УСТРОЙСТВО ДЛЯ ОПРЕДЕЛЕНИЯ ПОЛОЖЕНИЯ ИНСТРУМЕНТА ДЛЯ ФОРМИРОВАНИЯ НАКЛОННЫХ И ГОРИЗОНТАЛЬНЫХ СКВАЖИН (ВАРИАНТЫ)

Изобретение относится к горному делу - к технике контроля направленного горизонтального бурения, используется для определения горизонтального положения и поворота инструмента для формирования наклонных и горизонтальных скважин вокруг оси для последующего управления траекторией его движения. Техническим результатом изобретения является повышение надежности и точности, расширение возможности применения устройства за счет передачи информации по беспроводному каналу связи. Устройство по первому варианту содержит три ртутных датчика (РД), соединенных каждый с одним из трех мультивибраторов, соединенных с соответствующими входами СВЧ-генератора, выход которого соединен со входом передающей антенны. Приемник электромагнитных сигналов (ЭМС) расположен на земле. Его три выхода соединены соответственно с входами трех активных фильтров, каждый соединенный выходом с соответствующим входом одного из трех световых индикаторов положения инструмента. Оси первого и третьего РД симметричны относительно оси ...

ДОСТУП В МНОГОСТВОЛЬНУЮ СКВАЖИНУ С ПЕРЕДАЧЕЙ ДАННЫХ В РЕЖИМЕ РЕАЛЬНОГО ВРЕМЕНИ

Изобретение относится к средствам для проведения работ в многоствольной скважине. Техническим результатом является обеспечение возможности проведения операций в скважине даже в случае, когда застревают нижние компоненты скважинного снаряда. В частности предложен скважинный снаряд, содержащий: зонд; выбросовый шарнирный отклонитель, присоединенный к зонду для отклонения зонда от центральной оси; ориентирующий переводник, выполненный с возможностью регулировки угловой ориентации по меньшей мере выбросового шарнирного отклонителя и зонда относительно центральной оси; измерительное устройство ориентации, выполненное с возможностью измерения азимута, наклона и направления передней поверхности инструмента; скважинное телеметрическое устройство, присоединенное с возможностью связи к измерительному устройству ориентации для передачи данных о местоположении устройства на поверхность в режиме реального времени; и переходник последовательного действия, приводимый в действие для предотвращения проникновения ...

СПОСОБ ИЗМЕРЕНИЯ АЗИМУТА ГОРИЗОНТАЛЬНЫХ КОМПОНЕНТ ЧУВСТВИТЕЛЬНОСТИ СКВАЖИННЫХ СЕЙСМОПРИЕМНИКОВ

Изобретение относится к измерительной технике и системам обработки информации и может быть использовано для измерения азимута горизонтальных компонент чувствительности скважинных сейсмоприемников. Способ измерения азимута горизонтальных компонент чувствительности скважинных сейсмоприемников заключается в том, что измерения проводятся методом сравнения их направления с измеренным направлением осей чувствительности контрольного сейсмоприемника, при этом отсутствует необходимость размещения дополнительного оборудования в скважине и определены диапазоны частот, каждый из которых используется при расчете азимута при обеспечении заданной точности и определяется как сумма значений угла между осями чувствительности проверяемого и контрольного сейсмоприемников, угла ориентации оси чувствительности контрольного сейсмоприемника относительно направления на магнитный север и магнитного склонения в месте установки сейсмоприемника. Техническим результатом является измерение азимута горизонтальных компонент ...

