bearing surface adapted to the outer contour of the front-end section. 1. A device for the positioning of an electronic unit on a front-end section of a drill string of a ground drilling device , wherein the electronic unit is designed to determine at least one of the following pieces of information: location , height , position and direction , and wherein the device has a seat for the electronic unit and a bearing surface adapted to the outer contour of the front-end section.2. The device according to claim 1 , wherein the seat and the bearing surface are rigidly facing each other.3. The device according to claim 1 , wherein a magnet is provided on the bearing surface for interaction with the front-end section.4. The device according to claim 1 , wherein the bearing surface lies against the front-end section with no additional fixation.5. The device according to claim 1 , wherein the bearing surface comprises two substantially flat contact surfaces making an angle with each other.6. A system for orienting a front-end section of a drill string comprising the device according to claim 1 , and the front-end section of the drill string.7. A method for orienting a front-end section of a drill string of a ground drilling device claim 1 , wherein an electronic unit is positioned on the front-end section of the drill string from the outside claim 1 , the electronic unit ascertains and displays at least one piece of information on the orienting claim 1 , and the front-end section of the drill string is oriented by means of the information displayed by the electronic unit.8. A method for orienting a front-end section of a drill string of a ground ...

DEVICE, SYSTEM AND METHOD FOR CORRELATING CORE SAMPLE ZONES WITH ACTUAL SUBTERRANEAN DEPTH

Disclosed herein is a device and method for correlating core sample zones with an actual subterranean depth. The disclosed device has a pair of independent distance measuring devices operably in communication with a core sample apparatus where a first distance measuring device measures the length of a core sample entering a core sampling tube and a second distance measuring device measures a drive depth of the core sampling tube entering into the ground. A processing unit is provided for correlating the two distances so as to allow a determination as to the actual depth below ground from where a given zone of the core sample is extracted. 1. A device for correlating core sample zones with an actual subterranean depth comprising:a rig frame having a rig foot, with a rig foot aperture, operably coupled to a rig lower end thereof and a component mounting surface coupled near a rig upper end thereof;a core sampling tube and motor for imparting forces on said core sampling tube located within said rig frame, said core sampling tube being dependable through said rig foot aperture;a core sampling tube lowerer operable with said component mounting surface for lowering said core sampling tube downward so as to depend through said rig foot aperture;a first distance measuring device in communication with a core sampler puck, said core sampler puck being maintained within and movable along an internal length of said core sampling tube;a second distance measuring device in communication with an external point located near an upper end of the core sampling tube;the first distance measuring device for measuring a decreasing distance between said core sampler puck and said upper end and the second distance measuring device for measuring an increasing distance between the upper end and the component mounting surface as the core sampling tube is depended through the rig foot aperture into the ground and a core sample enters the core sampling tube;said decreasing distance and said ...

SPECTRAL GAMMA RAY DOWNHOLE LOGGING TOOL

A variety of applications can include a gamma ray downhole logging system having a gamma ray detector, where temperature sensitivity of the gamma ray detector is accounted for in the operation of the logging system. Correction of sensitivity of the gamma ray detector can include using a measure of sensitivity drift derived from temperature binned gamma ray spectra from measurements by the gamma ray detector over a calibration period for a number of calibration periods. Additional apparatus, systems, and methods are disclosed. 1. A gamma ray downhole logging system comprising:a gamma ray detector to measure gamma ray spectra;a temperature sensor to measure the temperature of the gamma ray detector;one or more processors;a memory having stored instructions, executable by the one or more processors, to perform operations, the operations including operations to make a correction of sensitivity of the gamma ray detector using a measure of sensitivity drift derived from temperature binned gamma ray spectra from measurements of the gamma ray spectra by the gamma ray detector over a calibration period for a number of calibration periods, including determining a change in the gamma ray spectrum between multiple temperature bins with each temperature bin assigned a range of temperatures.2. The system of claim 1 , wherein the operations include operations to make a correction of reversible temperature effect of sensitivity of the gamma ray detector using a temperature correction lookup table.3. The system of claim 1 , wherein the operations include operations to:record the measured gamma ray spectra as histograms of gamma ray pulse counts versus amplitudes of recorded gamma ray pulses over a measurement period; andrecord calibration spectra as two-dimensional histograms of counts of the recorded gamma ray pulses versus the amplitudes of the pulses and sensor temperature over the calibration period.4. The system of claim 3 , wherein the memory includes a non-volatile memory to ...

GENERATING A SCRIPT FOR PERFORMING A WELL OPERATION JOB

Examples of techniques for deployment risk management are disclosed. In one example implementation according to aspects of the present disclosure, a computer-implemented method may include: receiving, by a processing device, operating parameters for simulating a well operation job; simulating, by the processing device, the well operation job based on the operating parameters to generate a script for performing the well operation job, wherein the script comprises an ordered plurality of tasks and corresponding task parameters; and performing the well operation job based on the script generated by the simulation. 1. A computer-implemented method for deployment risk management , the method comprising:receiving, by a processing device, operating parameters for simulating a well operation job;simulating, by the processing device, the well operation job based on the operating parameters to generate a script for performing the well operation job, wherein the script comprises an ordered plurality of tasks and corresponding task parameters; andperforming the well operation job based on the script generated by the simulation.2. The method of claim 1 , wherein the operating parameters comprise a logging tool parameter claim 1 , a drilling fluid type parameter claim 1 , a cable type claim 1 , a cable load rating claim 1 , a wellbore geometry.3. The method of claim 1 , wherein receiving the operating parameters further comprises receiving well parameters.4. The method of claim 1 , wherein the corresponding task parameters comprise a task duration claim 1 , an elapsed time parameter claim 1 , a measured depth parameter claim 1 , a cable speed parameter claim 1 , a capstan state parameter claim 1 , a production rate parameter claim 1 , a wellhole pressure parameter claim 1 , and a surface weight parameter.5. The method of claim 1 , wherein the ordered plurality of tasks are identified by a task number.6. The method of claim 1 , wherein simulating the well operation job comprises ...

METHOD FOR EXPANSION OF MATURE BRINE WELLS IN SALT DOMES

A method for expanding a mature brine well cavern wherein the brine well comprises an existing casing extending from the surface into a cavern, an insoluble deposit at a bottom of the cavern, the method comprising an initial drilling operation including removing existing strings, if any, from the brine well; determining position and depth of the insoluble deposit; determining volume and depth of a salt formation present below the existing brine well; providing an outer drill string casing with sufficient length to penetrate the insoluble deposit and penetrate the salt formation; providing a drillable drill bit at a bottom end of the drill string casing to penetrate the insoluble deposit and salt lying under the insoluble deposit; drilling continuously through the insoluble deposit; and drilling into the salt formation is provided. 1. A method for mining a salt dome under the Earth's surface wherein the salt dome includes a mature brine well including an existing casing extending from the surface into an upper cavern , an insoluble deposit at a bottom of the upper cavern , and optionally , a sump for holding the insoluble deposit in whole or in part , the method comprising an initial drilling operation comprising the steps of:(1) removing existing seal fluids followed by removing existing hanging strings from the mature brine well;(2) determining from past and present sonars the top of, depth of, and volume of the insoluble deposit as it relates to the original total depth of the upper cavern;(3) drilling casing continuously through the insoluble deposit into a portion of the salt dome which underlies the mature brine well;(4) providing a rotating drill casing with a drillable drill bit and sufficient length to penetrate the insoluble deposit and penetrate into the salt under the upper cavern;(5) providing the rotating drill casing string with seal packer(s) to be placed in the newly drilled salt;(6) replenishing seal fluid in the upper cavern through drill casing ...

System for detecting and alerting drill depth based on designated elevation, strata and other parameters

A system for detecting and alerting drill depth based on designated elevation, strata, and other parameters includes an apparatus to observe one or more drill depths using an elevation and strata network, a processor to capture strata and other parameter information to calculate a drill depth based on data observations, and a communication device to communicate alerts based on desired drill depth. 1. A system for detecting and alerting drill depth based on designated elevation , strata , and other parameters comprising:one or more sensor nodes, each sensor node comprising either a flow sensor and/or pressure sensor within a drill depth location, each sensor node also incorporating a processing unit and a communications unit configured to transmit sensor observations to a processor node, wherein each of the sensors within the one or more nodes is pre-calibrated;the processor node is configured to integrate the sensor observations from multiple modalities to detect drill depth, the processor node comprising:a compression module configured to compress the sensor data provided by the one or more sensor nodes;a data analysis module configured to receive data from the compression module and to perform drill depth analysis of the data received from the compression module to create registered action;a location module configured to store gps coordinates from each registered actiona database configured to store registered actions from the compression module and to store all drill data, gps coordinates, and location module;a strata and elevation detection module configured to compare predefined observations to current observations received from the drill data analysis to detect strata and elevation of a defined interest;a filter module configured to select data that is of sufficient interest from the detected actions to generate an alert, wherein the selected actions are based upon at least one filter property; anda communication module configured to automatically communicate ...

