УСТРОЙСТВО РАСПОЗНАВАНИЯ ИСКОПАЕМЫХ, А ТАКЖЕ СООТВЕТСТВУЮЩАЯ СИСТЕМА И СПОСОБ

Изобретение относится к способу, устройству и системе распознавания ископаемых. Техническим результатом является определение происхождения шлама/ископаемых, особенно в вертикальных разведочных скважинах. Способ, реализуемый посредством процессора, включает получение информации об изображении флюида от формирователя изображений, у которого флюид находится в поле обзора, причем указанная информация об изображении флюида содержит информацию об изображении ископаемого, обработку информации об изображении ископаемого для идентификации типов ископаемых во флюиде в виде данных, связывающих типы ископаемых с пластом, из которого был получен флюид, определение местоположения первой скважины в пласте на основе упомянутых данных и записей смещения, связанных со второй скважиной, и публикацию упомянутых данных в сочетании с указаниями местоположения. 3 н. и 26 з.п. ф-лы, 7 ил.

УСТРОЙСТВО И СПОСОБ ВИЗУАЛИЗАЦИИ ОБЪЕКТОВ В ТРУБЕ, ПРОВОДЯЩЕЙ ТЕКУЧУЮ СРЕДУ

Использование: для визуализации объектов в трубе, проводящей текучую среду. Сущность заключается в том, что испускают фотоны (2) высокой энергии по направлению к целевому объекту (3) посредством управляемого источника (1) излучения, регистрируют фотоны (4) обратного рассеяния, поступающие от целевого объекта (3) посредством сенсорного модуля (1а), снабженного диафрагмой (5) для ограничения рассеяния, усилителем (6) и устройством (7) для регистрации изображений, в ячейках которого создаются электронные заряды, передаваемые на блок (8) управления и отображения через буферную память, встроенную в устройство (7) для регистрации изображений, формируют с использованием зарегистрированных сигналов изображение на экране и затем сравнивают данные выбранного участка изображения с информацией о материалах, содержащейся в базе данных, для определения состава целевого объекта (3) посредством спектрального анализа обратных фотонов. Технический результат: обеспечение быстрого и качественного получения ...

Устройство оперативного исследования нефтяных и газовых скважин

Изобретение относится к измерительным комплексам для геофизических исследований, предназначено для контроля технического состояния нефтяных, газовых и других скважин. Устройство содержит наземное оборудование, включающее компьютер, кабель, связывающий наземное оборудование и скважинный прибор, в котором размещены видеокамера, блок подсветки, блок приема-передачи информации. Кабель выполнен волоконно-оптическим, в качестве видеокамеры, размещенной в скважинном приборе, используют видеокамеру диапазона SWIR, синхронизированную с импульсным лазерным диодным блоком подсветки, модуль инклинометра, а в наземное оборудование введен оптический рефлектометр для распределенной по стволу скважины термометрии и барометрии. Повышается оперативность, надежность, производительность, расширяются функции. 1 ил.

СПОСОБ ВЫПОЛНЕНИЯ РАЗВЕДКИ

Изобретение относится к способам вычисления вероятного положения структур в земной коре. Предложен способ вычисления вероятных положений структур в некотором районе земной коры, в котором определяют указанный район в земной коре, создают первую структурную модель указанного района по сейсмическим данным с неопределенностями и корреляциями. Создают вторую структурную модель указанного района по результатам измерений в стволе скважины с неопределенностями и корреляциями. Создают третью структурную модель указанного района по результатам измерений в некотором объеме вокруг указанного ствола скважины, отсчитываемых от ствола скважины с неопределенностями и корреляциями. Определяют ограничивающие уравнения для указанных первой, второй и третьей структурных моделей и, используя указанные ограничивающие уравнения, вычисляют вероятные положения структур в указанном районе и вероятные неопределенности и корреляции, связанные с указанными положениями. Технический результат – повышение информативности ...

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 ...

СИСТЕМА И СПОСОБ ПРОГНОЗИРОВАНИЯ И ВИЗУАЛИЗАЦИИ СОБЫТИЙ В ПРОЦЕССЕ БУРЕНИЯ

АЗИМУТАЛЬНОЕ ЗЕРКАЛЬНОЕ УСРЕДНЕНИЕ В СКВАЖИНЕ

НАПРАВЛЕННОЕ БУРЕНИЕ С ИСПОЛЬЗОВАНИЕМ ОПТИЧЕСКОГО ВЫЧИСЛИТЕЛЬНОГО ЭЛЕМЕНТА

... 1. Способ, содержащий:направление света от стенки ствола скважины к оптическому вычислительному элементу, причем оптический вычислительный элемент является оптическим устройством, осуществляющим вычисления по принимаемому свету при взаимодействии с принимаемым светом;анализ светового сигнала, выходящего из оптического вычислительного элемента в ответ на прием оптическим вычислительным элементом света от стенки ствола скважины; иопределение характеристики, связанной со стенкой ствола скважины, на основании анализа светового сигнала, выходящего из оптического вычислительного элемента.2. Способ по п. 1, причем данный способ включает в себя генерирование сигнала для направленного бурения на основании определенной характеристики.3. Способ по п. 2, в котором генерирование сигнала для направленного бурения включает в себя геоуправление бурением.4. Способ по п. 3, в котором геоуправление бурением включает в себя удержание ствола скважины в углеводородном продуктивном пласте.5. Способ по п. 2, в ...

Optical sensor and method of use

An interferometer apparatus for an optical fibre system and method of use is described. The interferometer comprises an optical coupler and optical fibres which define first and second optical paths. Light propagating in the first and second optical paths is refelected back to the optical coupler to generate an interference signal. First, second and third interference signal components are directed towards respective first, second and third photodetectors. The third photodetector is connected to the coupler via a non-reciprocal optical device and is configured to measure the intensity of the third interference signal component directed back towards the input fibre. Methods of use in applications to monitoring acoustic perturbations and a calibration method are described.

Optical sensor and method of use

An interferometer apparatus for an optical fibre sensing system, the apparatus comprising an optical coupler with first and second ports connected to first and second optical paths which have a path length difference that defines a spatial resolution of the system and where a third coupler port receives an input from an optical source and further comprises first, second and third photodetectors coupled to the respective ports. Preferably an optical circulator is coupled to the third coupler port and there may be an optical amplifier and filter configured to filter out Amplified Spontaneous Emission noise. Preferable is the introduction of third and fourth optical paths with a plurality of optical switches arranged to change and/or select different combinations of the paths to provide multi-spatial resolution. Also an interferometer system comprising a plurality of interferometer apparatus 602-605 arranged in series or parallel or a combination of both, where the interferometers may have ...

Distributed nondestructive inspection system and method for identifying slickline cable defects and mechanical strength degradation trend

High quality visualization in a corrosion inspection tool for multiple pipes

A method includes conveying a pipe inspection tool including one or more sensors into a wellbore having at least one pipe, transmitting an excitation signal from the pipe inspection tool and measuring response signals with the sensors, and processing the response signals to obtain measured responses. A map of the pipe is then generated based on the measured responses, where the map is divided into pipe ranges extending along the length of the pipe and each pipe range corresponds to a percentage of metal loss in the pipe. A photorealistic image is assigned to each pipe range based on the percentage of metal loss, and a two-dimensional (2D) or three-dimensional (3D) image is then generated as a combination of each photorealistic image. The 2D or 3D image is then graphically visualized.

Method and apparatus for optical sensing

Optical cap

System and method for stress inversion via image logs and fracturing data

Method and apparatus for optical sensing

Method and apparatus for optical sensing

Method for characterising a subsurface formation

A method for characterizing a subsurface formation with a logging instrument disposed in a borehole penetrating the formation, the logging instrument having a longitudinal axis and being equipped with at least a transmitter system and a receiver system that collectively comprise at least one set of upper antennas and one set of lower antennas, comprises the steps of: ```positioning the logging instrument within the borehole so that the transmitter system and receiver system are disposed in the vicinity of a formation boundary of interest; ```measuring the azimuthal orientation of the logging instrument; ```transmitting electromagnetic energy into the formation using the transmitter system; ```measuring signals associated with the electromagnetic energy transmitted by the transmitter system using the receiver system; ```composing a symmetrized directional measurement using the measured signals; and ```plotting the determined directional measurement as a function of depth for a plurality ...

Modular downhole inspection system for coiled tubing

Autonomous depth control for wellbore equipment

IMPROVEMENTS IN OR RELATING TO THE REPAIR OF BOREHOLES

Method of flow monitoring

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 ...

Underream soil testing

Optical sensor

Fiber optic monitoring of sand control equipment via tubing string

Methods and apparatus for wellbore evaluation

A wellbore tool string includes a combination of acoustic inspection tool(s) and electro-mechanical inspection tool(s). The tool string is configured to combine acoustic with electro-mechanic wellbore inspection to circumvent limitations that both technologies may be subject to in wellbore environments. Anomalous data from one or more acoustic tools can be correlated with data acquired by an electro-mechanical tool incorporated into the same tool string to determine wellbore conditions that may have adversely affected the operation of the acoustic tool(s).

Downhole electrode apparatus, systems, and methods

Electromagnetic viscosity sensor

Method to illuminate and image the inside diameter of a stent

MEMS-Based transducers on a downhole tool

In accordance with embodiments of the present disclosure, systems and methods for taking acoustic/ultrasonic wave measurements of a wellbore using a downhole tool equipped with microelectromechanical (MEM) transducers are provided. The MEM transducers may include a plurality of MEM transmitters (e.g., MEM speakers) and a plurality of separate MEM receivers (e.g., MEM microphones). These MEM transducers may be disposed in arrays proximate an outer surface of the downhole tool to collect acoustic/ultrasonic wave measurements of the full circumference of a wellbore. Due to their small size, large numbers of MEM transducers may be distributed radially around the downhole tool. Such an arrangement of sensors may enable the downhole tool to perform measurements of the entire wellbore without the downhole tool needing to be rotated, leading to an increased signal-to- noise ratio of the measurements.

Downhole imaging device and method of using the same

A downhole device (10, fig 2) deployable in a well, comprises an elongate housing 16 connectable to a wireline or tractor for coarse movement along a longitudinal axis of the well; an end effector 13 located at a distal end of the housing and distally extendable therefrom; and at least one actuator contained in the housing for fine extension of the end effector 13, away from the housing 16, along the longitudinal axis of the housing 16. An image sensor 12 may be attached to the end effector 13. Multiple actuators may be present to move the end effector in transverse and longitudinal directions.

Method to compute density of fractures from image logs

A method for performing a formation-related physical action includes: receiving image data of a wall of a borehole penetrating a formation, the image data having image data of fractures intersecting the wall of the borehole; and defining a volume surrounding the borehole. The method also includes determining a surface area of each fracture intersecting the volume at each defined depth in a plurality of depths and calculating a fracture density for each defined depth based on the surface area of each fracture intersecting the volume at each defined depth in a plurality of depths and a size of the volume. The method further includes performing the formation-related physical action based on the fracture density for each defined depth using apparatus configured to perform the formation-related physical action.

Real-time operations information on wearable smart heads up display

To reduce costs and free on-site personnel to freely move about a well site in a hydrocarbon recovery, exploration, operation, or services environment, systems and methods are presented for collecting data associated with one or more on-site pieces of equipment, distributing the collected data using a network system, optionally storing the collected data in one or more resources including databases, and producing a notification on a wearable notification device based, at least in part, on the collected data to enable on-site users to respond to the collected data by modifying on-site operations.

Manufacturing process for integrated computational elements

Smart frac plug

A smart frac plug assembly including an instrument plug module with a sensor for collecting data during a hydraulic fracturing process. This assembly when used in conjunction with a wireless or tubing conveyed data logger and other related recording/processing systems, provides direct measurements of pressure, temperature, observed velocity field and/or observed acceleration field in a subsurface.

Compressing ultrasound data in a downhole tool

INSPECTION APPARATUS FOR TUBULAR MEMBERS

MODULAR DOWNHOLE INSPECTION SYSTEM FOR COILED TUBING

Inspection assembly viewport

An inspection assembly for imaging the internal surface of a pipe or conduit comprises an elongate housing, a sideview camera within the housing and arranged to capture an image of a region within a field of view external to the housing, and a viewport element 114 mounted in the housing and located such that light is transmitted through the viewport element 114 and into said sideview camera, wherein the viewport element 114 is diffusion bonded to a metal support 166.

Determining permeablility based on collar responses

A method for determining tubing permeability includes conveying a tool through a tubular string in a borehole. The tool includes a transmitter that transmits a primary electromagnetic field and a receiver that receives at least one collar response. The collar response includes a secondary electromagnetic field produced in response to the primary field by a collar in the tubular string. The method further includes determining a permeability of at least one portion of the tubular string based on a magnitude of the at least one collar response. The method further includes displaying a representation of the at least one portion of the tubular string based on the permeability.

Devices and methods for imaging wells using phased array ultrasound

Methods and devices for imaging wells using phased array ultrasound imaging devices is described. The devices enable high resolution real-time imaging of a well during various operations in the well, including during completions, fracturing, milling, fishing and drilling operations. The phased array ultrasound imaging devices may be integrated with other well tools, such as a bottom hole assembly (BHA), fishing tools, milling tools, fracturing tools, and drilling tools, in order to integrate imaging capabilities into such tools.

Imaging sensor

Estimation of fracture properties based on borehole fluid data, acoustic shear wave imaging and well bore imaging

Depth and speed correction of logging data

Acoustic detection of position of a component of a fluid control device

A system for estimating a position of a component of a fluid control device includes an optical fiber sensor having a section disposed at a fixed location relative to the fluid control device, the fluid control device configured to be disposed in a borehole in an earth formation and including a moveable member, the fixed location selected so that acoustic signals generated by fluid flowing through the fluid control device are receivable by the section of the optical fiber sensor. The system also includes an interrogation assembly configured to inject an optical signal into the optical fiber and receive a return signal, and a processing device configured to detect the return signal, identify a signal pattern based on the return signal, and estimate a position of the moveable member based on the identified signal pattern.

Virtual real time operation

Downhole Camera Enhanced Manipulation Tool

A first aspect relates to a manipulation element 10 for a downhole tool, comprising a root portion (12, Fig 2), a stem portion (36, Fig 2) and a manipulation surface (62, Fig 1). The root portion is connectable to the downhole tool and includes an aperture (24, Fig 4) for receiving part of a camera assembly such that, in use, a lens of the camera assembly is disposed forward of the root portion. The stem portion extends from the root portion and includes a hollow or gap (30, Fig 1) aligned with the aperture for receiving the lens. The stem portion terminates at a tip (50, Fig 2). The manipulation surface extends continuously between the tip and the root portion. At least a part of the manipulation surface extends at a non-zero angle to a longitudinal axis of the manipulation element. A second aspect relates to a downhole tool comprising the manipulation element and a camera assembly including a camera and a lens 80. A third aspect relates to a method of viewing, in real time, a region forward ...

Drill bit wear and behaviour analysis and correlation

A method comprises determining a measure of drilling efficiency, such as a friction factor or mechanical specific energy, of a drill bit used in a drilling operation of a wellbore and performing video analytics of at least one video that includes a substantially complete view of the wear surfaces of a drill bit to determine drill bit wear of the drill bit that is a result of the drilling operation of the wellbore. The method includes determining a cause of the drill bit wear based on the measure of drilling efficiency and the drill bit wear determined by performing video analytics. Based on correlation or modeling of drill bit wear and the measure of drilling efficiency, drill bit wear can be predicted and some types of drilling dysfunction mitigated in subsequent drilling runs.

INTEGRATED INSPECTION AND MAINTENANCE RAISE BORING METHOD AND AN ASSOCIATED DRILL STRING ARRANGEMENT

System zum Ermitteln eines Ortsbrustbilds

The invention relates to an assembly (120) for determining an image of at least one region of a working face (122) of a rock mass (102), which working face is processed by a tunnel boring machine (180), wherein the assembly (120) comprises a rotatable drilling head (150) for the tunnel boring machine (180) for removing rock material of the working face (122), an image recording device (124), which is attached to the drilling head (150) in order to record image data of at least one section (600) of the working face (122), and an image processing device (126), which is designed to process image data of a plurality of sections (600) of the working face (122), which are recorded by means of the image recording device (124) in particular during the rotation of the drilling head (150), and for reconstructing the image of at least the region of the working face (122) from the image data of the plurality of sections (600) of the working face (122). In addition, a regular or continuous optical analysis ...

Procedure and plant for the investigation of boreholes

Subterranean monitoring using enhanced video

Video of an above ground effect of a subterranean event is received. The subterranean event is identified using Eulerian video magnification of the received video. 128 122 118 126) 101a 101a 108 101b 101b 108 ...

Self-propelled peeping probe adapted to different diameters of drill holes and peeping method

A self-propelled peeping probe adapted to different diameters of drill holes and a method. The probe comprises a peeping probe body (1), a camera (2), walking wheels (3), rocker arms (4) connected to the walking wheels (3), and an operating host (30). The rock arms (4) can achieve a certain angle of damping opening or closing under the effects of internal torsion springs (12) and gas springs (16), and have alarm functions, and the rocker arms (4) can be fixed in grooves (5) in the side of the peeping probe by means of locking holes (7) and locking blocks (6). The self-propelled function of the peeping probe in a drill hole can be achieved by means of an internal power supply, a driving motor (8), a video processing module (19), a control module (21), a WIFI module (22), and the external operating host (30). The peeping probe has the advantages of centered drill hole, self-propelling, and few operating workers in a drilling peeping operation process, the complexity in a conventional drilling ...

Virtual white lines for indicating planned excavation sites on electronic images

Methods and apparatus for facilitating detection of a presence or an absence of at least one underground facility within a dig area. Source data representing one or more input images of a geographic area including the dig area is electronically received at a first user location, which may be remote from the dig area. The source data is processed so as to display at least a portion of the input image(s) on a display device at the first user location. One or more indicators are added to the displayed input image(s), via a user input device associated with the display device, to provide at least one indication of the dig area and thereby generate a marked-up digital image. In one example, the indicator(s) is/are added to the displayed input image(s) without acquiring geographic coordinates corresponding to the indicator(s).

Image data processing

Downhole electrode apparatus, systems, and methods

Apparatus, systems, and methods are disclosed. In some embodiments, an apparatus comprises a stabilizer element attached to a downhole tool housing. The stabilizer element includes at least a portion of a surface that is not parallel to a longitudinal axis of the tool housing, and that does not contact a borehole wall during operation. An electrode element is attached to the portion of the surface.

Perspective-based modeling of a subterranean space

A method for graphically representing a subterranean space from the perspective of a point within the subterranean space, in some embodiments, comprises: obtaining data associated with the subterranean space, said data corresponding to a plurality of coordinates in a first coordinate system; associating the data for each of said plurality of coordinates with one or more corresponding coordinates in a second coordinate system; generating a different model of the subterranean space based on the data and said associations; and displaying the different model on a display, wherein the different model represents the subterranean space from the perspective of a point within the subterranean space.