АВТОМАТИЗАЦИЯ БУРЕНИЯ СКВАЖИН С ИСПОЛЬЗОВАНИЕМ ПРОФИЛЯ ЭНЕРГИИ И ФОРМЫ СТВОЛА СКВАЖИНЫ

ДОСТУП В МНОГОСТВОЛЬНУЮ СКВАЖИНУ С ПЕРЕДАЧЕЙ ДАННЫХ В РЕЖИМЕ РЕАЛЬНОГО ВРЕМЕНИ

Прибор для ориентирования искусственных отклонителей

Электробур

Устройство для спуска приборов в наклонные скважины

Устройство для ориентирования отклонителя

Изобретение относится к технике проводки наклонно направленных скважин- забойными двигателями. Цель изобретения - повышение быстродействия и точности ориентирования. Устр- во содержит телеметрическую систему, включающую забойные датчики 3, наземный пульт 2 с регистратором углов положения отклонителя, азимута и наклона скважины, блок 4 сравнения,блок 1 задания углз положения отклонителя, исполнительный механизм 5 поворота бурильной колонны с породоразрушаю- щим инструментом. Устр-во имеет преобразователь 6 рассогласования сигналов углов положения отклонителя, подключенный к механизму 5 и связанный с регулятором 13 подачи породоразру- шающего инструмента. Ориентирование отклонителя осуществляют с помощью механизма 5 и с помощью регулятора 13. Используют при этом зависимость угла закручивания низа бурильной колонны реактивным моментом забойного двигателя от величины осевого усилия на долото. 1 з.п. ф-лы, 2 ил. § (Л ...

Индикатор для определения угла разворота фотозонда вокруг оси наклонной скважины при непрерывном фотокаротаже

Изобретение относится к горному делу. Цель изобретения - упрощение и повышение точности измерений. Для этого индикатор имеет волоконно-оптический преобразователь изображения с регулярной укладкой торцов световодов . Входные торцы световодов уложены влотную друг к другу в виде кольца и сопряжены с торцом полого цилиндра 5, а выходные торцы уложены вплотную друг к другу Б линию по ширине фотопленки 2. Освещенные входные торцы через выходные торцы передают свет на тыльную сторону движущейся фотопленки 2. Выходные торцы имеют прямоугольное сечение и уложены вдоль прямой линии вплотную один к другому широкими сторонами сечения. Благодаря этому на фотопленке 2 запечатлевается изображение кольцевой щели в виде линейки с разрывом в точке расположения изображения воздушного пузырька на фоне заснятого на эмульсионную сторону изображения стенок скважины. Индикатор позволяет одновременно измерять одну угловую координату, а для измерения двух координат составляется конструкция из двух индикаторов. 2 ...

Прибор для определения угла установки отклонителя в скважине

Прибор для ориентирования отклоняющего инструмента при наклонном бурении скважин

Drehbare Sensoren zur Messung von Eigenschaften einer unterirdischen Formation

Bohrlochanordnung (214), umfassend:einen Werkzeugstrang (212);einen mit dem Werkzeugstrang (212) gekoppelten richtungsabhängigen Sender (216);einen mit dem Werkzeugstrang (212) gekoppelten richtungsabhängigen Empfänger (218), wobei zumindest einer von dem richtungsabhängigen Empfänger (218) und dem richtungsabhängigen Sender (216) bezogen auf den Werkzeugstrang (212) drehbar ist; undein mit zumindest dem Empfänger (218) kommunikativ gekoppeltes Informationsverarbeitungssystem, wobei das Informationsverarbeitungssystem einen Prozessor (1102) und eine mit dem Prozessor gekoppelte Speichervorrichtung (1104) umfasst, wobeizumindest einer von dem Sender (216) oder Empfänger (218) eine Antenne einschließt, die eine erste, in einer ersten Wicklungsebene (217) angeordnete Wicklung (215) und eine zweite, in einer zweiten Wicklungsebene (219) angeordneten Wicklung (213) aufweist, wobei die erste Wicklung (215) bezogen auf die zweite Wicklung (213) geneigt ist, wobei der in der Speichervorrichtung ...