Analysis/Visualization of a Well Drilling Window

A way to analyze/visualize the options available to safely and effectively drill an oil or gas well through a pore pressure/fracture gradient (drilling) window is presented. 1. An analysis/visualization of pressures existing and imposed within a wellbore during the drilling operation , such that the risks and consequences of actions and unknown values can be readily seen by all members of the drilling team. Specifically , a baseline of well pressure due to the mud density within the well (corrected for pressure and temperature) is established and (estimated or measured) pore pressures and fracture gradients depicted relative to this baseline in pressure units.2. A means whereby potential operational decisions and the impact of these decisions can be accurately , comprehensively and quickly assessed by members of the drilling team prior to such decisions being made , such that un-necessary risks can be avoided and such that mitigations to issues that arise during the drilling operation can be properly evaluated.3. A means whereby the impact and operation of a Managed Pressure Drilling (MPD) system can be readily visualized and controlled.4. A means whereby well pressures (relative to the static pressure caused by the mud density) can be plotted on the x-axis with either True Vertical Depth or Actual Measured Depth plotted on the y-axis. The ability to use Actual Measured Depth enables this approach to be very effective/applicable to horizontal or high angle wells. For horizontal wells , the plot may be rotated such that the user is far better visually connected to the orientation of the well.5. A means whereby (in real time) any well exposure to an underbalanced occurrence can be combined with knowledge of the well formations (for example , from LWD) and as a result be assessed and quantified , such that appropriate action can be taken.6. The application of this approach to all wells , not just wells such as those shown in the examples. This new analysis/ ...

DOWNHOLE SENSOR, ULTRASONIC LEVEL SENSING ASSEMBLY, AND METHOD

A downhole sensor including a body configured for attachment to a downhole pump. The body having a fluid receiving portion; and, an ultrasonic transducer supported by the body; wherein ultrasonic pulses transmitted by the ultrasonic transducer are directed towards the fluid receiving portion, and reflected waves receivable by the ultrasonic transducer are indicative of a liquid fluid level and type of fluid within the fluid receiving portion. A method of determining a liquid fluid level and a type of fluid adjacent a downhole pump. 1. A downhole sensor comprising:a body configured for attachment to a downhole pump, the body having a fluid receiving portion; and,an ultrasonic transducer supported by the body;wherein ultrasonic pulses transmitted by the ultrasonic transducer are directed towards the fluid receiving portion, and reflected waves receivable by the ultrasonic transducer are indicative of a liquid fluid level and type of fluid within the fluid receiving portion.2. The downhole sensor of claim 1 , wherein a liquid fluid level within the fluid receiving portion is substantially same as a liquid fluid level exterior to the fluid receiving portion.3. The downhole sensor of claim 1 , further comprising a housing configured to allow fluid entry into and exit from the fluid receiving portion claim 1 , and configured to prevent particulates from entering the fluid-receiving portion.4. The downhole sensor of claim 3 , wherein the housing is perforated.5. The downhole sensor of claim 3 , wherein the housing is a multi-layer structure including an inner apertured tubular and an outer wrapping screen.6. The downhole sensor of claim 1 , wherein the body includes a wave guide claim 1 , the wave guide including the fluid receiving portion claim 1 , a reference portion claim 1 , and a reflection portion claim 1 , wherein the fluid receiving portion and the reference portion are disposed between the ultrasonic transducer and the reflection portion.7. The downhole sensor of ...

COMPUTER-IMPLEMENTED IMPACT ANALYSIS OF ENERGY FACILITIES

A data processing method for execution using a programmed computer to generate an objective score value specifying an estimated impact of an oil or gas processing operation comprises: receiving a plurality of data associated with the oil or gas processing operation; identifying, using the plurality of data, a plurality of events that may occur during the oil or gas processing operation; for each event of the plurality of events, determining a relative weighting of potential impact of the event for the oil or gas processing operation using local conditions and a master event profile for the event; for each event of the plurality of events, determining an effectiveness of one or more control efforts; for each event of the plurality of events, determining a score using the relative weighting of the potential impact of the event and the effectiveness of the one or more control efforts; determining the objective digitally stored score value for the oil or gas processing operation using the score for each event of the plurality of events and benchmarking the objective digitally stored score value to a plurality of objective digitally stored score values for other oil or gas processing operations. 1. A data processing method for execution using a programmed computer to generate a digitally stored objective score value specifying an estimated impact of an oil or gas processing operation on safety , health , production efficiency or economics , the method comprising:receiving a plurality of digital data associated with the oil or gas processing operation;identifying, using the plurality of data, a plurality of events that may occur during the oil or gas processing operation and storing digital data representing the plurality of events;for each event of the plurality of events, using a first programmed algorithm, determining a relative weighting of potential impact of the event on safety, health, production efficiency or economics for the oil or gas processing operation using ...

NON-OBTRUSIVE METHODS OF MEASURING FLOWS INTO AND OUT OF A SUBSEA WELL AND ASSOCIATED SYSTEMS

A fluid level monitoring system comprising: a subsea well comprising a wellbore and a wellhead; a subsea well isolation device installed on the wellhead; and a fluid level monitoring device and associated methods. 1. A fluid level monitoring system comprising:a subsea well comprising a wellbore and a wellhead;a subsea well isolation device installed on the wellhead; anda fluid level monitoring device.2. The fluid level monitoring system of claim 1 , wherein the fluid level monitoring device comprises a mud-line wellbore differential pressure monitoring device.3. The fluid level monitoring system of claim 2 , wherein the mud-line wellbore differential pressure device comprises one or more pressure gauges.4. The fluid level monitoring system of claim 2 , further comprising a wellhead remote visual monitoring device claim 2 , a constant level subsea pump system claim 2 , and a subsea control module.5. The fluid monitoring system of claim 2 , further comprising an umbilical flow conduit claim 2 , a subsea control system umbilical claim 2 , and a surface operating unit.6. The fluid level monitoring system of claim 1 , wherein the fluid level monitoring device comprises a mud-line wellbore pressure monitoring device.7. The fluid level monitoring system of claim 6 , wherein the mud-line wellbore pressure device comprises one or more pressure gauges.8. The fluid level monitoring system of claim 6 , further comprising a wellhead remote visual monitoring device claim 6 , a constant level subsea pump claim 6 , and a subsea control module.9. The fluid monitoring system of claim 6 , further comprising an umbilical flow conduit claim 6 , a subsea control system umbilical claim 6 , and a surface operating unit.10. The fluid level monitoring system of claim 1 , wherein the fluid level monitoring device comprises one or more resistance temperature detectors.11. The fluid level monitoring system of claim 10 , wherein the fluid level monitoring device comprises a temperature source ...

Constructing survey programs in drilling applications

A computing system, non-transitory computer-readable medium, and a method for surveying a wellbore. The method includes receiving a first survey of the wellbore from a first survey tool, receiving a second survey of the wellbore form a second survey tool, determining a first uncertainty of the first survey tool and a second uncertainty of the second survey tool, determining a first growth rate of the first uncertainty and a second growth rate of the second uncertainty, and generating a combined survey based at least partially on the first and second growth rates.