Downhole apparatus and method

A downhole actuator (30) comprises a tubular housing (34) which includes an indexing profile (42) on an inner surface thereof, and an indexing sleeve (46) mounted within the housing (34). The indexing sleeve (46) comprises an engaging arrangement including first and second axially spaced engagement members (52, 54) which cooperate with the indexing profile (42) of the housing (34) to be sequentially engaged by an actuation object (48) passing through a central bore (50) of the indexing sleeve (46) to drive the indexing sleeve (46) one discrete step of movement through the housing (34) towards an actuation site.

Systems and methods for removal of electromagnetic dispersion and attenuation for imaging of proppant in an induced fracture

Systems and methods for generating a three-dimensional image of a proppant-filled hydraulically-induced fracture in a geologic formation are provided. The image may be generated by capturing electromagnetic fields generated or scattered by the proppant-filled fracture, removing dispersion and/or an attenuation effects from the captured electromagnetic fields, and generating the image based on the dispersion and/or attenuation corrected fields. Removing the dispersion and/or attenuation effects may include back propagating the captured electromagnetic fields in the time domain to a source location. The image may be generated based on locations at which the back propagated fields constructively interfere or may be generated based on a model of the fracture defined using the back propagated fields.

OPTICAL SENSOR AND METHOD OF USE

An interferometer apparatus for an optical fibre system and method of use is described. The interferometer comprises an optical coupler and optical fibres which define first and second optical paths. Light propagating in the first and second optical paths is refelected back to the optical coupler to generate an interference signal. First, second and third interference signal components are directed towards respective first, second and third photodetectors. The third photodetector is connected to the coupler via a non-reciprocal optical device and is configured to measure the intensity of the third interference signal component directed back towards the input fibre. Methods of use in applications to monitoring acoustic perturbations and a calibration method are described.

BOREHOLE TELEVIEWER SYSTEM USING MULTIPLE TRANSDUCER SUBSYSTEMS

... "BOREHOLE TELEVIEWER SYSTEM USING MULTIPLE TRANSDUCER SUBSYSTEMS" In an acoustic logging system for providing information regarding selected parameters of the wall of a borehole in the earth, and of the rock formation which is adjacent the borehole, in which a single transmit/receive transducer system (T/RTS) mounted on a rotating assembly probes the wall of the borehole in a circular scanning pattern as a function of depth, the improvement which includes at least a second T/RTS mounted on the rotating assembly in known geometrical relation to the first T/RTS, and means to utilize in combination the electrical scan signals from the at least two scanning T/RTS.

OVERLAPPED SCHEDULING AND SORTING FOR ACOUSTIC TRANSDUCER PULSES

A device and method used to increase the resolution when imaging, measuring and inspecting wells, pipes and objects located therein. The device comprises an array of acoustic transducers that both transmit and receive acoustic signals. Scan lines may be overlapped by interlacing transmission and receiving windows thus increasing either the resolution or logging speed drastically compared to conventional approaches. The sequence of the scan lines making up an imaging frame is created by stratifying physically close lines and randomly selecting from within each stratum, preventing interference from neighboring transducers, signals and acoustic artifacts that fundamentally limit logging speed and resolution using conventional methods.

METHOD FOR COMBINING THE RESULTS OF ULTRASOUND AND X-RAY AND NEUTRON CEMENT EVALUATION LOGS THROUGH MODALITY MERGING

A combining mechanism for borehole logging tool data that employs modality merging to combine the output data of various borehole logging tools to provide a combined result and automated interpretation is provided, said mechanism comprising: at least one mechanism for assigning interpretive values to individual processed data types; at least one mechanism for combining the interpretive value data sets; and, at least one mechanism for providing an interpretation. A method of combining borehole logging tool data that employs modality merging to combine the output data of various borehole logging tools to provide a combined result and automated interpretation is also provided, said method comprising: assigning interpretive values to individual processed data types; combining the interpretive value data sets; and, providing an interpretation.

AUTOMATED CORE DESCRIPTION

An image associated with a core sample is received. The image represents a property of the core sample. A plurality of values of at least one image attribute are determined from the received image. A core description of the core sample is determined from a set of core descriptions. The core description describes the property of the core sample. The set of core descriptions are associated with a set of training core samples. Each training core sample has a corresponding core description and is associated with a set of plurality of values. Determining the core description of the core sample is based on a comparison between the plurality of values associated with the core sample and sets of plurality of values associated with the set of training core samples. The core description of the core sample is provided to an output device.

INSPECTION ASSEMBLY LIGHTING SYSTEM

This invention relates to the field of inspection assemblies and in particular to inspection assemblies that include light sources for illuminating a field of view of a camera. An inspection assembly for imaging the internal surface of a pipe or conduit comprises an elongate housing having a longitudinal axis, a camera mounted in the housing and arranged to capture an image of a region within a field of view external to the housing, a light source mounted in the housing and arranged to illuminate the field of view, and a window element mounted in the housing, the window element comprising a light transmitting material and being located such that light emitted by the light source passes through the window element before illuminating the field of view. The window element has an internal surface, closer to the light source, and an external surface, further from the light source, and the external surface comprises a concave region.

TOOL DETECTION AND ALIGNMENT FOR TOOL INSTALLATION

A modular top drive system for construction of a wellbore includes an alignment assembly configured to align a tool with a top drive unit to facilitate automatic tool installation during rig up.

360-DEGREE CORE PHOTO IMAGE INTEGRATION AND INTERPRETATION IN A 3D PETROPHYSICAL MODELING ENVIRONMENT

The present disclosure describes methods and systems, including computer-implemented methods, computer-program products, and computer systems, for providing 360-degree well core sample photo image integration, calibration, and interpretation for modeling of reservoir formations and lithofacies distribution. One computer-implemented method includes receiving a 360-degree well core sample photo image, geospatially anchoring, by a computer, the received 360-degree well core sample photo image, decomposing, by a computer, the geospatially-anchored 360-degree well core sample photo image into a color numerical array, transforming, by a computer, the color numerical array into a formation image log, calibrating, by a computer, the formation image log for consistency with additionally available data, and generating, by a computer, 3D lithofacies interpretation and prediction data using the formation image log.

UNDERGROUND STRUCTURE INSPECTION SYSTEM AND METHOD

A system for inspecting an underground structure and a method of inspecting an underground structure, for example a shaft, tunnel or excavation, is provided. The system comprises a memory configured to store a plurality of images captured whilst moving along a predetermined path through the underground structure, a position determination module configured to generate position data associating each of the stored images with a position on the predetermined path, and a user terminal configured to receive a user input specifying a position on the predetermined path and to display at least one of the stored images corresponding to the specified position based on the position data. Accordingly, the user may retrieve and inspect images of the underground structure, based on the position at which the image was captured therein.

INTEGRATED INSPECTION AND MAINTENANCE RAISE BORING METHOD AND AN ASSOCIATED DRILL STRING ARRANGEMENT

A raise boring method is disclosed including the steps of cutting a raise with a raise boring arrangement comprising a surface-mounted drilling unit from which a hollow drill string, comprising a plurality of hollow drill pipes fitted together, extends downwardly through a pre-drilled pilot hole, with a reamer head to cut the raise being fitted to the end of the drill string; stopping the cutting process; lowering a cable through the hollow drill string towards the bottom of the raise; fitting an inspection device at the bottom of the raise to the cable extending through the hollow drill string, the inspection device comprising a controller to receive data obtained by the inspection device; operating the inspection device so as to inspect the side wall below where the reamer head is cutting; communicating the data obtained by the inspection device to an inspection station; and determining whether maintenance is required on the side wall.

METHOD AND APPARATUS FOR OPTICAL SENSING

The present invention provides novel apparatus and methods for fast quantitative measurement of perturbation of optical fields transmitted, reflected and or scattered along a length of an optical fibre. The present invention can be used for point sensors as well as distributed sensors or the combination of both. In particular this technique can be applied to distributed sensors while extending dramatically the speed and sensitivity to allow the detection of acoustic perturbations anywhere along a length of an optical fibre while achieving fine spatial resolution. The present invention offers unique advantages in a broad range of acoustic sensing and imaging applications. Typical uses are for monitoring oil and gas wells such as for distributed flow metering and or imaging, seismic imaging, monitoring long cables and pipelines, imaging within large vessels as well as for security applications.

BACKSCATTERING SPECTROMETRY FOR DETERMINING A CONCENTRATION OF SOLIDS IN A SOLIDS-LADEN FLUID

An apparatus including an electromagnetic radiation source that emits electromagnetic radiation, a sample chamber comprising a fluid sample inlet for introducing a solids-laden fluid sample therein, and a detector that receives a backscattering signal and generates an output signal corresponding to a concentration of solids in the solids-laden fluid sample. The electromagnetic radiation transmits through the sample chamber and optically interacts with the solids-laden fluid sample to generate a backscattering signal. The sample chamber may include one or more of a shear bob for applying a shear rate to the solids-laden fluid sample, the shear bob suspended in the sample chamber and rotatable about an axis, a sealable fluid pressurizing inlet for pressurizing the sample chamber and a pressure gauge for measuring the pressure in the sample chamber when pressurized, and/or a temperature source for heating the solids-laden fluid sample.

BOREHOLE PROFILING AND IMAGING

A borehole instrument includes an image sensor for capturing images of an inside wall of a borehole. A borehole profile may also be measured by, for example, a laser. The same image sensor may be used for image capture and profile measurement. Different image sensors may be used for image capture and profile measurement. Image capture and profile measurement may be performed with reference to the same depth measurement, so that images and profiles are depth-aligned at capture. Orientation of the instrument within the borehole may also be measured to compensate for rotation of the instrument. A communications subsystem can transmit image data, profile data, and orientation data to a computer located outside the borehole for storage and analysis.

CORE AND DRILL BITS WITH INTEGRATED OPTICAL ANALYZER

A disclosed method for obtaining a core sample includes directing light at a core sample being collected, receiving reflected light from the core sample, and analyzing the received reflected light to determine one or more characteristics of the core sample and/or form an image of the core sample. Characteristics include rock type, hydrocarbon type, water concentration, porosity, and permeability. The light may be infrared (IR), visible, and/or ultraviolet (UV). The received reflected light may be passed through one or more multivariate optical elements (MOEs). Measurements made at two different positions on the core sample may be used to determine a coring rate. A described coring bit includes a barrel to receive a core sample, a light source illuminating the core sample as it enters the barrel, a detector system that receives reflected light from the core sample, and an optical transmission system communicating light to and from the core sample.

WELL DRILLING METHODS WITH AUDIO AND VIDEO INPUTS FOR EVENT DETECTION

A well drilling method can include sensing at least one of audio and optical signals, generating a parameter signature during a drilling operation, the parameter signature being based at least in part on the sensing, and detecting a drilling event by comparing the parameter signature to an event signature indicative of the drilling event. A well drilling system can include a control system which compares a parameter signature for a drilling operation to an event signature indicative of a drilling event, the parameter signature being based at least in part on an output of at least one audio and/or optical sensor, and a controller which controls the drilling operation in response to the drilling event being indicated by at least a partial match between the parameter signature and the event signature.

INSPECTION APPARATUS FOR TUBULAR MEMBERS

INSPECTION APPARATUS FOR TUBULAR MEMBERS An inspection apparatus for the internal inspection of tubular members has a body 1 adapted for insertion into the tubular member and the body has an inspection window 2. A projection means including a laser 14 and associated reflectives 13, 10 and 9, the reflective 9 being rotated by a motor 7, is directed such that a beam of radiant energy is directed through the window to illuminate an axial extending strip of the entire 360.degree. interior circumference of the tubular member. Light reflected from the tubular member passes through the window 2 and is reflected by reflective 8 onto a camera 12 which, via transmitting circuitry 16 transmits the image ring C and the light reflected by the window B back to a monitor 51 at the well head and to a computer 52 where the data transmitted from the camera is correlated with predetermined data values to determine damage to the interior surface of the tubular member such as ovality or corrosion. Where the ...

AUTONOMOUS DOWNHOLE OILFIELD TOOL

An autonomous downhoIe oilfield tool having its own mobility and decision making capability so that it may be deployed in a downhole environment to monitor and control said environment by modifying operations of other devices and maintaining downhole structures.

FIBER OPTIC MONITORING OF SAND CONTROL EQUIPMENT VIA TUBING STRING

A method and apparatus are disclosed which enhance the ability to control fi ne sand production in a production well. The invention operates to optimize san d control equipment by monitoring the installation, integrity and performance thereof. Monitoring is achieved by the apparatus of the invention which comprises optical fibers, with or without integrated sensors, disposed in a particular arrangement related both to the particular resolution capability of the optical equipment and th e parameters to be measured.

Background sounding apparatus.

Die Erfindung betrifft ein verbessertes Untergrundsondiersystem, bei dem verschiedene Bohrrohreinsatz-Module (30, 33) vorgesehen sind, um effizient und diagnosesicher Sondierdaten zu generieren und integriert darzustellen. Insbesondere betrifft die Erfindung ein optisches Bohrrohreinsatz-Modul zur Aufzeichnung von Bildern aus dem Bohrloch.

aparelhos e métodos para gerar imagens de tempo de residência no setor de ferramentas de fundo de poço

Core sample holder

A sample holder that can withstand high pressures and temperatures is disclosed. The sample holder can be used to subject a geological sample to the same temperature and pressure that the sample would experience in its native underground environment. The sample holder provides a mechanism for hydrostatically confining the rock core sample to simulate the below ground pressure, while simultaneously allowing fluid to be directed through the core, as needed. The material used for the housing of the sample holder, specifically ceramic zirconia, and the mechanism by which the end fixtures are mounted in the housing, e.g., a square thread or modified square thread, allow for operation at higher pressures and temperatures than is offered by currently available systems. The sample holder can be used to analyze rock core samples via NMR spectroscopy or MRI.

Method and apparatus for ultrasonic scanning of a borehole having improved sensor array and timing circuit

A borehole televiewer is modified to provide an improved signal-to-noise ratio by utilizing a series of receivers arranged in a planar array configuration with respect to a centrally located transmitting transducer. The array covers at least a 90 DEG quadrant of the tool, extending approximately 45 DEG on either side of the transducer to allow the receivers to capture all primarily reflected signals, both the specular component as well as the vertical and horizontal components of the scattered reflections. The signal-to-noise ratio is further enhanced by the use of a noise-dependent timing means, as well as signal conditioning and detection circuits for each of the receivers in the array.

Downhole reeled tubing inspection system with fiberoptic cable

A system for the inspection of a well borehole and the formation around the borehole. The system includes a pair of concentric reeled tubings for injecting a pair of fluids into a wellbore through a wellhead, one of said fluids being an optically transparent or acoustically homogenous fluid which forms a slug of said fluid around an optical sensor which transmits signals indicative of well conditions to the surface. The other of said fluids is used to perform functions with respect to said sensor such as cooling said sensor or protect it from a corrosive environment. In addition, a fiberoptic cable construction in combination with the reel tubing is also disclosed.

Method for fluid identification and evaluation within wellbores using ultrasonic scanning

The flow of bubbles in a borehole within an active well is determined by using data from a borehole televiewer. A known discontinuous material is introduced into the borehole at a known distance from the borehole televiewer, and the elapsed time is determined between introduction and detection of the discontinuous material by the borehole televiewer.

Automatic dip picking in borehole images

The techniques and device provided herein relate to receiving, via a processor, image data representative of a borehole of a well. The technique may include generating dequantized image data based on the image data, such that the dequantized image data filters one or more artifacts present in a Hough transformed version of the image data. One or more dip orientations (inclination and azimuth) associated with one or more formation dips present in the image data may be determined based on the dequantized image data. The technique may also include performing an a-contration validation algorithm for for the one or more formation dips to verify whether at least a formation dip having the or one of the possible dip orientation is present at a predetermined measured depth in the image data.

WELLBORE PARTED CASING ACCESS TOOL

A wellbore tool includes a rotatable elongate pipe that includes a first elongate portion extending along a longitudinal axis of the elongate pipe. A first bending portion with a first end attaches to a downhole end of the first elongate portion. The first bending portion deviates from a longitudinal axis of the first elongate portion in a first direction. A second bending portion has a first end attached to a second end of the first bending portion. The second bending portion is positioned downhole of the first bending portion. The second bending portion deviates towards the longitudinal axis in a second direction different from the first direction. The first bending portion and the second bending are eccentric relative to the first elongate portion. The wellbore tool is rotated a set amount and stabbed in a downhole direction until the wellbore tool enters the parted casing.

Method and Apparatus for Utilizing Optically Clear Fluid for Acquiring Visual Data in Wellbore Environments

A fluid (30) of optically clear composition is used to create a viewing window within a wellbore (1), pipelines, tanks, vessels, or any other similar environment. Selective placement of optically clear fluid facilitates acquisition of visual images and/or other data in particular areas of interest within environments containing opaque or non-transparent fluids. Such optically clear fluid can displace opaque fluids and gases, while maintaining specific viscosity, weight, and other fluid properties in order to keep opaque fluids from encroaching into a viewing area while visual data acquisition is performed.

Electrical system for use with recording meters

DOWNHOLE WELL INTEGRITY RECONSTRUCTION IN THE HYDROCARBON INDUSTRY

The present disclosure describes methods and systems for downhole well integrity reconstruction in a hydrocarbon reservoir. One method for downhole well integrity reconstruction in a hydrocarbon reservoir includes: positioning, a laser head at a first subterranean location, wherein the laser head is attached to a tubular inside of a wellbore; directing, by the laser head, a laser beam towards a leak on the wellbore; and sealing the leak using the laser beam.

Verfahren und Vorrichtung zur Untersuchung der Wandung eines Bohrlochs in Gestein

INSTRUMENTENSONDE MIT RÜCKSEITIG BELEUCHTETER KAMERA

Sensor cover

A sensor cover (1) for an inspection assembly (3) is provided. The inspection assembly (3) is adapted to inspect the interior of a hollow member (5). The sensor cover (1) comprises a delimiting means (13.1, 13.2) configured to at least partially delimit a sensor cover volume (11.1, 11.2). The delimiting means (13.1, 13.2) comprises a flexible material and is configured to permit a modification of the sensor cover volume (11.1, 11.2) such that at least a portion of said delimiting means (13.1, 13.2) is closer to a portion of said hollow member wall (7) after said modification than before said modification to thereby enable said sensor signal to be transmitted from the hollow member wall (7) to the sensor (9). The present disclosure also relates to inspection assembly (3), a use of an inspection assembly (3), and a method (100) for inspecting the interior of a hollow member (5).

Sensor data compression for downhole telemetry applications

Device and method to position an end effector in a well

A downhole device includes a housing an imaging sensor (12a fig 5A) connected to the housing and being rotatable 28 thereto. The sensor includes a one-dimensional array of sensing elements along a longitudinal axis of the housing. An actuator is present to rotate the imaging sensor about the longitudinal axis relative to the housing. An imaging circuit captures and processes data received form the imaging sensor. The device is said to be capable of precise positioning 22, 24 movement of 1mm or less achieved by means of the imaging sensor being connected to the housing via a Delta robot and an end effector that allows for transverse movement.

Well site collaboration system with smart technology

To reduce As difficulties associated with sub-site collaboration in hydrocarbon recovery, exploration, operation, or services environments, on-site collaboration between users is provided by including a multi-location virtual collaboration and.monitoring system that enables multi- location virtual collaboration, monitoring, and data sharing, between users at sub-sites In. hydrocarbon recovery, exploration operation, or services environments. A. user may.access real- time and stored data using one or more wearable or portable devices. Further, a user rmay configure data provision and data provision preferences for consumption of data In a variety of formats.

Method and apparatus for real time streaming and onboard recordation of video data

A method and apparatus for visual inspection of wellbore environments wherein a real-time video feed is received at the earth's surface from a camera assembly positioned downhole within a wellbore. The camera system is capable of recording high quality video images in full streaming quality and speed in either color or black and white bands, simultaneously transmitting live visual images to the earth's surface, and accepting and acting upon commands from the surface (including, without limitation, recording programmability).

Method And Apparatus For Determining Topography Within Awellb re Environment

A method for determining topography within a wellbore environment comprises locating a probe in a wellbore, directing a beam of light from the probe onto a plurality of positions of a target region within a wellbore environment, detecting light reflected from a plurality of positions of the target region and analysing the detected light to determine a topography of the target region. Light may be directed onto the plurality of positions of the target region at the same time and/or at different times. Such a method may permit features in the wellbore environment to be monitored, or may permit a requirement for maintenance of the wellbore environment to be identified and/or a life-span of the wellbore environment to be predicted. An apparatus for determining topography within a wellbore environment is also disclosed.

Side view downhole camera and lighting apparatus and method

Downhole tool system

A downhole tool system which comprises a downhole tool connected for fluid communication to a continuous reel of tubing (1), drill pipe or conventional tubing via a pressure-tight connector (5) for flowing fluids between the formation, the tool and the surface, the downhole tool being in electrical communication with the surface (4).

Methods of electromagnetic migration imaging of geologic formation

Methods and systems for imaging-while-drilling and look-ahead imaging of a geological formation using a borehole devices measuring multi-component vector and/or tensor logging data. An electromagnetic field transmitter generates an electromagnetic field. Electromagnetic receivers measure the response from the geological formation around the borehole and ahead of the device at various receiving positions. A central processing unit may compute a migration field by simulating the replacement of the receivers with conceptual transmitters, calculate an integrated sensitivity of the recorded electromagnetic field data, compute a reference field, and calculate a cross power spectra of the reference and the migration fields or cross correlation functions between the reference and the migration fields. A spatial weighting of the cross power spectra or cross correlation functions produces a numerical reconstruction of directional images and look-ahead images of the conductivity distribution around the borehole and/or ahead of the device located within the borehole.

System and method for generation of alerts and advice from automatically detected borehole breakouts

A method for generating an alert or advice for drilling a borehole penetrating an earth formation includes: receiving with a processor a borehole image from a downhole tool disposed at a drill tubular drilling the borehole; detecting a first breakout and a second breakout shifted approximately 180° apart from the first breakout if breakouts are in the image using a method for detecting breakouts implemented by the processor; and generating an alert or advice with the processor if the first and second breakouts are detected.

Methods for Fluid Monitoring in a Subterranean Formation Using One or More Integrated Computational Elements

Methods for fluid monitoring in a subterranean formation can comprise: providing a diverting fluid comprising a diverting agent; introducing the diverting fluid into a subterranean formation comprising one or more subterranean zones; and monitoring a disposition of the diverting fluid within the subterranean formation using one or more integrated computational elements in optical communication with the subterranean formation.

Downhole Digital Survey Camera

A digital camera surveying system and method allows digital images of other surveying tools, such as an inclinometer and gyro compass, to be captured during surveying. The digital camera provides a protective housing securing a lens assembly and flash lap positioned to capture images of other surveying tools. Further, the protective housing may also provide an interface window that allows an operator to command operation of the digital camera and to connect external devices to the digital camera.

Systems and Methods for Computing Surface of Fracture per Volume of Rock

Systems and methods for estimating surface of fracture per volume of rock are provided. The systems include a logging tool, such as a resistivity tool, for generating a borehole image representative of segments of fractures in one or more planes and a processor for estimating surface of fracture per volume of rock (P 32 ) from the segments without the need for defining the one or more planes bearing the segments. The methods include using a downhole logging tool, such as a resistivity tool, to collect data corresponding to segments of fractures in one or more planes, and estimating surface of fracture per volume of rock (P 32 ) by reconstructing theoretical elliptical fractures from the segment data, calculating length of fracture segment per surface of borehole (P 21 ) for the theoretical elliptical fractures, and deriving P 32 from P 21 .

DEVICES AND METHODS FOR IMAGING WELLS USING PHASED ARRAY ULTRASOUND

Methods and devices for imaging wells using phased array ultrasound imaging devices is described. The devices enable high resolution real-time imaging of a well during various operations in the well, including during completions, fracturing, milling, fishing and drilling operations. The phased array ultrasound imaging devices may be integrated with other well tools, such as a bottom hole assembly (BHA), fishing tools, milling tools, fracturing tools, and drilling tools, in order to integrate imaging capabilities into such tools. 1. A method for imaging an in-situ heavy oil well production liner string comprising the steps of:a) inserting a phased array ultrasound imaging system into the well before the well is placed on production;b) moving the imaging system through the liner string in a substantially horizontal section of the well while activating the imaging system to generate a three dimensional image of the liner string; andc) assessing the condition liner string using the three-dimensional image of the liner string.2. The method as in claim 1 , wherein the phased array ultrasound imaging system has a ring-shaped or radial transducer.3. The method as in wherein steps a) and b) are undertaken during a well completions process.4. The method as in claim 1 , wherein the well contains water claim 1 , brine claim 1 , water-based drilling mud claim 1 , oil-based drilling mud or production fluids.5. The method as in claim 1 , wherein the imaging system includes a ranging system operatively connected to the imaging system claim 1 , and steps a) and b) occur during ranging operations as a second well is being drilled adjacent to the well claim 1 , and/or after ranging operations have been completed and the imaging system and ranging system are being removed from the well.6. A device for imaging an in-situ heavy oil well production liner string during completions operations comprising:a body adapted for movement through the liner string;a downhole tractor operatively ...

Methods and Means for the Measurement of Tubing, Casing, Perforation and Sand-Screen Imaging Using Backscattered X-ray Radiation in a Wellbore Environment

An x-ray-based cased wellbore tubing and casing imaging tool is disclosed, the tool including at least a shield to define the output form of the produced x-rays; a two-dimensional per-pixel collimated imaging detector array; a parallel hole collimator format in one direction that is formed as a pinhole in another direction; Sonde-dependent electronics; and a plurality of tool logic electronics and PSUs. A method of using an x-ray-based cased wellbore tubing and casing imaging tool is also disclosed, the method including at least: producing x-rays in a shaped output; measuring the intensity of backscatter x-rays returning from materials surrounding a wellbore; determining an inner and an outer diameter of tubing or casing from the backscatter x-rays; and converting image data from said detectors into consolidated images of the tubing or casing. 1. An x-ray-based cased wellbore tubing and casing imaging tool , said tool comprising:a shield to define the output form of the produced x-rays;a two-dimensional per-pixel collimated imaging detector array;a parallel hole collimator format in one direction that is formed as a pinhole in another direction;Sonde-dependent electronics; anda plurality of tool logic electronics and PSUs.2. The tool of claim 1 , wherein said imaging detector comprises a two-dimensional per-pixel collimated imaging detector arrays claim 1 , wherein the imaging array is one pixel wide and multiple pixels long.3. The tool of claim 1 , wherein said imaging detectors comprise two sets of two-dimensional per-pixel collimated imaging detector arrays.4. The tool of claim 1 , wherein said imaging detectors comprise a plurality of two-dimensional per-pixel collimated imaging detector arrays.5. The tool of claim 1 , wherein the images contain spectral information to inform characteristics of any wellbore materials or debris.6. The tool of claim 1 , wherein said shield further comprises tungsten.7. The tool of claim 1 , wherein the tool is configured so as to ...

CHANNEL DETECTION SYSTEM AND METHOD

Systems, methods, and computer-readable media are provided for detecting a channel behind casing and generating an image that represents the channel. An example method can include receiving data samples associated with at least one casing, each data sample representing channel information behind a representative casing, training a machine learning model using the data samples to generate a mapping between waveform information in each of the data samples and the channel information behind the representative casing, receiving acoustic data from a tool, the acoustic data representing a particular casing, and using the machine learning model to analyze the acoustic data from the tool and determine one of a presence and an absence of a channel behind the particular casing at a plurality of depths. 1. A method comprising:receiving, by at least one processor, data samples associated with at least one casing, each data sample representing channel information behind a representative casing;training, by the at least one processor, a machine learning model using the data samples to generate a mapping between integral amplitudes calculated from waveform information in each of the data samples and the channel information behind the representative casing, wherein at least one integral amplitude is calculated by rectifying the waveform information, determining a peaks-based envelope of the rectified waveform information, using the peaks-based envelope to modulate a sinusoid signal, and integrating a period of the sinusoid signal to obtain the integral amplitude;receiving, by the at least one processor, acoustic data from a tool, the acoustic data representing a particular casing;calculating a plurality of integral amplitudes based on the acoustic data from the tool; andusing, by the at least one processor, the machine learning model to analyze the calculated plurality of integral amplitudes from the acoustic data and determine one of a presence and an absence of a channel behind ...

Downhole Imaging Systems and Methods

Downhole Camera systems and methods. Certain systems include a high-speed video camera configured with a 360 degree optical field-of-view, a jet-flushing system capable of temporarily displacing debris substantially simultaneously along all azimuths within the optical field-of-view, and optionally a downhole real-time image processing system for reducing the amount of captured video transmitted to surface. Certain methods include capturing a set of images downhole using a high-speed video camera having a 360 degree optical field-of-view, substantially simultaneously temporarily displacing debris in the optical field-of-view for at least a portion of the time the camera is capturing video using a jet-flushing system capable of projecting flushing fluid substantially simultaneously along all azimuths in the borehole. The methods may also involve pre-processing the set of images to reduce the number of images or reduce the amount of information transmitted to surface.

ANALYSIS OF DRILLING SLURRY SOLIDS BY IMAGE PROCESSING

Analysis of drilling slurry solids by image processing includes receiving images of a solid slurry including a mixture of wellbore drilling mud and solid objects found in the wellbore while drilling the wellbore through a subterranean zone. The solid objects include drill cuttings and non-drilled solids. By implementing image processing techniques on the images, the solids in the solid slurry are classified a drill cutting or as a non-drilled solid. 1. A system comprising:a digital imaging device mounted to a non-vibrating member of a shale shaker of a wellbore drilling assembly, the shale shaker positioned at a surface of the Earth adjacent a wellbore and configured to receive a solid slurry comprising a mixture of wellbore drilling mud and solid objects found in the wellbore while drilling the wellbore through a subterranean zone, the solid objects comprising drill cuttings and non-drilled solids, the digital imaging device oriented to face a portion of the shale shaker that receives the solid slurry, the digital imaging device configured to capture digital images of the solid objects while the solid slurry is received by the shale shaker; and one or more processors; and', receiving the images captured by the digital imaging device; and', 'by implementing image processing techniques on the images, classifying a first solid object captured in a first image as a drill cutting and a second solid object captured in a second image as a non-drilled solid., 'a computer-readable medium storing instructions executable by the one or more processors to perform operations comprising], 'a computer system operatively coupled to the digital imaging device, the computer system comprising2. The system of claim 1 , wherein an image of a solid object comprises a plurality of particles including particles representing the solid object in a first color and particles representing remaining portions of the image in a second color different from the first claim 1 , wherein claim 1 , to ...

MARINE TO BOREHOLE ELECTROMAGNETIC SURVEY

Methods of marine to borehole measurement may include dispersing one or more borehole receivers in one or more boreholes; distributing one or more marine receivers in marine water at a seabed; immersing an electromagnetic dipole source in the marine water above the seabed; energizing the electromagnetic dipole source; measuring one or more borehole signal measurements using the one or more borehole receivers and one or more seabed signal measurements using the one or more marine receivers; and determining a three-dimensional property distribution of a reservoir of interest by processing the one or more borehole signal measurements and the one or more seabed signal measurements. 1. A method , comprising:dispersing one or more borehole receivers in one or more boreholes;distributing one or more marine receivers in marine water at a seabed;immersing an electromagnetic dipole source in the marine water above the seabed;energizing the electromagnetic dipole source;measuring one or more borehole signal measurements using the one or more borehole receivers and one or more seabed signal measurements using the one or more marine receivers; anddetermining a three-dimensional property distribution of a reservoir of interest by processing the one or more borehole signal measurements and the one or more seabed signal measurements.2. The method of claim 1 , further comprising:designing a drilling operation or secondary recovery operation based on the three-dimensional property distribution.3. The method of claim 1 , wherein the three-dimensional property distribution is selected from a group consisting of: three-dimensional electromagnetic property distribution claim 1 , three-dimensional resistivity distribution claim 1 , three-dimensional induced polarization distribution claim 1 , three-dimensional anisotropy distribution claim 1 , three-dimensional saturation distribution claim 1 , three-dimensional fracture distribution claim 1 , three-dimensional permeability distribution ...

Distributed nondestructive structural defects detection in slickline cables

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

SELF-POWERED SENSORS FOR DETECTING DOWNHOLE PARAMETERS

A self-powered sensor array (SPSA) for sensing environmental parameters along a drillstring includes an outer collar having moveable member retainers with moveable members movably located in the moveable member retainers. An inner ring is rotatably supported within the outer collar with bearing elements on an outer surface of the inner ring positioned to displace the moveable members relative to the moveable member retainers in response to relative rotation between the inner ring and the outer collar. Shape memory material elements are arranged in a respective moveable member retainer. Distance sensors are configured to sense a gap responsive to a shape change of the respective shape memory material element and a displacement of the respective moveable member. Power generation components are configured such that, in response to the relative rotation, the bearing elements displace a particular moveable member into a particular moveable member retainer, generating an electric charge. 1. A sensor array for sensing environmental parameters along a drillstring , the sensor array comprising:an outer collar having a plurality of moveable member retainers formed therein;a plurality of moveable members movably disposed in the plurality of moveable member retainers;an inner ring rotatably supported within the outer collar;a plurality of bearing elements retained on an outer surface of the inner ring, the plurality of bearing elements positioned to displace the plurality of moveable members relative to the plurality of moveable member retainers in response to relative rotation between the inner ring and the outer collar;a plurality of shape memory material elements, each shape memory material element arranged in one of the plurality of moveable member retainers; anda plurality of distance sensors, each distance sensor disposed in a respective moveable member retainer of the plurality of moveable member retainers and between a respective shape memory material element in the ...

DOWNHOLE COMPLETION ASSEMBLY FOR EXTENDED WELLBORE IMAGING

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

MEASURING SEALING QUALITY OF CONNECTIONS IN DOWNHOLE CASINGS

A method and system for inspecting casings in a wellbore to determine a mechanical or sealing quality of casing connections. Casing connections may become mechanically weak or start to leak after some period of use in harsh conditions. A radial array of ultrasound transducers images the casing in-situ to create an ultrasound image, which is analyzed to detect the casing connector then analyzed a sealing band of the connector. Machine learning and image processing methods may be used to analyze the images. 1. A method of inspecting a wellbore comprising:deploying an imaging tool into and axially through casings of the wellbore;imaging the casing with a radial array of ultrasound transducers to create an ultrasound image;analyzing the ultrasound image to detect features that identify a casing connector;locating a band of the ultrasound image at a predetermined offset from the detected features; andanalyzing the band of the image to determine a connection quality of the casing connector to the casing.2. The method of claim 1 , wherein the band is a sealing band next to the features which sealing band corresponds to a metal-to-metal sealing interface between the casing and a casing connector andwherein analyzing the band of the image comprises determining a sealing quality of the casing connector to the casing.3. The method of claim 1 , wherein the band corresponds to a plurality of threads connecting the casing and casing connector andwherein analyzing the band of the image comprises determining a mechanical connection strength of the casing connector to the casing.4. The method of claim 1 , wherein the feature of the casing connector is at least one of: threads claim 1 , a torque shoulder claim 1 , and a dope relief.5. The method of claim 1 , further comprising filtering out reflections in the ultrasound image from the inner and/or outer surfaces of the casing.6. The method of claim 1 , further comprising converting a magnitude of reflection energy in the ultrasound ...

Multi-Run Retrievable Battery Pack for Electronic Slickline Tools

A downhole tool assembly includes a downhole tool and an anchor. The anchor is positionable at a downhole work site and includes a wet-connect port for engaging a battery pack. The tool operates until the battery runs low on power, when a low battery power alert is activated. The tool may be anchored at the work site while the battery is disconnected and retrieved to the surface for replacement. One or more charged batteries are then deployed and connected to the tool without having to remove the tool from the worksite or reposition the tool. The tool may be coupled to a wireline cable or a slickline cable or coiled tubing having a conductive wire for delivering low-voltage power to the tool. While the low-voltage power may not be adequate to operate the tool at full load, the power may be used to charge the tool during downtime.

System and console for monitoring and managing well site operations

A well advisor system and console for monitoring and managing well drilling and production operations. The system may be accessed through one or more workstations, or other computing devices, which may be located at a well site or remotely. The system is in communication with and receives input from various sensors. It collects real-time sensor data sampled during operations at the well site. The system processes the data, and provides nearly instantaneous numerical and visual feedback through a variety of graphical user interfaces (“GUIs”), which are presented in the form of an operation-specific console. The input and data provides information related to geologic uncertainty concerning a well being drilled, with a focus on the safety of the drilling operation.

Systems and methods for hydraulic fracture treatment and earth engineering for production

Provided herein are systems and methods for hydraulic fracturing in earth. Systems may comprise a first well comprising sensors configured to collect sensor data at the first well. The calibration data may comprise sensor data, hydraulic fracture treatment conditions of the first well, geological data from an area containing the first well, or production date of oil or gas from the first well. The calibration data may be analyzed with the aid of one or more processors to generate an integrated 3-D model of hydraulic fracturing and fluid flow in the wellbore and reservoir of the first well. The system may further comprise a second well configured to operate according to simulation data generated from the integrated 3-D model of the first well and hydraulic fracture treatment conditions received from a user device. The user device may be configured to communicate with a server comprising the one or more processors.