TVD CORRECTED GEOSTEER

A method for determining a total vertical depth (TVD) for a well plan involves measuring differences between a projected BHA position at a depth of a survey station and a calculated BHA position based upon a minimum curvature method at the depth of the survey station. The differences are accumulated at each survey station with respect to the BHA position. Real time TVD corrected gamma logs are generated responsive to the accumulated differences of the BHA position. 1. A method for determining a total vertical depth (TVD) for a well comprising:measuring differences between a projected BHA position at a depth of a survey station and a calculated BHA position based upon a minimum curvature method at the depth of the survey station;accumulating the differences at each survey station with respect to the BHA position; andgenerating real time TVD corrected gamma logs responsive to the accumulated differences of the BHA position.2. The method of claim 1 , further comprising:receiving at least one of continuous inclination readings or continuous azimuth readings relating to a BHA position;comparing the received at least one of the continuous inclination reading or continuous azimuth reading relating to the BHA position to projected results between survey stations.3. The method of further including the step of mapping additional location points between the survey stations responsive to the continuous inclination readings or continuous azimuth readings relating to BHA position.4. The method of claim 1 , wherein the step of accumulating further comprises continuously updating survey projections of the BHA position based on the detected differences.5. The method of further including improving an accuracy of the TVD and azimuthal placement of the BHA responsive to the real time TVD corrected gamma logs.6. The method of claim 1 , wherein the step of generating the real time TVD corrected gamma logs further comprises determining a true vertical depth of the BHA at location points ...

LOCATING MULTIPLE WELLBORES

Methods and systems are described that can be used for locating conductive bodies such as wellbore casing or piping disposed below the earth's surface. An electrical current can be excited in a conductive body in each wellbore in a given area to produce a magnetic field, and the magnetic field can be detected by a ranging tool. Location and current parameters can be determined for an estimated number of wellbores producing non-negligible contributions to the magnetic field, and the estimated number of wellbores can be adjusted until the number of contributing wellbores is determined. Location solutions can be returned for each of the contributing wellbores, and the location solutions can be employed to facilitate exploration of drilling applications such as well avoidance, well intersection and/or steam assisted gravity drainage (SAGD) steering operations. 1. A method of locating multiple wellbores , comprising:exciting a first electrical current in a first wellbore;exciting a second electrical current in a second wellbore;disposing a ranging tool at a remote location with respect to the first and second wellbores;receiving and detecting a magnetic field at the remote location with receivers provided on the ranging tool; andmeasuring at least one wellbore parameter of each of the first wellbore and the second wellbore from the magnetic field received by the ranging tool.2. The method of claim 1 , wherein the at least one wellbore parameter comprises at least one of the group consisting of the first electrical current claim 1 , the second electrical current claim 1 , a distance of either of the first and second wellbores from the receivers claim 1 , azimuth angle of either of the first and second wellbores claim 1 , and an orientation of first and second wellbores.3. The method of claim 2 , wherein the at least one wellbore parameter comprises at least one of the first current and the second current.4. The method of claim 1 , further comprising determining that the ...

GRADE MANAGEMENT SYSTEM FOR AN IMPLEMENT

A grade management system configured to control a depth of a dig includes a vehicle including an arm assembly coupled to an implement, the implement configured to dig into a surface, and an implement position sensor coupled to the arm assembly, the implement position sensor configured to detect a position of the implement relative to the vehicle, wherein in response to digging into the surface with the implement, detecting the position of the implement relative to the vehicle and determining whether any portion of the implement reaches a targeted depth into the surface. 1. A grade management system configured to control a depth of a dig , the system comprising:a vehicle including an arm assembly coupled to an implement, the implement configured to dig into a surface; andan implement position sensor coupled to the arm assembly, the implement position sensor configured to detect a position of the implement relative to the vehicle, wherein in response to digging into the surface with the implement, detecting the position of the implement relative to the vehicle and determining whether any portion of the implement reaches a targeted depth into the surface.2. The grade management system of claim 1 , further comprising comparing the detected position of the implement relative to the vehicle to a calculated position of the implement relative to the vehicle representative of the targeted depth of the dig into the surface.3. The grade management system of claim 1 , wherein the implement includes an auger.4. The grade management system of claim 3 , wherein the auger includes an auger length used to detect the position of the auger relative to the vehicle.5. The grade management system of claim 1 , wherein the vehicle is one of a compact track loader or a skid steer6. The grade management system of claim 1 , wherein the implement position sensor assembly includes at least one of a cylinder position sensor claim 1 , a pin rotation sensor claim 1 , or an inertial measurement ...

METHODS FOR CHARACTERIZING MULTI-STRING CASED WELLS USING WIDE FREQUENCY BANDWIDTH SIGNALS

Methods are provided for estimating a quality of cement in the annuli of a multi-string wellbore. Wideband acoustic energy signals are generated and detected in the wellbore and are processed to obtain indications of wideband casing-formation phase slowness dispersions in the wellbore. The indications are compared to reference wideband model casing-formation phase slowness dispersions in order to estimate status of cement or lack of cement in the annuli at that location based on the results of the comparison. 1. A method of characterizing the annuli of a multi-string wellbore , comprising:utilizing at least one tool in the wellbore to excite wideband acoustic energy and detect resulting wideband signals at a location in the wellbore;processing the detected wideband signals to obtain indications of wideband casing-formation phase slowness dispersions in the wellbore;comparing the indications of wideband casing-formation phase slowness dispersions in the wellbore to reference wideband model casing-formation phase slowness dispersions; andestimating status of cement or lack of cement in the annuli at said location based on said comparing.2. The method of claim 1 , wherein said wideband signals include a range of at least 5 kHz to 70 kHz.3. The method of claim 1 , wherein said wideband signals range from at least 5 kHz to 100 kHz.4. The method of claim 1 , wherein said wideband signals range from at least 1 kHz to 100 kHz.5. The method of claim 1 , wherein said comparing comprises comparing indications of wideband casing-formation phase slowness dispersions in the wellbore to sets of a plurality of reference wideband model casing-formation phase slowness dispersions claim 1 , each set of said sets being for a different wellbore configuration.6. The method of claim 5 , wherein said sets include a water-inner metal-inner cement-outer metal-outer cement-formation configuration claim 5 , a water-inner metal-water-outer metal-cement-formation configuration claim 5 , a water- ...

System for determining position of marker depth coordinates for construction of geological model of deposit

A system for building a geological model of oil or other mineral deposit. In particular, the system allows the coefficients of correlation to be determined for a set of well-logging curves and marker depth positions to be established for which the values of correlation coefficient are maximal. A technical result is the improvement of the accuracy of evaluating the parameters that are used to construct a geological model of location of oil or other deposits. The system makes it possible, given a marker, which already has its marks in a group of wells, which is referred to as reference group, to calculate such marks for wells from another group. For any well W where the marker depth is to be determined, wells from the reference group are chosen lying within the specified distance from the well W, and a well with the maximal coefficient of correlation is chosen among them.

SYSTEMS AND METHODS FOR DETERMINING POSITION OF MARKER DEPTH COORDINATES FOR CONSTRUCTION OF GEOLOGICAL MODEL OF DEPOSIT

The invention relates to the method, device, and a machine-readable data carrier used for building a geological model of oil or other mineral deposit. In particular, the invention refers to the method, device, and machine-readable data carrier used for determining the position of marker depth coordinates in wells W from a reference group of wells at the building of a geological model. A technical result is the improved accuracy of the evaluation of parameters used in the building of a geological model describing the location of oil or other deposits. The invention makes it possible, for markers chosen as an initial solution, to calculate the marker depth in each well to maximize the total correlation. For each marker in the set, a functional is defined as the sum of correlation coefficients of a set of well-logging methods for pairs of wells located within a specified distance from one another. 1. A computer-implemented method for determining a position of coordinates of a marker depth in well W for building of a geological model of a deposit , the computer-implemented method comprising:1) determining wells W and wells located within a specified neighborhood of the well W, the radius of the neighborhood being R;{'sub': 'i', '2) determining the values of the mark of marker depth {z}, i=0, . . . , n in each well W and in wells located within a specified neighborhood of the well;'}{'sub': 'i', '3) evaluating the functional C in points where the value of marker depth {z} is known;'}{'sub': 'i', '4) composing gradient vectors in points where the value of marker depth {z} is known;'}5) smoothing the gradient vector by replacing each component of the gradient vector in the well W by the mean value of components of gradient vector in wells in the neighborhood with radius R;{'sub': i', 'i, '6) searching for a value of the functional C greater than the previously found value of the functional C within a segment of specified length starting from the marker depth mark {z} in ...