Cement evaluation using neutron tool

A method for evaluating cement in a cased wellbore in a geological formation includes placing a downhole tool into the cased wellbore, where the cased wellbore has been cased using a cement that contains a particular material. The method includes emitting neutrons using the downhole tool, wherein the neutrons interact with the particular material via inelastic scattering or capture of neutrons and cause the material to emit an energy spectrum of the gamma rays associated with the material or wherein the time-based measurement of gamma rays or neutrons is influenced by the presence of the material. The method includes using the downhole tool to detect radiation radiation, such as the energy spectrum of the gamma rays, or a die-away pattern of the gamma rays or neutrons that indicates a presence of the particular material and enable to estimate a parameter of the cement.

Improved structural modelling

A method of calculating the likely positions of structures in a region of the earth's crust includes defining the region in the earth's crust; creating a first structural model of the region from seismic data with uncertainties and correlations; creating a second structural model of the region from measurements in a wellbore with uncertainties and correlations; creating a third structural model of the region from measurements in a volume around the wellbore measured from the wellbore with uncertainties and correlations; defining constraining equations for the first, second and third structural models; and using said constraining equations, calculating likely positions of structures in the region, and likely uncertainties and correlations relating to the positions.

Deep Structural Dip Determination And Improved Reflection Imaging Using Full-Waveform Borehole Sonic Data

The present disclosure relates to borehole sonic logging and, more particularly to, improved reflection imaging of formation structures away from the wellbore. A method for borehole sonic reflection imaging may comprise: disposing a borehole sonic logging tool in a wellbore, wherein the borehole sonic logging tool comprises one or more transmitters and one or more receivers; emitting sound waves from the one or more transmitters; receiving sound waves at the one or more receivers to obtain borehole sonic data; separating up-going arrivals in the borehole sonic data from down-going arrivals in the borehole sonic data; generating a first reflection image based at least on the borehole sonic data; estimating a relative dip angle of a formation bed from the first reflection image; generating an updated velocity model based at least on the relative dip angle; and generating an updated reflection image based at least on the updated velocity model. 1. A method for borehole sonic reflection imaging , comprising:disposing a borehole sonic logging tool in a wellbore, wherein the borehole sonic logging tool comprises one or more transmitters and one or more receivers;emitting sound waves from the one or more transmitters;receiving sound waves at the one or more receivers to obtain borehole sonic data;separating up-going arrivals in the borehole sonic data from down-going arrivals in the borehole sonic data;generating a first reflection image based at least on the borehole sonic data;estimating a relative dip angle of a formation bed from the first reflection image;generating an updated velocity model based at least on the relative dip angle; andgenerating an updated reflection image based at least on the updated velocity model.2. The method of claim 1 , wherein the generating a first reflection image comprises separately imaging the up-going arrivals and the down-going arrivals to generate images from measurements on either side of a bed boundary and then combining the images ...

DEVICE AND METHOD FOR OPTICAL ANALYSIS USING MULTIPLE INTEGRATED COMPUTATIONAL ELEMENTS

A method including generating integrated computational element (ICE) models and determining a sensor response as the projection of a convolved spectrum associated with a sample library with a plurality of transmission profiles determined from the ICE models. The method includes determining a regression vector based on a multilinear regression that targets a sample characteristic with the sensor response and the sample library and determine a plurality of regression coefficients in a linear combination of ICE transmission vectors that results in the regression vector. The method further includes determining a difference between the regression vector and an optimal regression vector. The method may also include modifying the ICE models when the difference is greater than a tolerance, and fabricating ICEs based on the ICE models when the difference is within the tolerance. A device and a system for optical analysis including multiple ICEs fabricated as above, are also provided. 1. A method , comprising:generating a plurality of integrated computational element (ICE) models;determining a sensor response from a projection of a plurality of ICE transmission vectors associated with the plurality of ICE models and a convolved spectrum associated with a sample library;determining a regression vector based on a multilinear regression that targets a sample characteristic from the sample library and the sensor response;determining a plurality of regression coefficients in a linear combination of the plurality of ICE transmission vectors that results in the regression vector;determining a difference between the regression vector and an optimal regression vector associated with the sample characteristic;modifying the plurality of ICE models when the difference between the regression vector and the optimal regression vector is greater than a selected tolerance; andfabricating a plurality of ICEs based on the plurality of ICE models when the difference between the regression vector ...

An Electromagnetic Insulating Component Used In Well Logging Tool Pad

A downhole tool, comprising: a tool mandrel; a pad comprising a transmitter operable to transmit an electric current into a formation and a receiver operable to receive at least a portion of the electric current from transmitter; an extension from the tool mandrel that couples pad to tool mandrel; and a signal filter positioned in the downhole tool to suppress passage of mandrel leakage current that passes through tool mandrel to pad. A method of resistivity imaging, comprising: disposing a downhole tool into borehole; transmitting a current into formation surrounding the borehole with a transmitter that is extended from tool mandrel of the downhole tool towards borehole wall; and recording at least a portion of the current that returns to receiver of downhole tool, wherein a signal filter suppress passages of mandrel leakage current that passes through the tool mandrel to a pad on which the transmitter is disposed.

A Method For Improving The Accuracy Of Mud Angle Measurements In Borehole Imagers

A method and system for estimating a mud angle. A method may comprise disposing a downhole tool into a borehole, energizing a button array, transmitting a current from the electrode into a formation, recording the current from the formation with a return electrode to obtain a plurality of measurements, identifying at least one low resistivity zone from the plurality of measurements to produce a measurement set, inverting the measurement set to find a mud angle vector, removing the mud angle vector from the measurement set to obtain a corrected measurement, and obtaining an electrical image using the corrected measurement. A system may comprise a downhole tool, a conveyance, and an information handling system. The downhole tool may further comprise at least one electrode and at least one return electrode. 1. A method for estimating a mud angle , comprising:disposing a downhole tool into a borehole;energizing a button array, wherein the button array comprises at least one electrode;transmitting a current from the electrode into a formation;recording the current from the formation with a return electrode to obtain a plurality of measurements;identifying at least one low resistivity zone from the plurality of measurements to produce a measurement set;inverting the measurement set to find a mud angle vector;removing the mud angle vector from the measurement set to obtain a corrected measurement; andobtaining an electrical image using the corrected measurement.2. The method of claim 1 , further comprising inverting the measurement set with an iterative inversion scheme.3. The method of claim 2 , wherein the iterative inversion scheme further comprises calculating a cost function with the measurement set and performing a convergence test.6. The method of claim 3 , wherein if a condition is met in the convergence test the mud angle is found.7. The method of claim 1 , further comprising inverting the measurement set by finding the mud angle vector that maximizes a ...

Method For Resistivity Determination With Borehole Imagers

A method and system for resistivity imaging. A method may comprise disposing a downhole tool into a borehole, applying a voltage difference between the array of injector electrodes, constructing a first set of formation images for each of the plurality of frequencies, applying a mud effect removal algorithm to produce a second set of formation images for each of the plurality of frequencies, applying a dielectric correction algorithm to each of the plurality of frequencies to produce a third set of formation images for each of the plurality of frequencies, and combining the first set of formation images, the second set of formation images, and the third set of formation images to obtain a blended image. A system for resistivity imaging may comprise a downhole tool. The downhole tool may comprises a pad, an array of injector electrodes, and one or more return electrodes. 1. A method of resistivity imaging , comprising: a pad;', 'an array of injector electrodes; and', 'one or more return electrodes;, 'disposing a downhole tool into a borehole, wherein the downhole tool comprisesapplying a voltage difference between the array of injector electrodes and the one or more return electrodes with a plurality of frequencies;making an impedance measurement with the array of injector electrodes for each of the plurality of frequencies;constructing a first set of formation images for each of the plurality of frequencies;applying a mud effect removal algorithm to produce a second set of formation images for each of the plurality of frequencies;applying a dielectric correction algorithm to each of the plurality of frequencies to produce a third set of formation images for each of the plurality of frequencies; andcombining the first set of formation images, the second set of formation images, and the third set of formation images to obtain a blended image.2. The method of claim 1 , wherein only two of the first set of formation images claim 1 , the second set of formation images ...

Mapping a fracture geometry

A fracture geometry mapping method includes determining a value of a diffusive tortuosity in a first direction in a first rock sample from a subterranean formation with one or more hardware processors; determining a value of a diffusive tortuosity in a second direction in the first rock sample from the subterranean formation with the one or more hardware processors, the second direction orthogonal to the first direction in the first rock sample; determining a value of a diffusive tortuosity in third direction in the first rock sample from the subterranean formation with the one or more hardware processors, the third direction orthogonal to both the first direction and the second direction in the first rock sample; comparing the values of the diffusive tortuosities in the in the first direction, the second direction, and the third direction; and based on the comparison, generating a first fracture network map of the subterranean formation, the first fracture network map including a first plurality of anisotropic fracture pathways.

CORE-LEVEL HIGH RESOLUTION PETROPHYSICAL CHARACTERIZATION METHOD

A method for characterizing a subsurface formation includes receiving image data of the subsurface formation obtained by a sensor tool and receiving a plurality of non-image data logs, each non-image data log being obtained by a different type of sensor tool. The method also includes performing an electrofacies analysis on the plurality of non-image data logs where the electrofacies analysis includes defining clusters wherein each cluster has a similar property to provide a plurality of electrofacies blocks with each electrofacies block representing a depth interval. The method further includes partitioning the image data into multiple high-resolution depth segments that share a similar property, feature, and/or pattern for each electrofacies block and assigning data from the plurality of non-image data logs into a corresponding high-resolution depth segment to provide a high-resolution data log that characterizes the subsurface formation. 1. A method for characterizing a subsurface formation , the method comprising:receiving image data of the subsurface formation, the image data obtained using a sensor tool;receiving a plurality of non-image data logs, each non-image data log being obtained by a different type of sensor tool;performing an electrofacies analysis on the plurality of non-image data logs, the electrofacies analysis comprising defining clusters wherein each cluster has a similar property to provide a plurality of electrofacies blocks, each electrofacies block representing a depth interval;partitioning the image data into multiple high-resolution depth segments that share a similar property, feature, and/or pattern for each electrofacies block; andassigning data from the plurality of non-image data logs into a corresponding high-resolution depth segment to provide a high-resolution data log that characterizes the subsurface formation.2. The method according to claim 1 , further comprising:performing a quality check on the high-resolution data log; ...

METHOD AND APPARATUS OF UNTETHERED CASING AND BORE HOLE SURVEY THROUGH THE DRILL STRING WHILE TRIPPING OUT DRILL PIPE

A method for measuring the thickness of casing in a wellbore and/or analyzing the inner surface of the cased or non-cased wellbore. The method includes an positioning an untethered logging tool in a drill string, receiving the logging tool in a catcher positioned within the drill string, positioning a plurality ultrasonic transducers with the average distance between the outer surface of the plurality of transducers and an interior surface of the catcher sub being less than 0.8 mm, and moving the drill string and the logging tool toward a mouth of the borehole while transmitting acoustic waves through the catcher sub toward the wellbore casing and receiving acoustic waves back to the logging tool after the acoustic waves interact with the wellbore casing and reflect through the catcher. 1. A method for measuring the thickness of casing in a wellbore and/or analyzing the inner surface of the cased or non-cased wellbore , comprising:positioning a drill string in a wellbore;positioning an untethered logging tool in the drill string;pumping fluid into the drill string so that the fluid pushes the logging tool toward a distal end of the drill string so that the logging tool moves in an untethered manner;receiving the logging tool in a catcher positioned within the drill string;positioning a plurality ultrasonic transducers with the average distance between the outer surface of the plurality of transducers and an interior surface of the catcher sub being less than 0.8 mm;moving the drill string and the logging tool toward a mouth of the borehole;while moving the drillstring and the logging tool toward a mouth of the borehole, transmitting acoustic waves through the catcher sub toward the wellbore casing with the logging tool and receiving acoustic waves after the acoustic waves interact with the wellbore casing and reflect back to the logging tool through the catcher; andwhile moving the drill string and the logging tool toward the mouth of the borehole, processing and ...

Sparse Deconvolution And Inversion For Formation Properties

The disclosure relates generally to the inversion of geophysical and/or logging measurements for formation evaluation and monitoring. The disclosure may be related to methods of deconvolution and/or inversion of piecewise formation properties. A method for formation evaluation from a downhole tool may comprise disposing a downhole tool into a wellbore, broadcasting a signal into a formation penetrated by the wellbore, recording the signal from the formation with at least one receiver disposed on the downhole tool, computing an objective function, and determining formation properties by minimizing the objective function.

A Method for Combined Resistivity and Permitivity Determination with Borehole Imagers

A method and system for resistivity imaging may comprise disposing a downhole tool into a borehole, wherein the downhole tool comprises a pad and a plurality of electrodes disposed on the pad, taking an impedance measurement with the plurality of electrodes, applying a correction to the measured impedance by using a relaxation constant of the measured impedance to find a corrected impedance for each electrode of the plurality of electrodes, and constructing an image from the corrected impedance, wherein the image maps formation impedance. The system for resistivity imaging may comprise a downhole tool, a conveyance for disposing the downhole tool in a borehole, and an information handling system. The downhole tool may further comprise an arm and a pad wherein the pad comprises a plurality of electrodes and at least one return electrode. 1. A method of resistivity imaging , comprising:disposing a downhole tool into a borehole, wherein the downhole tool comprises a pad and a plurality of electrodes disposed on the pad;taking an impedance measurement with the plurality of electrodes;applying a correction to the measured impedance by using a relaxation constant of the measured impedance to find a corrected impedance for each electrode of the plurality of electrodes; andconstructing an image from the corrected impedance, wherein the image maps formation impedance.2. The method of claim 1 , wherein the corrected impedance is found from Z=Z(1−j tan(ϕ)).3. The method of claim 1 , further comprising dividing a real part of the corrected impedance with a tool constant to estimate a formation resistivity estimate.4. The method of claim 3 , where the tool constant is a function of corrected impedance.5. The method of claim 3 , further comprising estimating a formation permittivity from the relaxation constant of the measured impedance and the formation resistivity estimate.7. The method of further comprising;measuring a property of a mud capable of being disposed borehole; ...

Method and apparatus for determining a fracture aperture in a wellbore

The disclosure relates to a method for determining a fracture aperture of at least a fracture aperture in a wellbore, comprising: Measuring a resistivity of the wellbore with a downhole tool in a wellbore for obtaining an image of the wellbore, Detecting at least a fracture in the wellbore, Calculating a fracture aperture of the detected fracture according to a predetermined model of the wellbore, the model being set up based on at least an hypothesis relative to the configuration of the wellbore, Estimating a correction to the predetermined model when at least one of the hypothesis is not met, Based on at least a measured parameter relative to the wellbore and on the correction, determining an uncertainty range for the fracture aperture

Ground treatment assistance method

Ground treatment assistance method comprising providing a machine comprising a ground treatment tool is provided, providing geographic coordinates of at least one treatment area, determining positioning data of the ground treatment tool using an optical acquisition device, displaying at least a first object representative of the ground treatment tool or of said at least one treatment area on a display device, and positioning said first object on the display device using the previously determined positioning data of the ground treatment tool and the geographic coordinates of said treatment area.

Passive Arm For Bi-Directional Well Logging Instrument

A downhole tool may comprise a tool body that is a structural support for the downhole tool, an upper arm attached at one end to the tool body, a pad attached at an opposite end of the upper arm, a lower arm attached at one end to a sliding block and attached to the pad at an opposite end of the lower arm, and a passive arm connected to the lower arm and the tool body. A method may comprise disposing a downhole tool into a borehole, applying a force to a passive arm, applying a second force from the passive arm to the lower arm in response to the force applied to the passive arm, and moving the lower arm and the passive arm in a longitudinal direction along an axis of the downhole tool. 1. A downhole tool comprising:a tool body that is a structural support for the downhole tool;an upper arm attached at one end to the tool body;a pad attached at an opposite end of the upper arm;a lower arm attached at one end to a sliding block and attached to the pad at an opposite end of the lower arm; anda passive arm connected to the lower arm and the tool body.2. The downhole tool of claim 1 , further comprising one or more pins that connect the upper arm to the tool body and the pad.3. The downhole tool of claim 2 , the one or more pins connect the lower arm to the tool body and the sliding block.4. The downhole tool of claim 1 , further comprising a spring in which the sliding block is connected to at one end and an actuator is connected at the opposite end of the spring.5. The downhole tool of claim 4 , wherein an actuator moves the spring and in turn the sliding block through the spring.6. The downhole tool of claim 1 , wherein the passive arm is connected at one end to the tool body by a pin and connected to the lower arm by a second pin.7. The downhole tool of claim 6 , wherein the second pin is placed within a slot that is formed in the lower arm.8. The downhole tool of claim 7 , wherein the second pin is moveable along a longitudinal length of the slot.9. The downhole ...

DOWNHOLE INTERVENTION AND COMPLETION DRONE AND METHODS OF USE

In one example, an apparatus includes a body, a propulsion system configured to move the body in a forward direction and in a reverse direction, and a reusable sealing and isolation element connected to the body and configured to be deployed so as to selectively seal and isolate sections or stages in a wellbore when the apparatus is disposed in the wellbore. The reusable sealing element may be selectively employed to isolate, and de-isolate, a portion of the wellbore, such as in connection with a perforation process for example. 1. An apparatus , comprising:a body;a propulsion system configured to move the body in a forward direction and in a reverse direction; anda reusable sealing and isolation element connected to the body and configured to be deployed so as to selectively seal and isolate sections or stages in a wellbore when the apparatus is disposed in the wellbore.2. The apparatus as recited in claim 1 , wherein the apparatus comprises an autonomous drone.3. The apparatus as recited in claim 1 , wherein the propulsion system comprises:a power source;one or more extendible/retractable propulsion systems, wherein one of the propulsion systems comprises a motor and one or more wheels disposed on an outer portion of the body; anda gear box that connects the motor to the wheels.4. The apparatus as recited in claim 3 , wherein the power source comprises one or more rechargeable batteries configured to be wirelessly charged downhole.5. The apparatus as recited in claim 3 , wherein the power source comprises rechargeable batteries.6. The apparatus as recited in claim 1 , wherein the apparatus is self-propelled.7. The apparatus as recited in claim 1 , wherein the body is articulated.8. The apparatus as recited in claim 1 , further comprising one or more hardware processors and non-transitory storage media carrying instructions that are executable by the one or more hardware processors to cause the seal to expand and retract according to a specified schedule.9. The ...

Apparatus and methods for determining operational mode of tong assembly

A system for tong assembly operation includes a mode switch for shifting the tong assembly between a first mode of operation and a second mode of operation, the mode switch having a first portion associated with the first mode and a second portion associated with the second mode; a first target coupled to the first portion, the first target movable to a first position corresponding to the first mode of operation; a second target coupled to the second portion, the second target movable to a second position corresponding to the second mode of operation; a first sensor configured to identify the first position of the first target; and a second sensor configured to identify the second position of the second target.

Micro Tunneling Machine

The present disclosure relates to a tunneling apparatus including a drill head including a main body and a steering member that is movable relative to the main body. The tunneling apparatus includes a steering target attached to the main body. The tunneling apparatus also includes a camera mounted within the main body. Further, the tunneling apparatus includes a shell position indicator mounted to the steering member in the field of view of the camera. The shell position indicator is adapted to indicate relative movement between the target and the shell position indicator. Additionally, the position indicator frames the target when no relative movement between the target and shell position indicator is indicated.

METHOD AND SYSTEM FOR PROCESSING WELL LOG DATA FROM MULTIPLE WELLS USING MACHINE LEARNING

A method may include obtaining well log data regarding a geological region of interest. The well log data may correspond to logging-while-drilling (LWD) measurements or measurement-while-drilling (MWD) measurements acquired from various wellbores. The method may further include generating image data regarding the geological region of interest using the well log data and a recurrent neural network. The method may further include determining a drilling parameter for a wellbore among the wellbores in real-time using the image data. The drilling parameter may be determined while the well log data is being acquired in the wellbore. The method may further include transmitting, based on the drilling parameter, a command to a drilling system coupled to the wellbore. 1. A method , comprising:obtaining, by a computer processor, well log data regarding a geological region of interest, wherein the well log data corresponds to logging-while-drilling (LWD) measurements or measurement-while-drilling (MWD) measurements acquired from a plurality of wellbores;generating, by the computer processor, image data regarding the geological region of interest using the well log data and a first recurrent neural network;determining, by the computer processor, one or more drilling parameters for a wellbore among the plurality of wellbores in real-time using the image data,wherein the one or more drilling parameters are determined while the well log data is being acquired in the wellbore; andtransmitting, by the computer processor and based on the one or more drilling parameters, a command to a drilling system coupled to the wellbore.2. The method of claim 1 ,wherein the first recurrent neural network comprises a plurality of long short-term memory (LSTM) cells,wherein a respective LSTM cell among the plurality of LSTM cells generates a respective output class signal, andwherein the respective LSTM cell obtains a previous output class signal and a cell state signal from a previous LSTM cell ...

BOREHOLE LOCALIZATION RELATIVE TO OBJECTS AND SUBTERRANEAN FORMATIONS

This disclosure presents methods and processes to estimate a position parameter, an orientation parameter, a dip parameter, and a diameter parameter of an object or subterranean formation change proximate an active borehole. The object or formation can be an adjacent borehole. The parameters can be utilized by a geo-steering system or a well site job plan system to reduce an uncertainty surrounding or looking ahead of the active borehole to avoid a collision with the object or formation, to intercept the object or formation, or to place the active borehole in a more advantageous position. The parameters can be derived from collected component resistivity data that has been reconstructed utilizing a three-dimensional inversion algorithm. In some aspects, low resistivity data can be extracted to improve the estimating of the parameters. In some aspects, the process can be implemented in a downhole tool, in a surface system, or a combination thereof. 1. A method , comprising:collecting component resistivity data utilizing a resistivity tool located downhole of an active borehole of a well site;reconstructing the component resistivity data to generate reconstructed resistivity data utilizing a three-dimensional (3D) inversion algorithm, wherein the reconstructed resistivity data represents information on part of an object or of a subterranean formation change in a proximate subterranean formation; andcomputing generated results utilizing the reconstructed resistivity data.2. The method as recited in claim 1 , wherein the object or the subterranean formation change is located at one or more of a radial position or a look ahead area respective to the active borehole and further comprising:communicating the generated results to one or more of a user, a well site controller, or a geo-steering system.3. The method as recited in claim 1 , further comprising:receiving input parameters, wherein the input parameters are utilized by the collecting and reconstructing, and the ...

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 and apparatus for video validation

A validation tool ( 100 ) has a central body member ( 10 ) with threaded connections at each end ( 12, 13 ), as well as a central bore ( 11 ) extending there through. At least one battery powered video camera ( 20 ) or other optical data sensor is disposed along an outer surface of the body member and can be selective activated and de-activated. Optional mirror(s) ( 50 ) are provided to permit optimum viewing of the surrounding environment, while visual images and/or other sensed data is recorded and stored on at least one data storage media. The validation tool can be used for various purposes including wellbore integrity and verification that drilling mud has been fully displaced with completion fluid in a wellbore.

Optical sensor and method of use

An interferometer apparatus for an optical fibre system and method of use is described. The interferometer comprises an optical coupler and optical fibres which define first and second optical paths. Light propagating in the first and second optical paths is reflected back to the optical coupler to generate an interference signal. First, second and third interference signal components are directed towards respective first, second and third photodetectors. The third photodetector is connected to the coupler via a non-reciprocal optical device and is configured to measure the intensity of the third interference signal component directed back towards the input fibre. Methods of use in applications to monitoring acoustic perturbations and a calibration method are described.

CORRECTING BOREHOLE IMAGES USING MACHINE-LEARNING MODELS

Borehole images can be corrected using machine-learning models. For example, a system can train a machine-learning model based on a training dataset. The training dataset can include a first set of borehole images correlated to a second set of borehole images, where the second set of borehole images are less precise versions of the first set of borehole images. The system can then execute the trained machine-learning model in relation to an input borehole image to receive a corrected borehole image as output from the trained machine-learning model. The corrected borehole image can be a visually corrected version of the input borehole image. The system may then perform one or more operations based on the corrected borehole image, such as generating a graphical user interface that includes the corrected borehole image for display on a display device. 1. A system comprising:a processor; and{'claim-text': ['train a machine-learning model based on a training dataset to generate a trained machine-learning model, the training dataset including a first set of borehole images correlated to a second set of borehole images, the second set of borehole images being less precise versions of the first set of borehole images;', 'execute the trained machine-learning model in relation to an input borehole image to receive a corrected borehole image as output from the trained machine-learning model, the corrected borehole image being a visually corrected version of the input borehole image; and', 'generate a graphical user interface that includes the corrected borehole image for display on a display device.'], '#text': 'a memory including instructions that are executable by the processor for causing the processor to:'}2. The system of claim 1 , wherein the input borehole image is a two-dimensional digital image that includes colored pixels representing a property of a subterranean formation into which a borehole is drilled for extracting hydrocarbons from the subterranean formation ...

DOWNHOLE INVESTIGATION TOOL

A downhole investigation tool for a borehole is disclosed. The downhole investigation tool includes a number of ultrasonic probes configured to generate an ultrasonic image of a forward portion of the borehole ahead of the downhole investigation tool and a rear/side portion of the borehole behind or beside the downhole investigation tool, at least one magneto-vision probe configured to generate a magneto-vision image of the forward portion and the rear/side portion of the borehole, and a mechanical attachment configured to attach the downhole investigation tool to a wireline or a steel pipe in the borehole. 1. A downhole investigation tool for a borehole , comprising:a plurality of ultrasonic probes configured to generate an ultrasonic image of a forward portion of the borehole ahead of the downhole investigation tool and a rear/side portion of the borehole behind or beside the downhole investigation tool;at least one magneto-vision probe disposed on a slanted cross-section at an angle to a longitudinal direction of the investigation tool and configured to generate a magneto-vision image of the forward portion and the rear/side portion of the borehole; anda mechanical attachment configured to attach the downhole investigation tool to a wireline or a steel pipe in the borehole,wherein at least two of the plurality of ultrasonic probes are disposed on opposite sides of the slanted cross-section, andwherein the ultrasonic image and the magneto-vision image are combined to detect an optically obscured metallic object in a non-transparent fluid of the borehole where no metallic object should be present.2. The downhole investigation tool of claim 1 ,wherein the ultrasonic image comprises mechanical shapes of one or more forward objects in the forward portion of the borehole and one or more rear/side objects in the rear/side portion of the borehole.3. The downhole investigation tool of claim 2 ,wherein the magneto-vision image comprises physical characteristics of a ...

WATERFLOOD FRONT IMAGING USING SEGMENTALLY INSULATED WELL LINERS AS ON-DEMAND ELECTRODES

A method for monitoring waterfront movement in a subsurface formation involves performing forward modeling of at least one deep electromagnetic survey of the waterfront movement, and determining locations for installing an electrically insulating spacer between well liners to form an on-demand electromagnetic source electrode. Based on the forward modeling, repeat survey time intervals are predicted. The method involves, during well completion, installing the electrically insulating spacer between the well liners in a reservoir to form at least one on-demand electromagnetic source electrode, and installing the electrically insulating spacer between the plurality of well liners in a reservoir to form an on-demand electromagnetic receiver electrode. A waterfront survey is performed by conveying a production logging tool into a well that temporarily converts the well liners into an on-demand electromagnetic source electrode and an on-demand receiver electrode, and inverse modeling of the waterfront survey is performed to produce a water saturation image. 1. A method for monitoring waterfront movement in a subsurface formation , the method comprising:performing forward modeling of at least one deep electromagnetic survey of the waterfront movement;determining, based on the forward modeling, locations for installing at least one electrically insulating spacer between a plurality of well liners to form at least one on-demand electromagnetic source electrode;determining, based on the forward modeling, locations for installing at least one electrically insulating spacer between a plurality of well liners to form at least one on-demand electromagnetic receiver electrode;predicting, based on the forward modeling, repeat survey time intervals;during well completion, installing the at least one electrically insulating spacer between the plurality of well liners in a reservoir to form at least one on-demand electromagnetic source electrode;during well completion, installing the ...

EXPERIMENTAL APPARATUS FOR SIMULATING LIFTING OPERATION OF DEEP-SEA MINING

Provided is an experimental apparatus for simulating lifting operation of deep-sea mining, which relates to the technical field of experimental equipment of deep-sea mining. By this apparatus, dynamic characteristics of a spatial structure when simulating lifting operation of deep-sea mining are solved. The apparatus includes an experimental box, a wave-making mechanism, a flowrate control mechanism, a mining simulation mechanism and a monitoring mechanism. The wave-making mechanism includes a control box and a wave-pushing board for simulating waves. The flowrate control mechanism includes a water pump, a motor, a grating board and a manifold so that the flowrate and the flow volume can be adjusted by the grating board and the manifold. The mining simulation mechanism includes an experimental ship model, a lifting pipe, a material-mixing pipe, a mineral slurry pipe, a material-delivering pipe and a material-returning pipe for simulating lifting operation states. The monitoring mechanism includes a wave height measurer, a displacement sensor, a flowrate measurer and an image collection apparatus for detecting dynamic influence of the wave height and the wave speed on the mining simulation mechanism during a mining process, especially during lifting operation. Further, the apparatus has advantages such as multi-parameter real-time monitoring, low fabrication cost and simple operation. 1. An experimental apparatus for simulating lifting operation of deep-sea mining , comprising an experimental box , a wave-making mechanism , a flowrate control mechanism , a mining simulation mechanism and a monitoring mechanism; wherein ,the wave-making mechanism comprises a control box and a wave-pushing board, the wave-pushing board is disposed at a side wall of an upper portion of the experimental box, the control box is connected with the wave-pushing board through a coupling; the flowrate control mechanism comprises a water pump, a motor, a grating board and a manifold, the ...

Image Correction Methods for Downhole Inspection Tools

Methods for correcting for non-centred tool geometry in image data obtained by a conduit inspection tool are disclosed. Embodiments of the invention apply to inspection tools with one or multiple sideview cameras and to inspection tools with downview cameras. The methods include obtaining at least two overlapping images of the internal surface of the conduit using the tool, identifying one or more features common to at least a pair of the overlapping images, determining, based on the positions of the or each common feature, the position of the tool with respect to a longitudinal axis of the conduit, determining a correction function based on the position of the tool and applying the correction function to the image data. Methods for determining the dimension of a feature of interest on the internal surface of the conduit are also disclosed. 1. A method for correcting for non-centred tool geometry in image data obtained by a conduit inspection tool having at least one camera for imaging the internal surface of a conduit , the method comprising:obtaining at least two overlapping images of the internal surface of the conduit using the tool;identifying one or more features common to at least a pair of the overlapping images;determining, based on the positions of the or each common feature, the position of the tool with respect to a longitudinal axis of the conduit;determining a correction function based on the position of the tool; andapplying the correction function to the image data.2. The method according to claim 1 , wherein the inspection tool comprises at least one sideview camera having a field of view with a centre line that extends substantially perpendicularly to a longitudinal axis of the tool.3. The method according to claim 2 , wherein the inspection tool comprises a plurality of sideview cameras arranged on a common plane perpendicular to the longitudinal axis of the tool.4. The method according to claim 1 , wherein the overlapping images overlap ...

System And Method To Conduct Real-Time Chemical Analysis Of Deposits

A system for conducting real-time chemical analysis of deposits is provided. The system includes an electromagnetic radiation source positioned on a downhole tool that emits electromagnetic radiation to a surrounding downhole environment within a field of view of interest. The system also includes a multivariate optical element positioned on the downhole tool that has optical filters configured to receive reflected radiation from the field of view of interest and generate respective filtered radiation signals. Each of the optical filters has a different transmission function that corresponds to a respective chemical species of interest. The system also includes an image sensor positioned on the downhole tool that detects each of the respective filtered radiation signals from the multivariate optical element. The image sensor provides image information of the field of view of interest that indicates a presence of at least one chemical species of interest located in the surrounding downhole environment.

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 ...

Hydrocarbon Wells and Methods for Monitoring Fracture Morphology of a Fracture that Exends from a Wellbore of the Hydrocarbon Wells

Hydrocarbon wells and methods for monitoring fracture morphology of a fracture that extends from a wellbore of the hydrocarbon wells are disclosed herein. The hydrocarbon wells include a wellbore, a fracture that extends from the wellbore, and an electromagnetic contrast material positioned within the fracture. The hydrocarbon wells also include a downhole electromagnetic transmitter, which is configured to direct an electromagnetic probe signal incident upon the electromagnetic contrast material, and a downhole electromagnetic receiver, which is configured to receive an electromagnetic resultant signal from the electromagnetic contrast material. The methods include flowing an electromagnetic contrast material into a fracture and generating an electromagnetic probe signal. The methods also include modifying the electromagnetic probe signal with the electromagnetic contrast material to generate an electromagnetic resultant signal. The methods further include receiving the electromagnetic resultant signal and determining the morphology of the fracture. 1. A method of monitoring a morphology of a fracture that extends from a wellbore of a hydrocarbon well and within a subsurface region , the method comprising:flowing an electromagnetic contrast material from the wellbore and into the fracture;generating an electromagnetic probe signal with a downhole electromagnetic transmitter such that the electromagnetic probe signal is incident upon the electromagnetic contrast material;modifying the electromagnetic probe signal, with the electromagnetic contrast material, to generate an electromagnetic resultant signal;receiving the electromagnetic resultant signal with a downhole electromagnetic receiver; anddetermining the morphology of the fracture based, at least in part, on the electromagnetic resultant signal.2. The method of claim 1 , wherein the wellbore is a first wellbore claim 1 , wherein the downhole electromagnetic transmitter is positioned within a transmitting ...

METHODS FOR POSITIONING A WELL FOR OPTIMAL FLUID PRODUCTION

Provided are methods of locating a well bore to optimize fluid extraction from a region of interest. In this manner, well production may be better predicted without having to go through the time and effort of drilling exploratory-type wells. The methods analyze semblance values of voxels within a full activity volume, and identify near well activity (NWA) voxels based on voxels that exceed the mean semblance value by a cut-off value. For example, the cut-off value may correspond to one or two standard deviations greater than the mean semblance value. Optimal fluid recovery corresponds to a well bore location at or near the putative location corresponding to the maximum number of NWA voxels in the region of interest.

STIMULATED ROCK VOLUME ANALYSIS

A data acquisition program, which includes core, image log, microseismic, DAS, DTS, and pressure data, is described. This program can be used in conjunction with a variety of techniques to accurately monitor and conduct well stimulation.

Smart Frac Plug System and Method

A frac plug system for use at the end of well drill string in a fractured underground formation, includes an elongated mandrel body, wherein the front portion of said elongated mandrel body includes a nose cone, the rear of said elongated mandrel body includes a mandrel head and the mid-portion of said elongated mandrel body includes a sealing assembly; a set of sensors positioned on said nose cone, said set of sensors being selected from a group including: temperature sensors, pressure sensors, pH sensors and fluid composition sensors; a battery operated microcontroller located within said mandrel body, said battery operated microcontroller constructed and arranged to periodically read the data output of said set of sensors and store said data from said set of sensors; a transmitter electrically connected to said battery operated microcontroller, said transmitter constructed and arranged to transmit said stored data from said set of sensors to a receiver when said receiver is in receiving range of said transmitter, said receiver constructed and arranged to write said transmitted stored data to an electronic memory; and whereby when said data from said set of sensors may be retrieved from said electronic memory.

STABLE MAGNETIC DRILLING MUD AND METHOD

A magnetic drilling mud for use in a well, the magnetic drilling mud including water; bentonite; magnetic micro-particles; and an anionic surfactant that prevents separation of the bentonite and the magnetic micro-particles in the water. The magnetic micro-particles have a diameter less than 100 μm. 1. A magnetic drilling mud for use in a well , the magnetic drilling mud comprising:water;bentonite;magnetic micro-particles; andan anionic surfactant that prevents separation of the bentonite and the magnetic micro-particles in the water,wherein the magnetic micro-particles have a diameter less than 100 μm.2. The magnetic drilling mud of claim 1 , wherein the anionic surfactant has a molecular concentration smaller than or equal to a critical micelle concentration of the anionic surfactant.3. The magnetic drilling mud of claim 1 , wherein the anionic surfactant is sodium dodecyl sulfate (SDS).4. The magnetic drilling mud of claim 3 , wherein the SDS has a molar concentration between 4 and 8 mM.5. The magnetic drilling mud of claim 4 , wherein the magnetic micro-particles are FeO.6. The magnetic drilling mud of claim 5 , wherein the FeOmicro-particles have a diameter of 50 μm.7. The magnetic drilling mud of claim 6 , wherein a concentration of the FeOmicro-particles is less than 10% of a total volume of the magnetic drilling mud.8. A method for making a magnetic drilling mud for use in a well claim 6 , the method comprising:adding bentonite to water to obtain a mixture;aging the mixture by exposing the mixture to a temperature larger than a room temperature;adding magnetic micro-particles to the mixture; andadding an anionic surfactant that prevents separation of the bentonite and the magnetic micro-particles in the water,wherein the magnetic micro-particles have a diameter less than 100 μm, andwherein the anionic surfactant has a molecular concentration smaller than or equal to a critical micelle concentration of the anionic surfactant.9. The method of claim 8 , wherein ...