AUTONOMOUS LOGGING-WHILE-DRILLING ASSEMBLY

The present application pertains to a self-powered logging-while-drilling assembly. The assembly has a body comprising a releasable hatch and a battery within said body configured to power the assembly. A memory and/or processor may be employed with a resistivity micro-imager and/or a spectral gamma sensor. 1. A self-powered logging-while-drilling assembly comprising:a body comprising a releasable hatch;an electronic chassis within said body;a battery within said body configured to power the assembly; anda resistivity micro-imager; anda memory for recording data.2. The self-powered logging-while-drilling assembly of wherein the resistivity micro-imager is configured to identify fracture size wherein said resistivity microimager comprises a guard electrode and two or more imaging electrodes.3. The self-powered logging-while-drilling assembly of further comprising a magnetometer within the electronic chassis.4. The self-powered logging-while-drilling assembly of further comprising an accelerometer within the electronic chassis.5. The self-powered logging-while-drilling assembly of wherein the assembly is configured to acquire a high side tool face angle for imaging a deviated well.6. The self-powered logging-while-drilling assembly of wherein the battery is a lithium battery.7. The self-powered logging-while-drilling assembly of wherein the self-powered logging-while-drilling assembly is configured to synchronize with a measurement-while-drilling system for depth correlation.8. The self-powered logging-while-drilling assembly of wherein the self-powered logging-while-drilling assembly is configured to acquire a high side tool face angle for imaging of a deviated well.9. The self-powered logging-while-drilling assembly of wherein the self-powered logging-while-drilling assembly is configured to synchronize with a tool clock.10. The self-powered logging-while-drilling assembly of further comprising a data port to download data from the memory.11. The self-powered ...

METHOD OF REMOVING WELLBORE FLUID FROM WELL AND WATER REMOVAL WELL

A method for removal of fluid from a subterranean formation is provided, the method including the steps of: providing a wellbore from the surface to within the formation: providing a pump in the wellbore capable of removing fluid from the wellbore to a surface location; establishing a pump performance function as pump curves; measuring at least one variable that establishes where the pump is operating on the pump curve; determining the differential pressure across the pump from the measured variable and the digital power and the flow rate; determining the suction side pressure from the differential pressure across the pump and the vertical height of the annular fluid column of the fluid column above the pump; determining the suction side fluid level from the suction side pressure and the fluid density. 1. A method for removal of fluid from a subterranean formation comprising the steps of:providing a wellbore from the surface to within the formation:providing a pump in the wellbore capable of removing fluid from the wellbore to a surface location;establishing a pump performance function as pump curves;measuring at least one variable that establishes where the pump is operating on the pump curve;determining a differential pressure across the pump from the at least one measured variable;determining a pressure of liquid pumped by the electric driven pump at a know height of the annular fluid column above the suction of the electric driven pump;determining a height of the annular fluid column of liquid above the suction of the pump from the differential pressure across the pump, the know height of the annular fluid column above the suction of the electric driven pump, and the pressure of liquid pumped by the electric driven pump at a know height of the annular fluid column above the suction of the electric driven pump.2. The method of further comprising the step of selecting a target height of the annular fluid column of liquid above the suction of the pump to which the ...

Systems and Methods for Vertical Depth Control During Extended-Reach Drilling Operations

Systems and methods for vertical depth control during extended-reach drilling operations include extending a length of a wellbore to locate a directional drilling assembly at a selected location within an intermediate portion of a subsurface region and detecting a detected pressure at the selected location. The methods further include determining an expected pressure at the selected location, comparing the detected pressure to the expected pressure, and adjusting an orientation of the directional drilling assembly based, at least in part, on the comparison. The expected pressure may be determined based, at least in part, on a reference pressure that was detected previously within the intermediate portion of the subsurface region. The systems include extended-reach drilling operations and/or directional drilling assemblies that include and/or are associated with controllers that are programmed to perform the methods. 2. The method of claim 1 , wherein the method further includes detecting the reference pressure.3. The method of claim 2 , wherein the wellbore is a second wellbore claim 2 , and further wherein the detecting the reference pressure includes detecting the reference pressure within a first wellbore that extends within the intermediate portion of the subsurface region claim 2 , wherein the first wellbore is spaced apart from the second wellbore.4. The method of claim 2 , wherein the detecting the reference pressure includes detecting the reference pressure at a reference location within the intermediate portion of the subsurface region claim 2 , and further wherein the method includes determining a reference depth of the reference location.5. The method of claim 2 , wherein the detecting the reference pressure includes detecting a plurality of reference pressures at a plurality of reference locations within the intermediate portion of the subsurface region claim 2 , and further wherein the method includes determining a plurality of reference depths of the ...

SYSTEMS, DEVICES, AND METHODS FOR GENERATING DRILLING WINDOWS

Systems, devices, and methods for visualizing and steering a drilling apparatus are provided, including a drill string with a bottom hole assembly (BHA), a sensor system, and a controller operable to generate a visualization comprising one or more drilling windows representing drilling tolerances of a drill plan of the drilling operation and a depiction of a location of the BHA based on the one or more measurable parameters of the drilled wellbore. The differences between the location of the BHA and the one or more drilling windows may also be visualized. This visualization may be used by an operator to steer the drilled wellbore. 1. A method of directing the operation of a drilling system , comprising:generating, with a controller, one or more drilling windows around a portion of a drill plan, each of the one or more drilling windows having an outer boundary;drilling with a bottom hole assembly comprising a bit disposed at an end of a drill string to create a drilled bore;receiving sensor data from one or more sensors adjacent to or carried on the bottom hole assembly;determining, with the controller, a position of the bottom hole assembly based on the received sensor data;determining, with the controller, whether the determined position of the bottom hole assembly is within the outer boundary of the one or more drilling windows; anddisplaying, on a display device, the position of the bottom hole assembly relative to the one or more drilling windows.2. The method of claim 1 , further comprising using the position of the bottom hole assembly relative to the one or more drilling windows as a reference to change the position of the bottom hole assembly.3. The method of claim 2 , further comprising generating claim 2 , with the controller claim 2 , a corrective action to move the bottom hole assembly into the one or more drilling windows if the controller determines that the bottom hole assembly is not within the outer boundary of the one or more drilling windows.4. ...

CASING DETECTION TOOLS AND METHODS

Methods and tools for detecting casing position downhole is presented. The method utilizes electromagnetic (EM) tools with tilted antenna systems to detect casing position. Sometimes titled antenna designs also increase EM tools' sensitivity to formation parameters, which can lead to false signals for casing detection. In addition, it is very difficult to distinguish measured signals between a casing source and a formation source. The methods presented help to distinguish between the two sources more clearly. The methods and tools presented also help to minimize those environmental effects, as well as enhance the signals from a surrounding conductive casing. The methods herein provide ideas of EM tool's design to precisely determine casing position within a certain distance to casing position. 1. A method comprising:obtaining formation resistivity measurements from a borehole;determining an expected environmental signal level for the borehole based, at least in part, on the formation resistivity measurements;selecting at least one of a transmitter-receiver spacing and an operating frequency to provide a casing detection signal level for the borehole which is greater than the expected environmental signal level; andproviding a tilted antenna logging tool having the selected transmitter-receiver spacing and/or operating frequency in a bottomhole assembly for the borehole.2. The method of claim 1 , wherein the casing detection signal level is less than ten times the expected environmental signal level.3. The method of claim 1 , wherein the borehole is cased before obtaining the formation resistivity measurements from the borehole.4. The method of claim 1 , wherein the tilted antenna logging tool comprises antenna modules that can be separated by a variable number of intervening subs.5. The method of claim 1 , wherein the tilted antenna logging tool has a programmable operating frequency.6. The method of claim 1 , wherein the expected environmental signal level includes ...

OPPORTUNISTIC SENSOR FUSION ALGORITHM FOR AUTONOMOUS GUIDANCE WHILE DRILLING

Described is a system for estimating a trajectory of a borehole. The system processes signals of sensor streams obtained from an inertial sensor system. Using the set of processed signals, the system determines whether a drill is in a survey mode state or a continuous mode state, and a measured depth of the borehole is determined. A set of survey mode positioning algorithms is applied when the drill is stationary. A set of continuous mode navigation algorithms is applied when the drill is non-stationary. Using at least one Kalman filter, results of the set of survey mode positioning algorithms and the set of continuous mode navigation algorithms are combined. An estimate of a borehole trajectory and corresponding ellipse of uncertainty (EOU) is generated using the combined results. 1. A system for estimating a trajectory of a borehole for drilling , the system comprising:an inertial sensor system; and processing signals of sensor streams obtained from the inertial sensor system, resulting in a set of processed signals;', 'using the set of processed signals, determining whether a drill is in a survey mode state or a continuous mode state;', 'using the set of processed signals, determining a measured depth of the borehole;', 'applying a set of survey mode positioning algorithms to the set of processed signals when the drill is stationary;', 'applying a set of continuous mode navigation algorithms to the set of processed signals when the drill is non-stationary;', 'using at least one Kalman filter, combining results of the set of survey mode positioning algorithms and the set of continuous mode navigation algorithms; and', 'generating an estimate of a borehole trajectory and corresponding ellipse of uncertainty (EOU) using the combined results., 'one or more processors and a non-transitory computer-readable medium having executable instructions encoded thereon such that when executed, the one or more processors perform operations of2. The system as set forth in claim 1 ...