ORIENTATION VERIFICATON DEVICES

An orientation verification tool permits an operator to confirm an orientation of one or more perforating charges in a perforating gun assembly when the perforating charges are not readily visible for inspection. The orientation verification tool includes an end fixture rotationally coupled at a longitudinal end of a charge carrier disposed within a tubular gun body. The end fixture includes a visual indicator of the orientation of the perforating charges on a longitudinal end face thereof. The visual indicator may include a plurality of hatch marks arranged at regular intervals around the end fixture, and each hatch mark may be identified by a specific angular identifier so that the hatch mark located at a reading location will identify the angular orientation of the perforating charges. 1. A perforating gun apparatus , comprising:a charge carrier defining a rotational axis;at least one perforating charge coupled to the charge carrier, the at least one perforating charge defining a lateral discharge direction;an end fixture coupled to a longitudinal end of the charge carrier and rotationally coupled to the charge carrier about the rotational axis, the end fixture defining a longitudinal end face with a visual reference indicator marked thereon in alignment with the lateral discharge direction of the at least one perforating charge.2. The apparatus of claim 1 , wherein the longitudinal end face of the end fixture further comprises a plurality of visual indicators radially spaced around a perimeter thereof.3. The apparatus of claim 2 , wherein the plurality of visual indicators includes at least one numerical indicator corresponding to an angular position of the at least one numerical indicator from the reference indicator.4. The apparatus of claim 1 , further comprising a plurality of fasteners coupled to one of the end fixture and the charge carrier in an asymmetrical array claim 1 , and wherein the other one of the end fixture and the charge carrier includes a ...

Topside Interrogation Using Multiple Lasers For Distributed Acoustic Sensing Of Subsea Wells

A distributed acoustic system (DAS) may include an interrogator that includes two or more lasers, a pulser module disposed after and connected to each of the two or more lasers, a wavelength division multiplexer (WDM), wherein each of the pulser modules are connected to the WDM as inputs, and a downhole fiber attached to the WDM as an output and wherein the downhole fiber includes at least one sensing fiber. A method for increasing a sampling frequency may include identifying a length of a downhole fiber connected to an interrogator, generating and launching a light pulse from each of the two or more lasers the pulser module, and delaying an output from the pulser module into the downhole fiber by k/N seconds, where k is a pulse repetition interval of the pulser module and N is equal to the two or more lasers.

Image Data Processing

A method for processing image data of a sample is disclosed. The method comprises registering a first and a second images of at least partially overlapping spatial regions of the sample and processing data from the registered images to obtain integrated image data comprising information about the sample, said information being additional to that available from said first and second images.

ULTRASONIC TRANSDUCER WITH REDUCED BACKING REFLECTION

A well tool can be used in a wellbore that can measure characteristics of an object in the wellbore. The well tool includes an ultrasonic transducer for generating an ultrasonic wave in a medium of the wellbore. The ultrasonic transducer includes a front layer, a rear layer, backing material coupled to the rear layer, and piezoelectric material coupled to the front layer and to the backing material. The rear layer can improve signal-to-noise ratio of the transducer in applications such as imaging and caliper applications. 1. A well tool usable in a wellbore , the well tool comprising: a front layer;', 'a rear layer;', 'backing material coupled to the rear layer; and', 'piezoelectric material coupled to the front layer and to the backing material., 'an ultrasonic transducer for generating an ultrasonic wave in a medium of the wellbore, the ultrasonic transducer comprising2. The well tool of claim 1 , wherein the rear layer is a rear quarter-wavelength plate.3. The well tool of claim 2 , wherein the front layer is a front quarter-wavelength plate.4. The well tool of claim 1 , wherein the ultrasonic transducer is an ultrasound ultrasonic transducer for outputting the ultrasonic wave at a frequency of 20 kHz or higher.5. The well tool of claim 1 , wherein the well tool comprises a logging-while-drilling tool or a wireline tool.6. The well tool of claim 1 , further comprising:an ultrasonic sensor for detecting a reflection or a refraction of the ultrasonic wave off an object in the wellbore and transmitting an associated signal;a processing device in communication with the ultrasonic transducer and the ultrasonic sensor; and receive the associated signal from the ultrasonic sensor; and', 'determine a characteristic of the object based on the associated signal., 'a memory device in which instructions are stored that are executable by the processing device for causing the processing device to7. The well tool of claim 6 , wherein the characteristic is an image of the object ...

Downhole Nuclear Magnetic Resonance (NMR) Tool for One-Dimensional NMR Imaging

A nuclear magnetic resonance (NMR) tool includes an antenna assembly and a magnet assembly. The NMR tool also includes a motional sensor comprising at least one radio frequency (RF) antenna disposed about a tool axis and about at least a portion of the magnet assembly, in which the motional sensor is operable to generate readings for lateral motion of the antenna assembly and the magnet assembly. The at least one RF antenna has a soft magnetic core and a coil winding disposed around the soft magnetic core. The motional sensor can determine a one-dimensional NMR image indicating a lateral displacement of the NMR tool based on one or more spatial positions of NMR excitation volumes in the region of interest that correspond to respective excitation frequencies in the at least one RF antenna. 1. A nuclear magnetic resonance (NMR) tool , comprising:an antenna assembly comprising an antenna winding at least partially disposed around a soft magnetic core comprising an upper axial end opposite a lower axial end;a magnet assembly comprising an upper end magnet spaced apart from the upper axial end of the soft magnetic core and a lower end magnet spaced apart from the lower axial end of the soft magnetic core; anda motional sensor comprising at least one radio frequency (RF) antenna disposed about a tool axis and about at least a portion of the upper end magnet, the motional sensor being operable to generate readings for lateral motion of the antenna assembly and the magnet assembly,wherein the motional sensor determines a one-dimensional NMR image indicating a lateral displacement of the NMR tool based on one or more spatial positions of NMR excitation volumes in a region of interest that correspond to respective excitation frequencies in the at least one RF antenna.2. The NMR tool of claim 1 , wherein:the at least one RF antenna comprises a soft magnetic core and a coil winding disposed around the soft magnetic core,the upper end magnet is operable to produce a static ...

Software Tuning of Borehole Imagers

A method and a system for tuning a pad. The method may comprise disposing a downhole tool into a borehole, configuring the pad in a first configuration, taking a first measurement of the formation in the first configuration, configuring the pad in a second configuration, taking a second measurement of the formation in the second configuration, determining a tuning coefficient to reduce a tool body effect in the first measurement and the second measurement, computing a first weighted measurement from the tuning coefficient and the first measurement, computing a second weighted measurement from the tuning coefficient and the second measurement, and computing a tuned impedance from a ratio of the first weighted measurement and the second weighted measurement. A system for determining a formation boundary may comprise a downhole tool, an arm, and a pad. The system may further comprise a conveyance and an information handling system. 1. A method for tuning a pad comprising;disposing a downhole tool into a borehole that penetrates a formation, wherein the downhole tool comprises the pad and wherein the pad is connected to the downhole tool through an arm;configuring the pad in a first configuration;taking a first measurement of the formation in the first configuration;configuring the pad in a second configuration;taking a second measurement of the formation in the second configuration;determining a tuning coefficient to reduce a tool body effect in the first measurement and the second measurement;computing a first weighted measurement from the tuning coefficient and the first measurement;computing a second weighted measurement from the tuning coefficient and the second measurement; andcomputing a tuned impedance from a ratio of the first weighted measurement and the second weighted measurement.2. The method of claim 1 , further comprising determining a plurality of tuning coefficients claim 1 , producing a graph of at least one of the plurality of tuning coefficients in ...

METHODS AND MEANS FOR MEASUREMENT OF THE WATER-OIL INTERFACE WITHIN A RESERVOIR USING AN X-RAY SOURCE

An x-ray-based reservoir evaluation tool for measurement variations in formation density anticipated at the water-oil interface of a reservoir is provided, the tool including at least: an internal length comprising a sonde section, wherein said sonde section further comprises an x-ray source; radiation measuring detectors; sonde-dependent electronics; and a plurality of tool logic electronics and PSUs. A method of using an x-ray based reservoir evaluation tool for measuring variations in formation density anticipated at the water-oil interface of a reservoir is also provided, the method including at least the following steps: using x-rays to illuminate the formation surrounding the cased borehole; uses detectors to directly measure the density of the formation; using detectors to directly measure the effects on the measurement from tool stand-off or production liner attenuation; and employing techniques for compensating for the production liner and liner-annular region when computing the saturated formation density within the production interval. 1. An x-ray based reservoir evaluation tool for measurement variations in formation density anticipated at the water-oil interface of a reservoir , wherein said tool comprises:an internal length comprising a sonde section, wherein said sonde section further comprises an x-ray source;a plurality of radiation measuring detectors;sonde-dependent electronics;and a plurality of tool logic electronics and PSUs.2. The tool of claim 1 , further comprising a detector used to measure casing standoff such that other detector responses are compensated for tool stand-off.3. The tool of claim 1 , wherein said shield further comprises tungsten.4. The tool of claim 1 , wherein the tool is configured so as to permit through-wiring.5. The tool of claim 1 , wherein a reference detector is used to monitor an azimuthal output of the x-ray source.6. The tool in claim 1 , wherein the tool is combinable with other measurement tools comprising one ...

Inspection system and method for use in underground boring operations

An inspection system and method for use in underground utility construction, especially underground boring operations, is provided. The inspection system generally includes a sensor, a sensor carrier apparatus, and an output device. The sensor is employed to obtain inspection data regarding the condition of a tunnel created in an underground boring operation. The sensor carrier is adapted to incorporate the sensor and connect to means for transporting the sensor through the tunnel. The output device receives an output signal from the sensor corresponding to the inspection data and presents it to an operator for interpretation and/or otherwise documents and/or records the inspection data.

DEEP LEARNING METHODS FOR WELLBORE PIPE INSPECTION

Methods and systems for inspecting the integrity of multiple nested tubulars are included herein. A method for inspecting the integrity of multiple nested tubulars can comprise conveying an electromagnetic pipe inspection tool inside the innermost tubular of the multiple nested tubulars; taking measurements of the multiple nested tubulars with the electromagnetic pipe inspection tool; arranging the measurements into a response image representative of the tool response to the tubular integrity properties of the multiple nested tubulars; and feeding the response image to a pre-trained deep neural network (DNN) to produce a processed image, wherein the DNN comprises at least one convolutional layer, and wherein the processed image comprises a representation of the tubular integrity property of each individual tubular of the multiple nested tubulars. 1. A method for inspecting tubular integrity comprising:conveying an electromagnetic pipe inspection tool inside an innermost tubular of multiple nested tubulars, wherein the electromagnetic pipe inspection tool has one or more transmitters and one or more receivers;taking measurements of the multiple nested tubulars with the electromagnetic pipe inspection tool;arranging the measurements into a response image representative of a tool response to tubular integrity properties of the multiple nested tubulars; andfeeding the response image to a pre-trained deep neural network (DNN) to produce a processed image,wherein the DNN comprises at least one convolutional layer, andwherein the processed image comprises a representation of the tubular integrity property of each individual tubular of the multiple nested tubulars.2. The method of claim 1 , wherein taking measurements of the multiple nested tubulars with the electromagnetic pipe inspection tool comprisestransmitting electromagnetic fields at one or more frequencies with the one or more transmitters; andmeasuring at least one of a real-part, an imaginary-part, an absolute, ...

DEEP LEARNING METHODS FOR WELLBORE PIPE INSPECTION

Methods and systems for inspecting the integrity of multiple nested tubulars are provided. A method for inspecting the integrity of multiple nested tubulars can comprise conveying an electromagnetic pipe inspection tool inside the innermost tubular of the multiple nested tubulars; taking measurements of the multiple nested tubulars with the electromagnetic pipe inspection tool; inverting the measurements for a tubular integrity property of each individual tubular of the multiple nested tubulars to provide inverted tubular integrity properties; arranging the inverted integrity properties into an inverted image representative of an estimated tubular integrity property of each individual tubular; and feeding the inverted image to a pre-trained deep neural network (DNN) to produce a corrected image, wherein the DNN comprises at least one convolutional layer, and wherein the corrected image comprises a representation of the tubular integrity property of each individual tubular of the multiple nested tubulars. 1. A method for inspecting tubular integrity comprising:conveying an electromagnetic pipe inspection tool inside an innermost tubular of multiple nested tubulars, wherein the electromagnetic pipe inspection tool has one or more transmitters and one or more receivers;taking measurements of the multiple nested tubulars with the electromagnetic pipe inspection tool;inverting the measurements for a tubular integrity property of each individual tubular of the multiple nested tubulars to provide inverted tubular integrity properties;arranging the inverted tubular integrity properties into an inverted image representative of an estimated tubular integrity property of each individual tubular; andfeeding the inverted image to a pre-trained deep neural network (DNN) to produce a corrected image,wherein the DNN comprises at least one convolutional layer, andwherein the corrected image comprises a representation of a corrected tubular integrity property of each individual ...

DEEP LEARNING METHODS FOR WELLBORE LEAK DETECTION

Methods and systems for leak detection are provided herein. A method for leak detection can comprise conveying an acoustic leak detection tool inside the innermost tubular of the multiple nested tubulars; taking measurements of the multiple nested tubulars at multiple measurement depths with the acoustic leak detection tool; arranging the measurements into a response image; and feeding the response image to a pre-trained deep neural network (DNN) to produce a flow likelihood image, wherein the DNN comprises at least one convolutional layer, and wherein the flow likelihood image comprises a representation of one or more flow patterns in at least one annulus formed by the multiple nested tubulars. 1. A method for leak detection comprising:conveying an acoustic leak detection tool inside an innermost tubular of multiple nested tubulars, wherein the acoustic leak detection tool has one or more acoustic sensors;taking measurements of the multiple nested tubulars at multiple measurement depths with the acoustic leak detection tool;arranging the measurements into a response image; andfeeding the response image to a pre-trained deep neural network (DNN) to produce a flow likelihood image,wherein the DNN comprises at least one convolutional layer, andwherein the flow likelihood image comprises a representation of one or more flow patterns in at least one annulus formed by the multiple nested tubulars.2. The method of claim 1 , wherein the one or more acoustic sensors are hydrophones.3. The method of claim 1 , wherein the one or more acoustic sensors comprises one or more arrays of acoustic sensors.4. The method of claim 3 , wherein taking measurements of the multiple nested tubulars at the multiple measurement depths with the acoustic leak detection tool comprises measuring an acoustic signal with each of the sensors of the one or more arrays claim 3 ,the method further comprising combining the measured acoustic signals from each of the sensor of the one or more arrays into ...

Wireline Signal Noise Reduction

A wireline system and method for removing wireline noise from an electromagnetic wireline tool comprising. The system may comprise a wireline measurement tool, which may comprise a wireline measurement tool body, a wireline cable traversing the tool body, and a wireline signal sensor measuring a signal induced by the wireline cable. The system may further comprise an electromagnetic wireline tool, comprising a wireline tool body, the wireline cable traversing the tool body, and a receiver measuring a signal. A method may comprise running the electromagnetic wireline tool into a wellbore on a wireline, recording wireline signals with a wireline signal sensor on a wireline measurement tool, recording signals with a receiver disposed on the electromagnetic wireline tool, and adjusting recorded signals on the receiver by subtracting filtered recorded signals from the wireline signal sensor.

DETECTION AND EVALUATION OF ULTRASONIC SUBSURFACE BACKSCATTER

A system for estimating a property of a region of interest includes an acoustic measurement device including a transmitter configured to emit an acoustic signal having at least one selected frequency configured to penetrate a surface of a borehole in an earth formation and produce internal diffuse backscatter from earth formation material behind the surface and within the region of interest, and a receiver configured to detect return signals from the region of interest and generate return signal data. The system also includes a processing device configured to receive the return signal data, process the return signal data to identify internal diffuse backscatter data indicative of the internal diffuse backscatter, calculate one or more characteristics of the internal diffuse backscatter, and estimate a property of the region of interest based on the one or more characteristics of the internal diffuse backscatter. 1. A system for estimating a property of a region of interest , comprising:an acoustic measurement device configured to be disposed in a region of interest in an earth formation, the acoustic measurement device including a transmitter configured to emit an acoustic signal having at least one selected frequency configured to penetrate a surface of a borehole and produce internal diffuse backscatter from earth formation material behind the surface and within the region of interest, and a receiver configured to detect return signals from the region of interest and generate return signal data; anda processing device configured to receive the return signal data, the processing device configured to: process the return signal data to identify internal diffuse backscatter data indicative of the internal diffuse backscatter; calculate one or more characteristics of the internal diffuse backscatter; and estimate a property of the region of interest based on the one or more characteristics of the internal diffuse backscatter.2. The system of claim 1 , wherein the ...

USING AN ACOUSTIC DEVICE TO IDENTIFY EXTERNAL APPARATUS MOUNTED TO A TUBULAR

A method, apparatus and system for locating external apparatus mounted to a tubular in a wellbore. The identification of apparatus, such as cable clamps, enables other tools in the string to operate more precisely. A computer model is used to locate the apparatus from acoustic images, which images are acquired using a downhole device having an acoustic sensor or acoustic array. The model may be a classifier, which may be machine trained to classify whether an apparatus is present, its location and its orientation. Automating this locating enables very long wellbores to be processed quickly. 1. A method of locating apparatus mounted external to a tubular , the method comprising:deploying an imaging device having an acoustic sensor into the tubular;creating acoustic images using the acoustic sensor from acoustic reflections from the tubular and portions of the apparatus contacting the tubular; andprocessing the acoustic images with a computer model to determine a location of the apparatus.2. The method of claim 1 , wherein the acoustic images extend longitudinally along the tubular and circumferentially around the tubular claim 1 , the image preferable further comprising depth data representing time of reflections into the tubular for each scan line.3. The method of claim 1 , further comprising converting acoustic reflections to one or more intensity features of the image claim 1 , which intensity features preferably represent at least one of: maximum intensity claim 1 , average intensity claim 1 , standard deviation of intensity claim 1 , average intensities for plural radial ranges claim 1 , or radius of center of intensity.4. The method of claim 1 , wherein the acoustic images to be processed are axially-segmented frames from the imaged tubular.5. The method of claim 1 , wherein processing the acoustic images comprises image processing to identify edges of the apparatus.6. The method of claim 1 , further comprising determining an azimuthal location of the apparatus ...

Apparatus and method for obtaining petrophysical images using electrical imager and multi-frequency dispersion measurements

Methods and systems for determining petrophysical parameters of a formation are provided. In one embodiment, a method includes acquiring formation data with a borehole imaging tool deployed in a well penetrating a formation and acquiring additional formation data with a dielectric logging tool deployed in the well. The method also includes calibrating the formation data acquired with the borehole imaging tool based on the additional formation data acquired with the dielectric logging tool. The calibrated formation data can then be used in determining a petrophysical parameter of the formation. Additional methods, systems, and devices are also disclosed.