System and Method for Determining Pump Intake Pressure or Reservoir Pressure in an Oil and Gas Well

A system and method are described to determine a pump intake pressure in a petroleum producing well. The system includes a controller at a well site of the petroleum producing well, a system of valves connected to pipes collecting the well casing gas produced from a casing annulus of the producing well. The valves are controlled by the controller and a pressure sensor measures the pressure of the well casing gas in the casing annulus. The system determines a well casing gas flow rate by measuring a build-up pressure of the well casing gas in a casing annulus when a valve from the casing annulus is closed. A fluid level in the casing of the well is determined using a pressure wave created in the well casing gas using the controller and the one or more valves. A fluid gradient correction factor is found using an actual fluid level in the casing. The controller then calculates the pressure using the gas flow rate, the fluid level and the fluid gradient correction factor. 1. A method for calculating a pressure at a producing well having a fluid level and a well casing gas , the method comprising:determining a well casing gas flow rate at the surface of the well by measuring a well casing gas build up pressure in a casing annulus when a valve from the casing annulus is closed;determining a fluid level in a casing of the well from the surface using a pressure wave created in the well casing gas;determining a fluid gradient correction factor using an actual fluid level in the casing; andcalculating the pressure using the well casing gas flow rate, the fluid level and the fluid gradient correction factor.2. The method of claim 1 , wherein the pressure is a pump intake pressure.3. The method of claim 1 , wherein the pressure is at any datum in the well.4. The method of claim 1 , wherein the well casing gas flow rate is determined from a plurality of well casing gas flow rate measurements taken over a period of time.5. The method of claim 1 , wherein determining the well ...

WELLBORE DRILLING

A method of issuing notifications for controlling drilling of a wellbore involves receiving real sensor data from the drilling rig and modelling the drilling of the wellbore by the drilling rig using a mathematical model. Modelled sensor data is extracted from the mathematical model and the real sensor data is analysed using the modelled sensor data. Notifications are generated based on the analysis. 1. A computer-implemented method of issuing notifications for controlling drilling of a wellbore by a drilling rig , the method comprising:receiving real sensor data from the drilling rig;modelling the drilling of the wellbore by the drilling rig using a mathematical model and extracting modelled sensor data from the mathematical model;analysing the real sensor data using the modelled sensor data;generating notifications based on the analysis.2. The computer-implemented method of claim 1 , wherein the real sensor data relates to one or more of a list comprising:drill string torque;pump rate;hook load;down-hole pressure;stand pipe pressure; andmud pit level.3. The computer-implemented method of claim 1 , comprising determining friction in different parts of the drilling rig and providing the determined friction for each different part of the drilling rig as the real sensor data.4. The computer-implemented method of claim 1 , comprising filtering the real sensor data to remove real sensor data relating to the drilling rig performing anomalous operations.5. The computer-implemented method of claim 4 , wherein the real sensor data relating to the drilling rig performing anomalous operations is one or more of a list comprising:drill string torque when a drill string of the drilling rig is held in slips;drill string torque when a drill bit of the drilling rig is at less than a predetermined depth in the wellbore; andstand pipe pressure when flow rate in the stand pipe in less than a predetermined flow rate.6. The computer-implemented method of claim 4 , wherein the real ...

METHOD AND SYSTEM FOR OPERATING A DRILLING PLANT

A method for analyzing a drilling operation includes obtaining a first set of logged operational data from the drilling operation through a first time interval, obtaining a set of operational activity dividers that delimit second time intervals within the first time interval, allocating one of a plurality of pre-defined activities to each of the second time intervals, wherein a first activity is one of the plurality of pre-defined activities, calculating a first performance indicator parameter for the second time intervals which have been allocated to the first activity, generating a time-dependent profile of the first performance indicator parameter for the second time intervals, and outputting at least one calculated value of the first performance indicator parameter to an operator. The first performance indicator parameter is calculated as a function of a duration of a respective second time interval which has been allocated to the first activity. 151-. (canceled)52. A method for analyzing a drilling operation , the method comprising:obtaining a first set of logged operational data from the drilling operation through a first time interval;obtaining a set of operational activity dividers that delimit a plurality of second time intervals within the first time interval;allocating one of a plurality of pre-defined activities to each of the plurality of second time intervals, wherein a first activity is one of the plurality of pre-defined activities;calculating a first performance indicator parameter for the plurality of second time intervals which have been allocated to the first activity, the first performance indicator parameter being calculated as a function of a duration of a respective one of the plurality of second time intervals which has been allocated to the first activity;generating a time-dependent profile of the first performance indicator parameter for the plurality of second time intervals; andoutputting at least one calculated value of the first ...

Active control method and control device for wellbore pressure in the open-cycle drilling of marine natural gas hydrates

An active control method and control device for wellbore pressure in the open-cycle drilling of marine natural gas hydrates comprises following steps: (1) optimized design of drilling parameter; (2) carry out open-cycle drilling according to the designed drilling parameters; (3) utilize the APWD to monitor the bottom-hole temperature and the bottom-hole pressure in real time for real-time correction of the wellbore annulus temperature and pressure calculation models; determine whether a hydrate decomposition has occurred in the annulus and then infer whether a shallow gas intrusion has occurred in the bottom hole; (4) Intelligent active control: control and adjust the mixed density of drilling fluid, the injection displacement of drilling fluid as well as the injection temperature of drilling fluid and the pump pressure in wellhead automatically during the well killing based on the real-time treatment results of the computer terminal for the signal fluctuations detected by the APWD. 1. An active control method for wellbore pressure in the open-cycle drilling of marine natural gas hydrates , which comprises steps as follows:(1) optimized design of drilling parameters: design the drilling fluid displacement, pump pressure in wellhead, and injection temperature of drilling fluid during the drilling through calculations based on the data of the marine NGH reservoirs to be drilled;(2) open-cycle drilling: carry out open-cycle drilling according to the drilling parameters designed in step (1) by injecting seawater into the drill pipe as drilling fluid to carry the cuttings from the bottom hole and discharge them out of the subsea wellhead through the annulus between the drill pipe and the casing pipe;(3) real-time monitoring of drilling: utilize the APWD to monitor the bottom-hole temperature and the bottom-hole pressure in real time for real-time correction of the wellbore annulus temperature and wellbore annulus pressure calculation models; determine whether a hydrate ...

Estimating Inspection Tool Velocity and Depth

A method for determining a corrected axial displacement parameter of a conduit inspection tool, in particular a downhole inspection tool, during transit of the tool axially along a conduit is disclosed. The tool used in the method has an imaging device and may be attached to a control module with a connecting line. The method comprises obtaining successive axially overlapping images of an internal wall of the conduit, determining, from the images, an observed axial displacement parameter of the tool as a function of transit time, identifying, in the images, a plurality of reference points, determining an estimated axial displacement parameter of the tool over an of transit time between successive reference points, and computing the corrected axial displacement parameter of the tool by applying a correction factor to the observed axial velocity of the tool. 1. A method for determining a corrected axial displacement parameter of a conduit inspection tool having an imaging device , the method comprising:obtaining, using the imaging device, successive axially overlapping images of an internal wall of a conduit during transit of the tool axially along the conduit;determining, from the images, an observed axial displacement parameter of the tool as a function of transit time;identifying, in the images, a plurality of reference features of fixed position in the conduit and corresponding reference points comprising transit times at which said reference features appear;determining an estimated axial displacement distance of the tool over an interval of transit time between successive reference points; andcomputing the corrected axial displacement parameter of the tool by applying a correction factor to the observed axial displacement parameter;wherein the correction factor is determined such that, within the interval of transit time between successive reference points, a total axial displacement distance of the tool determined from the corrected axial displacement parameter ...