Sensor cover

A sensor cover ( 1 ) for an inspection assembly ( 3 ) is provided. The inspection assembly ( 3 ) is adapted to inspect the interior of a hollow member ( 5 ). The sensor cover ( 1 ) comprises a delimiting means ( 13.1, 13.2 ) configured to at least partially delimit a sensor cover volume ( 11.1, 11.2 ). The delimiting means ( 13.1, 13.2 ) comprises a flexible material and is configured to permit a modification of the sensor cover volume ( 11.1, 11.2 ) such that at least a portion of said delimiting means ( 13.1, 13.2 ) is closer to a portion of said hollow member wall ( 7 ) after said modification than before said modification to thereby enable said sensor signal to be transmitted from the hollow member wall ( 7 ) to the sensor ( 9 ). The present disclosure also relates to inspection assembly ( 3 ), a use of an inspection assembly ( 3 ), and a method ( 100 ) for inspecting the interior of a hollow member ( 5 ).

FISHING SCANNING TOOL

A borehole fishing tool, including a grapple for fixedly attaching to a fish in a borehole, a tool housing to which the grapple is connected, and at least one camera, mounted in the tool housing, to generate at least one image of the fish in the borehole. The borehole fishing tool also includes at least one light source, mounted in the tool housing, to illuminating a portion of the borehole between the at least one camera and the fish, a connector attached to the tool housing to connect the tool housing to a conveyor, and a telemetry transceiver to transmit at least one image of the fish through a telemetry channel in the conveyor to a computer system at an Earth's surface. 1. A borehole fishing tool , comprising:a grapple for fixedly attaching to a fish in a borehole;a tool housing to which the grapple is connected;at least one camera, mounted in the tool housing, to generate at least one image of the fish in the borehole;at least one light source, mounted in the tool housing, to illuminating a portion of the borehole between the at least one camera and the fish;a connector attached to the tool housing to connect the tool housing to a conveyor;a conduit disposed within the tool housing and the grapple and running from the connector to a tip of the grapple at a distal end of the grapple to deliver a transparent fluid from the conveyor to a portion of the borehole between the one or more cameras and the fish; anda telemetry transceiver configured to transmit at least one image of the fish through a telemetry channel in the conveyor to a computer system at an Earth's surface.2. The borehole fishing tool of claim 1 , wherein the grapple is a spear grapple.3. (canceled)4. The borehole fishing tool of claim 1 , wherein the fish is a magnetic fish and the grapple contains a magnetic component to attract the grapple to the magnetic fish.5. The borehole fishing tool of claim 4 , wherein the magnetic component is a controllable electromagnetic component.6. The borehole ...

CHANNEL DETECTION SYSTEM AND METHOD

Systems, methods, and computer-readable media are provided for detecting a channel behind casing and generating an image that represents the channel. 1. A method comprising:receiving, by at least one processor, data samples associated with at least one casing, each data sample representing channel information behind a representative casing;training, by the at least one processor, a machine learning model using the data samples to generate a mapping between integral amplitudes calculated from waveform information in each of the data samples and the channel information behind the representative casing, wherein at least one integral amplitude is calculated by rectifying the waveform information, determining a peaks-based envelope of the rectified waveform information, using the peaks-based envelope to modulate a sinusoid signal, and integrating a period of the modulated sinusoid signal to obtain the integral amplitude;receiving, by the at least one processor, acoustic data from a tool, the acoustic data representing a particular casing;calculating a plurality of integral amplitudes based on the acoustic data from the tool; andusing, by the at least one processor, the machine learning model to analyze the calculated plurality of integral amplitudes from the acoustic data and determine one of a presence and an absence of a channel behind the particular casing at a plurality of depths.2. The method of claim 1 , further comprising generating an azimuthal cement bond depth channel image that represents the presence and the absence of the channel behind the particular casing at the plurality of depths.3. The method of claim 2 , wherein the channel image is a binary two-dimensional image.4. The method of claim 3 , wherein the binary two-dimensional image represents a size and an azimuthal location of the channel behind the particular casing at the plurality of depths.5. The method of claim 1 , wherein the tool comprises at least one array of receivers azimuthally arranged ...

SYSTEMS AND METHODS FOR PROCESSING DRILL CUTTINGS

An example system may be used to automate one or more processes relating to drill cutting handling, cleaning, and packing to produce consistently high-quality cleaned samples. In some implementations, an example system may employ cleaning processes including centrifugal and ultrasonic processes to clean a sample automatically without the aid of a human operator thereby increasing efficiency and quality of the produced samples for better subsequent sample analysis. A system may include an unloading module, a cleaning module, and packing module, all of which may be operated in combination with a robotic arm. 1. A system for processing a sample comprising drill cuttings from a wellbore in a rock formation , the system comprising:an unloading module for transferring the sample from a collection container to a sample tube, the unloading module comprising a funnel and an unloading module camera for reading a label on the collection container;a cleaning module for cleaning a sample, the cleaning module comprising a tank comprising a centrifuge for centrifuging at least one sample tube;a packing module for packaging a sample, the packing module comprising a tray for receiving the sample form the at least one sample tube, a packing module camera for imaging the sample, and a packing and labeling device for packaging the sample; anda robotic arm for transferring the sample tube between the unloading module, the cleaning module, and the packing module, the robotic arm comprising a robotic arm camera.2. The system of claim 1 , where the unloading module comprises a water jet nozzle for discharging a water jet to drive the sample from the collection container to the funnel.3. The system of claim 1 , where the sample tube comprises an opening and a removable perforated top cap at a proximal end and an opening and a removable perforated bottom cap at a distal end claim 1 , and where the unloading module is arranged such that the sample tube receives the sample from the funnel ...

DOWNHOLE WELL INTEGRITY RECONSTRUCTION IN THE HYDROCARBON INDUSTRY

The present disclosure describes methods and systems for downhole well integrity reconstruction in a hydrocarbon reservoir. One method for downhole well integrity reconstruction in a hydrocarbon reservoir includes: positioning, a laser head at a first subterranean location, wherein the laser head is attached to a tubular inside of a wellbore; directing, by the laser head, a laser beam towards a leak on the wellbore; and sealing the leak using the laser beam. 1. An in-situ well integrity reconstruction device , comprising:a 3-dimensional (3D) laser head;at least one hardware processor; and 'positioning, the 3D laser head at a first subterranean location, wherein the 3D laser head is attached to a tubular inside of a wellbore; and', 'a non-transitory computer-readable storage medium coupled to the at least one hardware processor and storing programming instructions for execution by the at least one hardware processor, wherein the programming instructions, when executed, cause the in-situ well integrity reconstruction device to perform operations comprising direct a laser beam towards a leak at the first subterranean location; and', 'seal the leak using the laser beam., 'wherein the 3D laser head is configured to2. The in-situ well integrity reconstruction device of claim 1 , wherein the 3D laser head comprises a reflector and a focused lens claim 1 , and the reflector and the focused lens are configured to be rotated to aim at the leak.3. The in-situ well integrity reconstruction device of claim 2 , wherein the 3D laser head comprises a protector that blocks debris for the focused lens.4. The in-situ well integrity reconstruction device of claim 1 , wherein the 3D laser head comprises an insulated cable that protects optical fibers claim 1 , and wherein the optical fibers conduct the laser beam.5. The in-situ well integrity reconstruction device of claim 1 , further comprising: a 3D scanner configured to generate images inside the wellbore.6. The in-situ well ...

Rig power system efficiency optimization through image processing

A method includes receiving, by a computer system, a video of a visible state of a component of a generator, the generator powering at least a portion of a rig equipment system at a wellsite. The computer system can determine an operational parameter based on the visible state of the component of the generator imaged in the video, and can transmit the operational parameter to an output device.

SYSTEMS AND METHODS FOR INITIATING ADJUSTMENT OF AN OPERATION ASSOCIATED WITH AN UNDERWATER DRILLING SYSTEM

This disclosure is directed to initiating adjustment of an operation associated with an underwater drilling system, which may include receiving at least one underwater image; identifying the reference object in the at least one underwater image, wherein a position of the reference object is fixed relative to an underwater borehole or an underwater cloud; determining a first parameter associated with the reference object; identifying the underwater cloud in the at least one underwater image; determining a second parameter associated with the underwater cloud; adjusting the second parameter associated with the underwater cloud based on the first parameter associated with the reference object; and initiating an adjustment of the operation associated with the underwater drilling system based on the adjusted second parameter associated with the underwater cloud. 1. A method of initiating adjustment of an operation associated with an underwater drilling system , the method comprising:receiving, using one or more computing device processors, at least one underwater image;identifying, using the one or more computing device processors, the reference object in the at least one underwater image, wherein a position of the reference object is fixed relative to an underwater borehole or an underwater cloud, wherein execution of a drilling operation associated with the underwater borehole causes formation of the underwater cloud;determining, using the one or more computing device processors, a first parameter associated with the reference object;identifying, using the one or more computing device processors, the underwater cloud in the at least one underwater image;determining, using the one or more computing device processors, a second parameter associated with the underwater cloud;adjusting, using the one or more computing device processors, the second parameter associated with the underwater cloud based on the first parameter associated with the reference object; andinitiating, ...

METHOD AND SYSTEM FOR A FAST AND ACCURATE ESTIMATION OF PETROPHYSICAL PROPERTIES OF ROCK SAMPLES

There is provided a system and process to predict the petrophysical properties of unclean rock samples using Medical-CT scanned three-dimensional (3D) images at both low and high resolutions. The captured 3D images are passed through machine learning, statistical methods and data lookups to identify the petrophysical properties of rock samples. Also disclosed is the process of measuring phase saturations of a clean rock sample or porous medium using Micro-CT scanned three-dimensional (3D) images. 123-. (canceled)24. A method of detecting a plurality of petrophysical properties of an uncleaned rock sample , the method comprising the steps of:capturing an image of the uncleaned rock sample;passing the captured image through a feature extraction engine;providing an output from the feature extraction engine to a neural network for estimating the petrophysical properties of the uncleaned rock sample; anddisplaying the estimated petrophysical properties of the uncleaned rock sample on a display medium.25. The method of claim 24 , wherein the image of the uncleaned rock sample is a three-dimensional (3D) image.26. The method in accordance with claim 24 , wherein the image of the uncleaned rock sample is a computed tomography (CT) image claim 24 , a micro-CT image or a medical-CT image.27. The method in accordance with claim 24 , wherein the image of the uncleaned rock sample is acquired at either a low resolution or a high resolution.28. The method in accordance with claim 24 , wherein the micro-CT image is captured from a core-flooding equipment through a fluid displacement test.29. The method in accordance with claim 24 , wherein the petrophysical properties comprise porosity claim 24 , permeability claim 24 , elastic property claim 24 , relative permeability or capillary pressure.30. The method in accordance with claim 24 , wherein the feature extraction engine is a porosity-permeability predictor engine.31. The method in accordance with claim 24 , wherein the feature ...

Downhole Ultrasound Image Correction in Oil Based Mud

A method for generating acoustic images corrected for distortions caused by attenuation of the ultrasonic signal by the mud may comprise disposing a downhole tool into a borehole, transmitting a pressure pulse from at least one transducer into the borehole, recording an echo with the at least one transducer, measuring a travel time, measuring an amplitude, determining a geometry of the borehole, determining a location of the downhole tool in the borehole, calculating an incident angle, mapping a mud attenuation, and correcting an image. A system for generating acoustic images corrected for distortions caused by attenuation of the ultrasonic signal by the mud comprising a downhole tool that may comprise a measuring assembly, wherein the measuring assembly comprises at least one transducer and wherein the at least one transducer is configured to emit a pressure pulse and record an echo. The system may further comprise an information handling system. 1. A method for eccentricity correction comprising:disposing a downhole tool into a borehole, wherein the downhole tool comprises a measuring assembly having at least one transducer;determining a beam pattern from the at least one transducer;determining a center of the measurement assembly in the borehole with the beam pattern;calculating a beam pattern factor;calculating an angle factor;calculating an eccentricity factor; andcreating an eccentricity corrected image.2. The method of claim 1 , further comprising multiplying the beam pattern factor and the angle factor to calculate the eccentricity factor.3. The method of claim 2 , further comprising determining an echo amplitude from the beam pattern.4. The method of claim 3 , further comprising producing a raw image from the beam pattern and the echo amplitude.5. The method of claim 4 , further comprising dividing an amplitude of the raw image at one or more azimuthal and depth locations with an inverse of the eccentricity factor.6. The method of claim 5 , further ...

DRILL BIT WEAR AND BEHAVIOR ANALYSIS AND CORRELATION

A method comprises determining a measure of drilling efficiency, such as a friction factor or mechanical specific energy, of a drill bit used in a drilling operation of a wellbore and performing video analytics of at least one video that includes a substantially complete view of the wear surfaces of a drill bit to determine drill bit wear of the drill bit that is a result of the drilling operation of the wellbore. The method includes determining a cause of the drill bit wear based on the measure of drilling efficiency and the drill bit wear determined by performing video analytics. Based on correlation or modeling of drill bit wear and the measure of drilling efficiency, drill bit wear can be predicted and some types of drilling dysfunction mitigated in subsequent drilling runs. 1. A method comprising:detecting, during a current drilling operation of a wellbore using a current drill bit, at least one drilling attribute;determining a measure of drilling efficiency of the current drill bit based on the at least one drilling attribute;performing video analytics of at least one video that includes at least a portion of a view of wear surfaces of the current drill bit;determining a drill bit wear of the current drill bit based on the video analytics; andmodifying the current drilling operation based on the measure of drilling efficiency, the drill bit wear and a drill bit wear model that defines a relationship between the measure of drilling efficiency and the drill bit wear.2. The method of claim 1 , further comprising:updating the drill bit wear model based on the measure of drilling efficiency and the drill bit wear.3. The method of claim 1 , wherein the drill bit wear model is generated from at least one prior drilling operation.4. The method of claim 1 , further comprising:determining a cause of the drill bit wear of the current drill bit that is a result of the current drilling operation of the wellbore, wherein determining the cause of the drill bit wear is based ...

A MACHINE VISION AND MACHINE INTELLIGENCE AIDED ELECTRONIC AND COMPUTER SYSTEM FOR ASSISTING ON FORMATION DRILLING, BORING, TUNNELING ON-LINE GUIDANCE, ASSISTED DECISION AND DULL GRADING SYSTEM FOR DRILLING TOOL AND ASSOCIATED DRILL STRING COMPONENTS

An electronic system is disclosed comprising of a drill tool which is mounted on a mechanical system with either a position and angular sensor assisted guidance of the camera itself around the drill tool in a guided trajectory as in a robotic arm or mobile device on the field with the drill tool pulled out from the wellbore or when the tool can be imaged while in operation; multiple fixed cameras on a test or working rig coupled with rotary control of the drill tool, and a controller capable of controlling the drill string motor and imaging. The system automatically profiles the degraded/worn out drill tool, when the drill string-drill tool is visually available or pulled out, by executing a host of machine vision engineering based and machine intelligence/data analytics engineering algorithms, where the algorithms can calculate and provide detailed current/predictive and prescriptive analysis of the drilling tool. 2. An electronic system as claimed in wherein claim 1 , the system can deep scan and analyses a partially or used formation drilling tool on the field or in a test setup; to perform detailed dull grading and engineering analysis; providing usability and guidance on the current and future usability of the drill tool including for directional drilling operation.3. An electronic system as claimed in wherein claim 1 , the system deep scan and analyze a partially or used formation drilling tool; to analyze and identify vulnerable and problematic areas on the tool and to provide recommendations and help re-engineer in an automated manner the design of the drill tool.4. An electronic system as claimed in wherein claim 1 , the system can act as intelligent sensor in order to provide the health and status of the drill tool claim 1 , providing information and data on the historical footprint claim 1 , health and current status of the drill tool to other drilling system and software as an intelligent sensor.5. An electronic system as claimed in wherein claim 1 , the ...

Real-time multimodal radiometry for subsurface characterization during high-power laser operations

Some implementations of the present disclosure provide a method that includes: irradiating a target surface with a process beam during a drilling process; in response to irradiating with the process beam, receiving a signal beam that contains light scattered from the target surface as well as light radiating from the target surface; splitting the signal beam into a first portion on a polarization arm and a second portion on a non-polarization arm; performing, on the polarization arm, a first plurality of polarization-dependent intensity and spectrum measurements of the first portion; performing, on the non-polarization arm, a second plurality of intensity and spectrum measurements of the second portion; and based on applying one or more machine learning techniques to at least portions of (i) the first plurality of polarization-dependent intensity and spectrum measurements, and (ii) the second plurality of intensity and spectrum measurements, determining a classification of the target surface.

RISK-BASED FINANCIAL OPTIMIZATION METHOD FOR SURVEILLANCE PROGRAMS

Systems and methods include a computer-implemented method for predicting optimization scenarios. Health and defect categories are generated from historical well integrity survey data for surveyed wells. For each asset, a reference point in time and fixed analysis time durations are generated for the health and defect categories. A probability of defect (PD) cumulative distribution function (CDF) for predicting probabilities of defects over time is generated. A probability of health (PH) CDF for predicting health probabilities over time is generated. An overall probability of failure (P) function for predicting the Pfor the asset is determined. An overall age CDF for the asset is determined and is fitted to optimization scenarios for annual surveys of assets under different survey frequencies. A prediction for a number of failures is determined for each of the optimization scenarios. The predictions are provided to a user for selection of an optimization scenario. 1. A computer-implemented method , comprising:generating a health category and a defect category of data points of historical well integrity survey data for surveyed wells;identifying, for each asset used in a well, a reference point in time and fixed analysis time durations for the health and defect categories of the data points;generating, using the fixed analysis time durations for the health and defect categories of the data points, a probability of defect (PD) cumulative distribution function (CDF) for predicting probabilities of defects over time, and a probability of health (PH) CDF for predicting health probabilities over time;{'sub': f', 'f, 'determining, using the PD CDF and the PH CDF, an overall probability of failure (P) function for predicting the Pfor the asset;'}{'sub': f', 'f, 'determining, using the PCDF, and the overall Pfunction, an overall age CDF for the asset;'}fitting the overall age CDF for the asset to optimization scenarios for annual surveys of assets under different survey ...

Modular Borehole Imaging Apparatus and Methods

The present disclosure introduces an apparatus including a toolstring for use in a tubular extending into a subterranean formation. The toolstring includes modular components that include one or more caliper modules and a power and control (P/C) module. The one or more caliper modules each include radially rotatable fingers for sensing an internal diameter of the tubular. The P/C module is operable for distributing power and control signals to the one or more caliper modules. The caliper and P/C modules are mechanically and electrically interconnected by common lower interfaces of the caliper and P/C modules. 1. An apparatus comprising: one or more caliper modules each comprising a plurality of radially rotatable fingers for sensing an internal diameter of the tubular; and', 'a power and control (P/C) module operable for distributing power and control signals to the one or more caliper modules;', 'wherein the caliper and P/C modules each have an upper and a lower interface,', 'wherein the lower interfaces of the caliper and P/C modules are identical.', 'wherein the caliper and P/C modules are mechanically and electrically interconnectable via interconnection of upper interface of the caliper and lower interface of the P/C modules., 'a toolstring for use in a tubular extending into a subterranean formation, wherein the toolstring comprises a plurality of modular components that includes2. The apparatus of wherein:the plurality of modular components further includes one or more centralizer modules operable for centralizing the one or more caliper modules within the tubular;the P/C module is operable for distributing power and control signals to the one or more centralizer modules; andwherein the caliper, P/C and centralizer modules each have lower and upper interfaces,wherein the upper interfaces of at least the caliper and centralizer modules are identical,wherein the lower interfaces of the caliper, P/C and centralizer modules are identical,wherein the caliper, ...