AUTOMATED WASH SYSTEMS FOR A PROGRESSING CAVITY PUMP SYSTEM

An automated wash system for use with a progressing cavity (PC) pump system. The automated wash system includes a wash fluid source and a wash valve. The wash valve is in fluid communication with the wash fluid source and an annulus of a well casing of the PC pump system and is operably coupled to the controller. Upon receipt of a command to initiate a wash cycle, the controller opens the wash valve to enable wash fluid to be directed into the annulus and increases a speed of a PC pump of the PC pump system to effect cleaning of the well casing. 1. An automated wash system for use with a progressing cavity (PC) pump system , the PC pump system having a well casing with an annulus , a progressing cavity (PC) pump disposed within the well casing , a motor operatively coupled to the PC pump , a controller operatively coupled to the motor , and a gas flow valve in communication with the annulus and operatively coupled to the controller , the automated wash system comprising:a wash fluid source; anda wash valve in fluid communication with the wash fluid source and the annulus of the well casing, the wash valve adapted to control the flow of wash fluid between the wash fluid source and the annulus, the wash valve adapted to be operatively coupled to the controller;wherein, upon receipt of a command to initiate a wash cycle, the controller closes the gas flow valve, opens the wash valve to enable wash fluid from the wash fluid source to be directed into the annulus, and increases a speed of the PC pump via a signal to the motor to effect cleaning of the well casing.2. The system of claim 1 , further comprising a pump for pressuring wash fluid in the wash fluid source claim 1 , the pump disposed downstream the wash fluid source.3. The system of claim 2 , wherein the pump is operatively coupled to the controller claim 2 , such that the pump is controlled by the controller via a signal.4. The system of claim 1 , further comprising a flow meter disposed downstream the wash ...

SYSTEM AND METHOD OF DRILLING A WELLBORE TO A TARGET

A system and method of drilling a wellbore to a target may include measuring attitudes at two adjacent survey stations along a wellbore using a downhole surveying tool. An actual change in wellbore position over a survey leg linking the two survey stations may be determined. Corrections may be applied to the measured attitude at one or both of the survey stations such that an estimated well path joining the survey stations indicates the determined actual change in wellbore position between the two survey stations. 1. A system , comprising:a processor; and measuring attitudes at two adjacent survey stations along a wellbore using a downhole surveying tool;', 'determining an actual change in wellbore position over a survey leg linking the two survey stations; and', 'applying corrections to the measured attitude at one or both of the survey stations and determining an estimated well path joining the adjacent survey stations, wherein the estimated well path indicates the actual change determined in the wellbore position over the survey leg, and wherein the estimated well path is a circular arc computed by a minimum curvature method., 'memory media accessible to the processor storing instructions executable by the processor for drilling a wellbore to a target, the instructions comprising instructions for2. The system of claim 1 , wherein determining the actual change in the wellbore position further comprises determining the actual change using continuous survey measurements taken at least between the two adjacent survey stations during drilling of the wellbore.3. The system of claim 1 , wherein determining the actual change in wellbore position comprises determining the actual change using continuous inclination angle measurements taken at least between the two adjacent survey stations during drilling of the wellbore.4. The system of claim 1 , wherein determining the actual change in wellbore position comprises determining the actual change using depths and toolface ...

BASEMENT ROCK HYBRID DRILLING

A method for monitoring and controlling a downhole pressure of a well during formation of a borehole of a well is provided. The method can include monitoring a downhole pressure of a well during formation of a borehole of the well using a millimeter wave drilling apparatus including a waveguide configured for insertion into the borehole. The monitoring can include determining the downhole pressure. The downhole pressure can include an amount of pressure present at a bottom of the well. The method can also include determining a lithostatic pressure of rock surrounding the well at the bottom of the well. The method can further include controlling the downhole pressure relative to the lithostatic pressure of the rock surrounding the well at the bottom of the well. Related systems performing the methods are also provided.

BASEMENT ROCK HYBRID DRILLING

A system for monitoring borehole parameters and switching to millimeter wave drilling based on the borehole parameters is provided. The system can include a mechanical drilling apparatus for forming a first portion of a borehole of a well. The first portion of the borehole can be formed based on a permeability of the first portion of the borehole and a temperature within the first portion of the borehole. The system can also include a millimeter wave drilling apparatus configured to inject millimeter wave radiation energy into a second portion of the borehole of the well via a waveguide. The second portion of the borehole can be formed via the millimeter wave drilling apparatus in response to determining the permeability of the first portion of the borehole is below a permeability threshold value and the temperature within the first portion of the borehole exceeds a temperature threshold value.

BASEMENT ROCK HYBRID DRILLING

A system for monitoring and controlling downhole pressure of a well borehole relative to a lithostatic pressure of rock surrounding the borehole is provided. The system can include a millimeter wave drilling apparatus including a gyrotron configured to inject millimeter wave radiation energy into a borehole of a well via a waveguide configured for insertion into the borehole. The borehole can be formed via the millimeter wave drilling apparatus and having a downhole pressure monitored at a bottom of the well. The system can also include a compressor fluidically coupled to the borehole and configured to control the downhole pressure via a gas supplied into and/or received from the borehole. The compressor can be configured to control the downhole pressure relative to a lithostatic pressure determined for rock surrounding the well at the bottom of the well.

DETERMINING THE DEPTH AND ORIENTATION OF A FEATURE IN A WELLBORE

The invention relates to a device for determining the depth and orientation of a feature in a wellbore, and to a corresponding method. It also relates to a downhole apparatus for performing an operation in a well comprising a device for determining the depth and orientation of a feature in a wellbore and a device for performing the operation. In an embodiment, a downhole device () for determining the depth and orientation of a feature () in a wellbore () containing a ferrous tubing () is disclosed, the device comprising: at least one magnetic field sensor () for monitoring the inherent magnetic field of the ferrous tubing so that the presence of the feature can be detected; and at least one orientation sensor () for determining the orientation of the device within the wellbore. An output from the at least one magnetic field sensor is correlated with an output from the at least one orientation sensor so that the orientation of the feature detected by the at least one magnetic field sensor within the wellbore can be determined. 140-. (canceled)41. A downhole device comprising:at least one magnetic field sensor that detects an inherent magnetic field of a ferrous tubing;at least one orientation sensor that determines an orientation of the device within the wellbore; anda processor that receives and correlates an output from the at least one magnetic field sensor and an output from the at least one orientation sensor to determine an orientation of a feature within or coupled to the ferrous tubing, the feature having an inherent magnetic field different than the inherent magnetic field of the ferrous tubing.42. The device of claim 41 , wherein the at least one magnetic field sensor is a passive magnetic field sensor.43. The device of further comprising a plurality of magnetic field sensors spaced around a periphery of the downhole device.44. The device of further comprising a plurality of arrays of a plurality of magnetic field sensors claim 41 , each array being spaced ...

Systems and Methods to Characterize Well Drilling Activities

Provided is a method of drilling a hydrocarbon well that includes conducting a drilling operation, collecting drilling data including characteristics of the drilling operation over a timespan, determining (based on the drilling data) drilling conditions for instants of time within the timespan, determining (based on application of the drilling conditions) preliminary classifications identifying a preliminary classification of the drilling operation for instants of time within the timespan, determining (based on the preliminary classifications) a series of classifications for the drilling operation that each indicate a determined classification for a respective instant of time, determining (based on the series of classifications) a change of classifications, conducting (in response to determining the change of classifications) a change point detection to identify a time of the change of classifications, generating drilling characteristic data indicating the time, and conducting the drilling operation in accordance with the time. 1. A method of drilling a hydrocarbon well , the method comprising:conducting a hydrocarbon well drilling operation comprising a drill bit boring a wellbore in a subsurface formation;collecting drilling operation data, the drilling operation data comprising characteristics of the hydrocarbon well drilling operation sensed by drilling sensors over a timespan;determining, based on the drilling operation data, drilling operation conditions, the drilling operation conditions comprising conditions of the hydrocarbon well drilling operation for instants of time within the timespan;determining, based on application of the drilling operation conditions to a well decision tree for identifying classifications of the hydrocarbon well drilling operation, preliminary operation classifications, the preliminary operation classifications identifying a preliminary classification of the hydrocarbon well drilling operation for respective instants of time within ...