Downhole sensing via swept source lasers

Systems and methods for performing downhole analysis within a well bore employ a swept source laser that can be sent downhole to generate high resolution images of the well bore. Various embodiments can also determine other physical properties of a below ground structure. The swept source lasers can create images using low-coherence interferometry or optical coherence tomography. Systems and methods may also be used to determine fluid flow rates towards the sensor at discrete points, such as individual perforations, by measuring the Doppler effect on the light back-scattered from the fluid. Fluid flow information could also be extracted by measuring the phase shift of the light between subsequent light scans if a phase sensitive detection scheme is utilized.

SENSOR ARRANGEMENT

A sensor arrangement is described comprising a sensor housing (), a first sensor () sensitive to a downhole parameter and carried by the housing (), a second sensor () sensitive to the same downhole parameter as the first sensor () and carried by the housing (), the second sensor () being spaced apart from the first sensor () by a fixed distance D in the axial direction of the housing (), and a control unit () operable to monitor the outputs of the first and second sensors () to ascertain information relating to the position, movement and/or related information of the housing (). A related operating method is also described. 1. A sensor arrangement comprising a sensor housing , a first sensor sensitive to a downhole parameter and carried by the housing , a second sensor sensitive to the same downhole parameter as the first sensor and carried by the housing , the second sensor being spaced apart from the first sensor by a fixed distance in the axial direction of the housing , and a control unit operable to monitor the outputs of the first and second sensors to ascertain information relating to at least one position , movement and related information of the housing.2. An arrangement according to claim 1 , wherein the housing is incorporated into or attached to a bottom hole assembly claim 1 , providing position information relating to the position of the bottom hole assembly claim 1 , and/or is located elsewhere in a drill string.3. An arrangement according to claim 1 , wherein the downhole parameter comprises temperature information.4. An arrangement according to claim 1 , wherein the first and second sensors comprise one of thermoelectric generators and thermal cameras operable to produce an output indicative of a temperature difference between parts of the housing and an inner tubular member adjacent the respective sensors.5. An arrangement according to claim 4 , wherein the first and second sensors together form a panoramic thermal camera.6. An arrangement ...

Method for Combining the Results of Ultrasound and X-Ray and Neutron Cement Evaluation Logs Through Modality Merging

A combining mechanism for borehole logging tool data that employs modality merging to combine the output data of various borehole logging tools to provide a combined result and automated interpretation is provided, said mechanism comprising: at least one mechanism for assigning interpretive values to individual processed data types; at least one mechanism for combining the interpretive value data sets; and, at least one mechanism for providing an interpretation. A method of combining borehole logging tool data that employs modality merging to combine the output data of various borehole logging tools to provide a combined result and automated interpretation is also provided, said method comprising: assigning interpretive values to individual processed data types; combining the interpretive value data sets; and, providing an interpretation. 1. A combining mechanism for borehole logging tool data that employs modality merging to combine the output data of various borehole logging tools to provide a combined result and automated interpretation , comprising:at least one mechanism for assigning interpretive values to individual processed data types;at least one mechanism for combining the interpretive value data sets; andat least one mechanism for providing an interpretation.2. The combining mechanism of claim 1 , wherein said mechanism is configured to process ultrasound or acoustic data from a borehole logging tool.3. The combining mechanism of claim 1 , wherein said mechanism is configured to process x-ray data from a borehole logging tool.4. The combining mechanism of claim 1 , wherein said mechanism is configured to process neutron porosity data from a borehole logging tool.5. The combining mechanism of claim 1 , wherein said mechanism is configured to process neutron activation data from a borehole logging tool.6. The combining mechanism for borehole logging tool data of claim 1 , wherein said borehole tool is a wireline-based tool.7. The combining mechanism for ...

Workflow and Visualization for Localization of Concentric Pipe Collars

A method and system for visualizing data to detect a collar. A method may comprise disposing an electromagnetic logging tool downhole; emitting an electromagnetic field from the transmitter; energizing a casing with the electromagnetic field to produce an eddy current; recording the eddy current from the casing with the receiver; creating a variable-density-log from the recorded eddy current; selecting a wrapping period for the variable-density-log; creating a wrapped-variable-density-log from the variable-density-log using the wrapping period; and determining at least one collar location and a pipe index with the wrapped-variable-density-log. A system for to detect a collar may comprise an electromagnetic logging tool. The electromagnetic logging tool may comprise a transmitter and a receiver, wherein the transmitter and the receiver may be a coil. The system may further comprise an information handling system. 1. A method for visualizing data to detect a collar comprising: a transmitter; and', 'a receiver;, 'disposing an electromagnetic logging tool downhole, wherein the electromagnetic logging tool comprisesemitting an electromagnetic field from the transmitter;energizing a casing with the electromagnetic field to produce an eddy current;recording the eddy current from the casing with the receiver;creating a variable-density-log from the recorded eddy current;selecting a wrapping period for the variable-density-log;creating a wrapped-variable-density-log from the variable-density-log using the wrapping period; anddetermining at least one collar location and a pipe index with the wrapped-variable-density-log.2. The method of claim 1 , further comprising adjusting the wrapping period until a substantially horizontal pattern is obtained.3. The method of claim 2 , wherein the determining the at least one collar location and the pipe index using a smoothness constraint on a line that connects adjacent identification of a plurality of collars.4. The method of claim 2 , ...

Methods for transmitting data acquired downhole by a downhole tool

The disclosure relates to a method and system for downhole processing of data, such as images, including using a set of downhole sensors to measure parameters relative to the borehole at a plurality of depths and azimuths and detecting predetermined features of the borehole, using a downhole processor, with a trained machine-learning model and extracting characterization data, characterizing the shape and position of the predetermined features that are transmitted to the surface. It also provides a method and system for providing an image of a geological formation at the surface including transmitting a first dataset to the surface that will be used for reconstructing an image at the surface, downhole processing of a second dataset to detect predetermined features and extract characterization data that are transmitted at the surface and displaying a combined image comprising the predetermined features overlaid on the first image. 1. A method for providing an image relative to a borehole crossing a geological formation based on data acquired downhole by a downhole tool comprising at least a first and second imaging sensor sets , the method including:a. Transmitting a first dataset acquired by the first imaging sensor set at the surface,b. Reconstructing a first image using the first dataset,c. Processing downhole a second dataset acquired by the second imaging sensor set, wherein the downhole processing includes detecting predetermined rock structural features of the borehole and extracting characterization data characterizing the shape and position of at least one of the predetermined features,d. Transmitting at the surface the characterization data,e. Based on characterization data, displaying a combined image comprising the predetermined rock structural features overlaid on the first image.2. The method of claim 1 , wherein the first imaging sensor set is a resistivity sensor set and the second imaging sensor set is an ultrasonic sensor set.3. The method of claim ...

Removable oil well seal

A method of sealing a well having a casing wall comprises transporting a camera into the casing wall making a visual recording by visually recording perforations, microfractures or other breach type damages of the wall and vertical location thereof on the wall. Selecting a vertical location for sealing the well, the vertical location being determined from the visual recording. Transporting an expandable sealing device being made of an expandable metal and a hydraulic cylinder attached to the sealing device by a shear pin into the well. Expanding the sealing device to engage the casing wall such that a gas seal is made between the sealing device and the casing wall, the sealing device being expanded through engagement by the hydraulic cylinder. 1. A method of sealing a well having a casing wall , the method comprising:transporting a camera into the casing wall making a visual recording by visually recording perforations, microfractures or other breach type damages of the wall and vertical location thereof on the wall;selecting a vertical location for sealing the well, the vertical location being determined from the visual recording;transporting an expandable sealing device being made of an expandable metal and a hydraulic cylinder attached to the sealing device by a shear pin; andexpanding the sealing device to engage the casing wall such that a gas seal is made between the sealing device and the casing wall, the sealing device being expanded through engagement by the hydraulic cylinder.2. The method of wherein the sealing device is positioned above the perforations claim 1 , microfractures or other breach type damages of the wall.3. The method of wherein the sealing device is expanded to an engagement point with the casing wall such that the engagement with casing wall breaks the shear pin.4. The method of wherein the expandable metal comprises brass.5. An apparatus for sealing a well claim 1 , the apparatus comprising:a hydraulic cylinder having a rod extending ...

Method and apparatus for communication of wellbore data, including visual images

A wireless communication assembly permits convenient and effective communication between down hole logging and/or data storage tools conveyed via non-conductive wireline and surface equipment, including while such tools are situated within a lubricator, wellhead or other surface equipment. Data acquired by a down hole logging or data storage tool is transmitted to a wireline-conveyed communication assembly, and then wirelessly transmitted to a surface data communication assembly. Thereafter, such data can then be acquired, displayed and/or downloaded via an external data port on said surface data communication assembly using a wired or wireless connection.

Segmentation of time-frequency signatures for automated pipe defect discrimination

A method for taking measurements in a wellbore including lowering a downhole logging tool in the wellbore; obtaining, via the logging tool, a plurality measurements of a downhole element; processing the plurality of measurements to obtain a plurality of processed measurements; calculating a contour model based on the plurality of processed measurements; and determining a parameter of the downhole element based on the contour model.

SYSTEM AND METHOD FOR DETERMINING FORMATION CHARACTERISTICS USING ELECTRICAL ARC MODELING

A disclosed downhole drilling system may include a drill bit electrically coupled to a pulse-generating circuit to generate electrical arcs between first and second electrodes during pulsed drilling operations, a sensor to record responses to electromagnetic or acoustic waves produced by the electrical arcs, and a sensor analysis system. The electrical arcs occur at different azimuthal locations between the electrodes. The sensor analysis system may obtain a plurality of measurements representing first responses recorded by the sensor during a pulsed drilling operation, generate a model of a source of the electrical arcs based on the measurements, obtain an additional measurement representing a second response recorded by the sensor during the operation, and determine a characteristic of a formation near the drill bit using an inversion based on the model and the additional measurement. The determined characteristic may be used to determine dip parameters or construct images of the formation. 1. A downhole drilling system , comprising:a drill bit including a first electrode and a second electrode, the first and second electrodes electrically coupled to a pulse-generating circuit to generate electrical arcs between the first and second electrodes based on pulse drilling signals received from the pulse-generating circuit during a pulsed drilling operation in a wellbore, the electrical arcs occurring at random azimuthal locations between the first and second electrodes;a sensor to record responses to electromagnetic waves or acoustic waves produced by the electrical arcs; and a processor; and', obtain a first plurality of measurements representing first responses recorded by the sensor during the pulsed drilling operation;', 'generate a model of a source of the electrical arcs based on the first plurality of measurements;', 'obtain an additional measurement representing a second response recorded by the sensor during the pulsed drilling operation; and', 'determine a ...

SYSTEM, METHOD AND APPARATUS FOR REDUCED WATER USAGE FOR FRACTURING HYDROCARBON WELLS WITH THREE-DIMENSIONAL IMAGING OF THE FORMATION FROM A SINGLE BOREHOLE

Provided are methods of reducing water consumption in a fracturing operation. The methods can include imaging a geologic formation surrounding a borehole using a downhole tool within the borehole. The method can further include identifying, within the image, fractures conducive to hydrocarbon production; correlating the fractures conducive to hydrocarbon production to fracture zones; and selecting locations of the fracture zones to be hydraulically fractured, wherein the selected locations collectively represent less than the axial length of the borehole, thereby reducing water consumption compared to hydraulic fracturing along an entirety of the axial length. 1. A method of reducing water consumption in a fracturing operation , comprising:imaging a geologic formation surrounding a borehole using a downhole tool within the borehole, the imaging along an axial length of the borehole within the geologic formation, and the imaging creates an image indicative of natural fractures within the geologic formation;identifying, within the image, fractures conducive to hydrocarbon production;correlating the fractures conducive to hydrocarbon production to fracture zones along the axial length, wherein each fracture zone spans a portion of the axial length, and collectively the fracture zones are less than the axial length; andidentifying locations of the fracture zones to be hydraulically fractured, thereby reducing water consumption compared to hydraulic fracturing along an entirety of the axial length of the borehole within the geologic formation.2. The method of claim 1 , wherein the step of identifying locations of the fracture zones to be hydraulically fractured is by way of a computer interface device.3. The method of or further comprising hydraulic fracturing of the fracture zones claim 1 , and refraining from hydraulic fracturing at least some remaining zones outside the fracture zones.4. The method of claim 3 , wherein hydraulic fracturing is only within the fracture ...

Optimized geosteering using real-time geological models

Systems and methods for optimized geosteering using real-time geological models that are updated with LWD measurements containing data such as, for example, layer boundaries and formation properties.

Apparatus for Monitoring At Least A Portion Of A Wellbore

There is described an apparatus for monitoring at least a portion of a wellbore, the apparatus comprising a body including at least an anchoring means for releasably positioning the apparatus with respect to a tubular in the wellbore. The apparatus comprises detecting means for detecting at least one parameter of a substance in the portion, and in that the apparatus comprises transceiver means configured to at least transmit data related to the parameter.

Optical sensor and method of use

An interferometer apparatus for an optical fibre system and method of use is described. The interferometer comprises an optical coupler and optical fibres which define first and second optical paths. Light propagating in the first and second optical paths is reflected back to the optical coupler to generate an interference signal. First, second and third interference signal components are directed towards respective first, second and third photodetectors. The third photodetector is connected to the coupler via a non-reciprocal optical device and is configured to measure the intensity of the third interference signal component directed back towards the input fibre. Methods of use in applications to monitoring acoustic perturbations and a calibration method are described.

An Apparatus for Verifying the Inner Diameter of Tubulars Forming A Tubular String

A floating drift apparatus for verifying the inner diameter of tubulars as the tubulars are made up into a tubular string being run into a wellbore. A float section provides buoyancy to float the apparatus in fluid within the bore of a tubular, and a drift section has a drift element with a diameter substantially equal to the tubular inner diameter being verified, which may be the drift diameter. When running a tubular string, the apparatus is inserted into the bore of the tubular string, floating in the fluid. As joints of tubular are made up and run into the wellbore, the tubulars move downhole around the apparatus. Preferably, the floating drift apparatus can be visually detected. If an undersize ID is encountered, the floating drift apparatus will be pushed downhole and no longer visible; the operator can remove the undersize ID tubular from the string.

Bandwith Extension of Geophysical Data

A methodology for extending bandwidth of geophysical data is disclosed. Geophysical data, obtained via a towed streamer, may have significant noise in a certain band (such as less than 4 Hz), rendering the data in the certain band unreliable. To remedy this, geophysical data, from a band that is reliable, may be extended to the certain band, resulting in bandwidth extension. One manner of bandwidth extension comprises using machine learning to generate a machine learning model. Specifically, because bandwidth may be viewed as a sequence, machine learning configured to identify sequences, such as recurrent neural networks, may be used to generate the machine learning model. In particular, machine learning may use a training dataset acquired via ocean bottom nodes in order to generate the machine learning model. After which, the machine learning model may be used to extend the bandwidth of a test dataset acquired via a towed streamer. 1. A computer-implemented method for bandwidth extension of geophysical data , the method comprising:accessing a machine learning model configured to identify one or more correlations between a first frequency band and a second frequency band;accessing measured seismic data from the first frequency band; andpredicting frequency response in the second frequency band based on the accessed machine learning model and the measured seismic data.2. The method of claim 1 , wherein the accessed machine learning model comprises a sequence-to-sequence model.3. The method of claim 2 , wherein the sequence-to-sequence model identifies a sequence for the first frequency band claim 2 , identifies a sequence for the second frequency band claim 2 , and correlates the sequence for the first frequency band to the sequence for the second frequency band.4. The method of claim 3 , wherein the sequence-to-sequence model comprises an encoder identifying the sequence for the first frequency band claim 3 , a decoder identifying the sequence for the second ...

Downhole inspection, detection, and imaging using conformable sensors

An example method for downhole surveying and measuring may include receiving a measurement from a receiver of a conformable sensor, the measurement corresponding to a response of a downhole element to an electromagnetic signal generated by a transmitter of the conformable sensor. A parameter of the downhole element may be determined based, at least in part, on the received measurement. A visualization of a feature of the downhole element may be generated based, at least in part, on at least one of the received measurement and the determined parameter.

Apparatus, system, and method for downhole imaging using a non-rotatable imaging tool having a radiation detector

A non-rotatable, downhole imaging tool, an imaging system including the non-rotatable imaging tool and methods of determining information about a wellbore employing the non-rotatable imaging tool are provided herein. One example of a non-rotatable imaging tool is disclosed that has a central axis and horizontal planes perpendicular to the central axis, and further includes: (1) a radiation detector positioned proximate the central axis and uniquely on one of the horizontal planes, and (2) a collimator configured to limit exposure of the radiation detector to a single azimuthal area along a circumference of the downhole imaging tool on the one of the horizontal planes.

VIRTUAL REAL TIME OPERATION

To reduce the expense associated with having experts work at remote hydrocarbon recovery, exploration, operation, or services environment site, such experts may use a virtual real time operation center to obtain information from and give instructions to the remote site. Such a virtual operation center may receive information from the site from a variety of different machines such as equipment pieces, controllers, or human machine interface personal computers. 1. A virtual real time operation and collaboration system comprising:a virtual real time operation center;a hydrocarbon recovery, exploration, operation or services environment site;a controller disposed about a hydrocarbon recovery, exploration, operation or services environment site which controls the operation of one or more equipment pieces, wherein the controller transmits at least one of real time data and one or more images to the virtual real time operation center; anda human machine interface that is coupled to the controller.2. The system of wherein the controller at least one of measures real time data and records one or more images from the at least one hydrocarbon recovery claim 1 , exploration claim 1 , operation claim 1 , or services environment site.3. The system of wherein one or more equipment pieces at least one of measures real time data and records one or more images from the at least one hydrocarbon recovery claim 1 , exploration claim 1 , operation claim 1 , or services environment site.4. The system of wherein the controller comprises at least one network server operable to transmit the at least one of the real time data and the one or more images to the virtual real time operation center through a communication pathway.5. The system of further comprising a display at the virtual real time operation center that displays the at least one of real time data and one or more images to one or more users.6. The system of further comprising an augmented reality device at the real time operation ...