CIVIL ENGINEERING WORK DATA PROCESSING DEVICE, CIVIL ENGINEERING WORK DATA PROCESSING METHOD, AND CIVIL ENGINEERING WORK DATA PROCESSING PROGRAM

A technique enables easy quantitative evaluation for drilling operations. A civil engineering work data processing device includes a positioning data receiving unit, a three-dimensional model estimating unit, and a drilled depth calculator. The positioning data receiving unit receives positioning data obtained by performing positioning using laser light, on a drilling rod. The three-dimensional model estimating unit estimates a three-dimensional model of the drilling rod, on the basis of the positioning data. The drilled depth calculator calculates a depth of a hole generated in a civil engineering work target by the drilling rod, on the basis of the estimated three-dimensional model. 1. A civil engineering work data processing device comprising a processor or circuitry , the processor or circuitry configured to:receive positioning data obtained by performing positioning using laser light, on a member to be pushed into a civil engineering work target;estimate a three-dimensional model of the member on a basis of the positioning data; andcalculate a displacement of the member relative to the civil engineering work target, on a basis of the estimated three-dimensional model.2. The civil engineering work data processing device according to claim 1 , wherein the member to be pushed into the civil engineering work target is a longitudinal member for drilling claim 1 , and a depth of a hole that is generated in the civil engineering work target by the longitudinal member is calculated by calculating the displacement.3. The civil engineering work data processing device according to claim 1 , wherein the processor or circuitry is further configured to calculate a position at the civil engineering work target claim 1 , into which the member is to be pushed claim 1 , on the basis of the estimated three-dimensional model.4. The civil engineering work data processing device according to claim 1 , wherein the processor or circuitry is further configured to calculate a direction ...

Locating a downhole tool in a wellbore

A downhole cement plug includes a casing collar locator (CCL) operable to generate signals indicative of casing collars on a downhole casing string of a wellbore system; a controller communicably coupled to the CCL to output a plurality of distinct frequency signals based on the signals from the casing collar locator; and a signal generator communicably coupled to the controller to receive the plurality of distinct frequency signals from the controller and transmit the plurality of distinct frequency signals to a terranean surface through a portion of a wellbore system.

CONTROL SYSTEM FOR DOWNHOLE OPERATIONS

A method of controlling a downhole operation includes: deploying a work string into a wellbore, the work string comprising a deployment string and a bottomhole assembly (BHA); digitally marking a depth of the BHA; and using the digital mark to perform the downhole operation. 1. A method of controlling a downhole operation , comprising:deploying a work string into a wellbore, the work string comprising a downhole sub;generating a digital mark to mark a depth or a time based on measurements from one or more sensors; andusing the digital mark to perform the downhole operation.2. The method of claim 1 , wherein the one or more sensors comprises one or more of: a mud pump stroke counter claim 1 , a hook load cell claim 1 , a hook position sensor claim 1 , a drawworks position sensor claim 1 , a standpipe pressure sensor claim 1 , a wellhead pressure sensor claim 1 , a torque cell claim 1 , a turns counter claim 1 , a pipe tally claim 1 , a measurement while drilling (MWD) sensor claim 1 , and logging while drilling (LWD) sensor.3. The method of claim 2 , wherein the one or more sensors is positioned in the downhole sub.4. The method of any one of claim 3 , wherein the one or more sensors are in communication with a rig controller.5. The method of claim 4 , wherein the one or more sensors are in communication with the rig controller by wireless telemetry.6. The method of claim 4 , wherein the one or more sensors are in communication with the rig controller by a wired path.7. The method of claim 1 , further comprising calculating operational parameters from the measurements of the one or more sensors.8. The method of claim 7 , wherein the operational parameters comprises one or more of depth claim 7 , flow rate claim 7 , rate of penetration claim 7 , rotational speed claim 7 , weight-on-bit claim 7 , and torque.9. The method of claim 1 , further comprising generating an animation of the downhole operation using the digital mark.10. The method of claim 9 , further ...

WELL LOG CORRELATION AND PROPAGATION SYSTEM

A system can include a processor; memory operatively coupled to the processor; and processor-executable instructions stored in the memory to instruct the system to: receive a marker on a well log for a well in a geographic region; and iteratively propagate the marker automatically to a plurality of well logs for other wells in the geographic region. 14210. A method () comprising:{'b': '4214', 'receiving a marker on a well log for a well in a geographic region (); and'}{'b': '4218', 'iteratively propagating the marker automatically to a plurality of well logs for other wells in the geographic region ().'}2. The method of wherein the marker comprises a formation top marker.3. The method of wherein the propagating comprises computing a warp distance.4. The method of comprising computing a confidence score based at least in part on the warp distance.5. The method of wherein the propagating comprises implementing a fast dynamic time warping (FastDTW) computational algorithm using one or more processors to compute the warp distance.6. The method of wherein the warp distance is a measure of a difference between data of two of the well logs.7. The method of wherein the propagating comprises adjusting an adjustable depth search range claim 1 , wherein the adjusting comprises determining an upper depth search range limit and a lower depth search range limit using a depth of a propagated marker that is based on the received marker.8. The method of wherein the well logs comprise data with respect to a vertical depth.9. The method of comprising computing confidence scores for individual correlations between pairs of the well logs.10. The method of comprising identifying a lowest confidence score as associated with one of the other wells and issuing a notification that identifies the one of the other wells.11. The method of wherein the propagating comprises generating a minimum spanning tree (MST) claim 1 , wherein the received marker is a seed of the MST.12. The method of ...

ACTIVE MAGNETIC RANGING WHILE DRILLING

A magnetic ranging system for use with a drilling assembly in a borehole in a formation, the drilling assembly including a drill string, a drill bit and a bottomhole assembly (BHA) connected to the drill bit, the BHA including a measurement-while-drilling (MWD) system, a bi-directional MWD telemetry interface, and a steerable component, may comprise at least one ranging magnetometer incorporated into the BHA. The ranging magnetometer may be configured to collect ranging measurements from behind the drill bit and the ranging magnetometer may be configured to transmit measurement data. The magnetic ranging system may include at least two ranging magnetometers, with one ranging magnetometer positioned above the MWD system and one ranging magnetometer positioned below the MWD system. 1. A magnetic ranging system for use with a drilling assembly in a borehole in a formation , the drilling assembly including a drill string , a drill bit and a bottomhole assembly (BHA) connected to the drill bit , the BHA including a measurement-while-drilling (MWD) system , a bi-directional MWD telemetry interface , and a steerable component , the magnetic ranging system comprising:at least one ranging magnetometer incorporated into the BHA, wherein the ranging magnetometer is configured to collect ranging measurements from behind the drill bit and wherein the ranging magnetometer is configured to transmit measurement data.2. The system of wherein the magnetic ranging system includes at least two ranging magnetometers and wherein one ranging magnetometer is positioned above the MWD system and one ranging magnetometer is positioned below the MWD system.3. The system of wherein the magnetic ranging system includes at least two ranging magnetometers and wherein at least one ranging magnetometer is integral with the MWD system.4. The system of wherein the magnetic ranging system includes at least two ranging magnetometers and wherein one ranging magnetometer is positioned above the steerable ...

Fluid flow back prediction

A computing device configured to determine when an alarm is triggered for a drilling operation is provided. Measured drilling data that includes a value measured for an input variable during a previous connection event of a drilling operation is received. A predicted value for a fluid flow back measure is determined by executing a predictive model with the measured drilling data as an input. The predictive model is determined using previous drilling data that includes a plurality of values measured for the input variable during a second drilling operation. The second drilling operation is a previous drilling operation at a different geographic wellbore location than the drilling operation. A fluid flow back measurement datum determined from sensor data is compared to the determined predicted value for the fluid flow back measure. An alarm is triggered on the drilling operation based on the comparison.

Downhole Pressure/Thermal Perturbation Scanning Using High Resolution Distributed Temperature Sensing

A system, method and computer readable medium for determining a feature in a wellbore is disclosed. A distributed temperature sensing system is disposed along the wellbore. A thermal perturbation is induced along the wellbore. A profile is determined of temperature change in response to the applied thermal perturbation using the distributed temperature sensing system. The feature of the wellbore is determined using the measured temperature profile. 1. A method of determining a feature in a wellbore , comprising:disposing a distributed temperature sensing system along the wellbore;inducing a thermal perturbation along the wellbore;determining a profile of temperature change in response to the applied thermal perturbation using the distributed temperature sensing system; anddetermining the feature of the wellbore using the measured temperature profile.2. The method of wherein inducing the thermal perturbation further comprises at least one of: generating a pressure perturbation in a fluid in the wellbore and generating the temperature perturbation using a heating element disposed along the wellbore.3. The method of claim 2 , wherein the pressure perturbation is a pressure wave that propagates along the wellbore.4. The method of claim 3 , wherein the pressure wave is generated by a pressure oscillator disposed at one of: a downhole location; and a surface location.5. The method of claim 1 , wherein the feature of the wellbore is at least one of: a component of a work string in the wellbore; a near wellbore feature of the formation; a gas hydrate formation in a fluid flowing in a production string in the wellbore; a flow assurance barrier; a liquid-liquid interface; a gas-liquid interface; an unexpected release of gases or fluids; and a well leakage.6. The method of claim 1 , further comprising determining the feature with respect to a formation depth.7. The method of claim 1 , wherein a magnitude of the induced thermal perturbation is less than a resolution of the ...

Casing detection tools and methods

Methods and tools for detecting casing position downhole is presented. The method utilizes electromagnetic. (EM) tools with tilted antenna systems to detect casing position. Sometimes titled antenna designs also increase EM tools' sensitivity to formation parameters, which can lead to false signals for casing detection. In addition, it is very difficult to distinguish measured signals between a casing source and a formation source. The methods presented help to distinguish between the two sources more clearly. The methods and tools presented also help to minimize those environmental effects, as well as enhance the signals from a surrounding conductive casing. The methods herein provide ideas of EM tool's design to precisely determine casing position within a certain distance to casing position.

ADAPTIVE QUALITY CONTROL FOR MONITORING WELLBORE DRILLING

A method of validating a directional survey includes measuring the gravity and magnetic field vectors using a surveying tool and computing an overall statistical distance of the measurement. The statistical distance may be calculated from reference values associated with the surveying tool using corresponding surveying tool codes with error values. In a further aspect, an error covariance matrix may be used to determine whether the new errors m a survey are consistent or not with errors from one or more previous surveys. 1. A system for monitoring drilling , the system comprising:a processor; during drilling, of a borehole by a drilling system, receiving a first survey from a measurement-while-drilling (MWD) tool, wherein the first survey comprises a first measurement of a gravity vector G and a second measurement of a magnetic field vector B;', 'calculating a magnetic dip angle φ responsive to the second measurement of the magnetic field vector B;', 'generating, responsive to tool codes for the MWD tool that define error values for the first measurement and the second measurement, a first covariant matrix describing the relationship of a plurality of measured values to expected errors in the measured values;', 'generating a plurality of residual values corresponding to the first measurement and the second measurement as a difference between a reference value and a measured value for each of first measurement of the gravity vector G and the second measurement of the magnetic field vector B;', 'computing, responsive to the residual values and the first covariant matrix, an error ellipsoid describing bounds for residual values for the first measurement of the gravity vector G and the second measurement of the magnetic field vector B;', 'comparing the first purvey with the error ellipsoid to determine if the first survey is acceptable; and', 'when the first survey is not acceptable based on the error ellipsoid, generating a first indication that the drilling should ...

SUBMERSIBLE PUMP ASSEMBLY

A submersible pump assembly (), for arrangement in a shaft () or receptacle, includes a pump () and an electric motor () driving the pump () and a cable () for the supply of electricity. The cable is configured for being led out of the shaft () or receptacle at the upper side and for connection to an electricity source () outside the shaft or receptacle. The pump assembly () includes an electronics unit () which is configured to transmit a signal into the cable () and to detect a reflection signal at the surface () of the fluid () located in the shaft () or receptacle. The electronics unit () is configured to determine, from this reflection signal, a fluid level () in the shaft () or receptacle by way of time domain reflectometry. 1. A submersible pump assembly for arrangement in a shaft or a receptacle , the submersible pump assembly comprising:a pump;an electric motor driving the pump;a cable for a supply of electricity to the electric motor, the cable being configured for being led out of the shaft or the receptacle, at the upper side and for connection to an electricity supply outside the shaft or the receptacle; andan electronics unit configured to transmit a signal into the cable and to detect a reflection signal at a surface of a fluid located in the shaft or the receptacle, and from the reflection signal to determine a fluid level in the shaft or receptacle by way of time domain reflectometry.2. A pump assembly according to claim 1 , wherein the cable is a standard electricity cable comprised of copper claim 1 , and a signal incoupling and a signal outcoupling is effected capacitively via a Y-capacitor.3. A pump assembly according to claim 1 , wherein the cable comprises at least one current conductor and at least one separate conductor for the transmitted signals and reflection signals for the time domain reflectometry and the at least one separate conductor also forms a motor data communication line with an external motor control.4. A pump assembly ...

Method and System for Collecting and Managing Remote Sensor Data

A system, method, and device for monitoring one or more sensors at a remote location. The system allows a user to register multiple sensors to the user's account. When the sensors are deployed at a remote location for measuring various properties of their surrounding environments, they collect data which is then transmitted to a server. The user may then monitor the data by connecting to the server via a client device, and receive alerts when the data satisfies certain conditions. 1. A method for remote sensing of at least one property , comprising:disposing at least one sensor that senses at least one property of its surroundings in a location for sensing the at least one property;providing a control module that communicates with the at least one sensor;implementing a control module sleep/wake cycle time period;using the control module to receive, during a wake portion of the sleep/wake cycle, at least one signal from the at least one sensor, the at least one signal corresponding to a reading of the at least one property;using the control module to set a communication interval wherein the control module communicates the at least one reading to a server during the communication interval and the communication interval comprises an amount of time as determined by a number of sleep/wake cycles selected according to a threshold amount of power available from a power source;maintaining the at least one sensor obtaining readings of the at least one property according to the sleep/wake cycle;during an increased communication interval comprising an amount of time as determined by an increased number of sleep/wake cycles, buffering sensor readings such that two or more buffered sensor readings are communicated to the server during the increased communication interval.2. The method of claim 1 , comprising turning on communications circuitry only during a communication interval.3. (canceled)4. The method of claim 1 , comprising the server:receiving, over a communications ...

Method and Apparatus for In-Well Wireless Control Using Infrasound Sources

A system and method for downhole data communication using an infrasound wave generator and receivers. The infrasound waves have a low frequency and a wavelength that is much larger than the transverse dimensions of the well. When the infrasound waves are directed down the well, the well will act as a wave guide for low frequency excitations. The receivers are operatively connected to inflow valves and other downhole equipment, and receive the infrasound waves. If the waves are of a predetermined frequency, the receivers command the valves to open or close, or otherwise control downhole equipment. The infrasound waves can also be used to probe well geometry and to identify fluid properties within the well.

METHOD AND DEVICE FOR OBTAINING MEASUREMENTS OF DOWNHOLE PROPERTIES IN A SUBTERRANEAN WELL

Embodiments of the invention provide an untethered apparatus for measuring properties along a subterranean well. According to at least one embodiment, the untethered apparatus includes a housing, and one or more sensors configured to measure data along the subterranean well. The data includes one or more physical, chemical, geological or structural properties in the subterranean well. The untethered apparatus further includes a processor configured to control the one or more sensors measuring the data and to store the measured data, and a transmitter configured to transmit the measured data to a receiver arranged external to the subterranean well. Further, the untethered appratus includes a controller configured to control the buoyancy or the drag of the untethered apparatus to control a position of the untethered apparatus in the subterranean well. The processor includes instructions defining measurement parameters for the one or more sensors of the untethered apparatus within the subterranean well. 1. A method for measuring properties along a subterranean well , the method comprising the steps of:programming a movement of an untethered apparatus along a subterranean well, wherein the untethered apparatus comprises a housing, wherein a position of the untethered apparatus along the subterranean well is controlled by changing at least one of: a buoyancy of the untethered apparatus or a drag of the untethered apparatus upon measuring data in the subterranean well, the data comprising one of one or more physical, chemical, or structural properties in the subterranean well or the dynamics or position of the untethered apparatus in the subterranean well; closing a master valve of the Christmas tree valve;', 'opening a swab valve of the Christmas tree valve;', 'introducing the untethered apparatus through the swab valve;', 'closing the swab valve; and', 'opening the master valve;, 'releasing the untethered apparatus into the subterranean well through a Christmas tree ...