Tragbare Anbringung einer faseroptischen Messschleife

Der Gegenstand dieser Patentschrift kann unter anderem in einem System zum lösbaren Anbringen einer Lichtleitersensorschleife an einem röhrenförmigen Element verkörpert werden, das eine Lichtleitersensorschleife, die einen Lichtleiter aufweist, der in einer Vielzahl von Schleifen positioniert angeordnet ist, wobei jede der Schleifen eine erste Endwende und eine zweite Endwende aufweist, eine erste und eine zweite Wendeführung, die jeweils eine Vielzahl von Wendenuten beinhalten, die in zunehmenden Radien nach außen zunehmen, wobei jede der Wendenuten dazu konfiguriert ist, einen Endwendeabschnitt des Lichtleiters aufzunehmen, einen ersten und einen zweiten Trägerkeil, die jeweils eine ebenflächige erste Fläche, die dazu konfiguriert ist, eine Wendeführung aufzunehmen, und eine gekrümmte zweite Fläche aufweisen, die dazu konfiguriert ist, an dem röhrenförmigen Element aufgenommen zu werden, und einen Verbinderbeinhaltet, der dazu konfiguriert ist, den ersten Montagekeil an den zweiten Montagekeil ...

Method and apparatus

Method and apparatus for orienting perforating devices

INDICATOR FOR SIGNALLING THE ANGULAR ORIENTATION OF A WELL DRILLING STRING IN AN INCLINED WELL

... 1,205,068. Drilling. BYRON JACKSON Inc. 16 Oct., 1968, No. 49115/68. Heading E1F. [Also in Division G1] Signalling apparatus adapted to be installed in a string for drilling an inclined well using a whip stock or deflection tool, or a bit having a jet orifice at one side larger than the other orifices, and to produce pressure pulse signals in a stream of drilling fluid indicative of the angular orientation of the string about its own axis in the inclined well, comprises a tubular body or drill collar 5, a member 14 movable in one direction upon interruption of the flow of the drilling fluid and movable in the other direction upon resumption of the flow, means-e.g. rings 7-cooperative with the member 14 to produce a number of pressure pulses dependent on the extent of movement of the member, and stops 17 arranged to limit the movement of member 14 according to the angular orientation of the string in the well. As shown member 14 comprises the head of a shaft 13 which is moved upwardly by ...

Apparatus and method for orienting and setting a hydraulically actuated tool in a borehole

An apparatus for detecting and properly orienting a hydraulically-actuatable tool in a borehole and commencing drilling in a single trip of the drill string includes an MWD subassembly, for sensing the orientation, and a bypass valve for setting the hydraulically-actuatable tool once it is properly oriented and for thereafter conducting the drilling fluid to the cutter assembly. The method of setting a hydraulically-actuatable tool and commencing drilling in a single trip of the drill string includes the steps of running the hydraulically-actuatable tool into the borehole on a drill string which includes an MWD subassembly, sensing the orientation using the MWD subassembly, orienting the drill string to the desired orientation, and setting the hydraulically-actuatable tool.

Scoop and method of orienting and setting a whipstock assembly

Method of servicing a subterranean well

Magnetization of target well casing string tubulars for enhanced passive ranging

Device and method for determining the roll angle of a device having a housing

The invention relates to a device for determining the roll angle of a device having a housing, wherein a coil, which is arranged on or in the housing so as to be rigid in relation to the housing of the device, and an actuation electronic system, which generates voltage profiles that are limited chronologically by means of the coil, are provided.

Reverse inertial navigation method for high precision wellbore surveying

A method of surveying a wellbore that contemplates positioning a probe having an inertial measurement unit in a wellbore at the wellbore bottom. The wellbore is surveyed by retrieving the probe from the wellbore bottom and determining the incremental positions of the probe during the retrieval using the inertial measurement unit. The probe retrieval is stopped at a survey endpoint whose true position is known. The survey is corrected using the difference between the survey endpoint probe position determined by the inertial measurement unit and the known true survey endpoint position.

REALTIME DOGLEG SEVERITY PREDICTION

A method for estimating an inclination and azimuth at a bottom of a borehole includes forming a last survey point including a last inclination and a last azimuth; receiving at a computing device bending moment and at least one of a bending toolface measurement and a near bit inclination measurement from one or more sensors in the borehole; and forming the estimate by comparing possible dogleg severity (DLS) values with the bending moment value.

Improved formation evaluation through azimuthal tool-path identification

Method and system for determining downhole object orientation

Real time misalignment correction of inclination and azimuth measurements

A method for determining wellbore trajectory includes determining survey parameters in the wellbore; measuring force parameters) in the wellbore; and correcting the survey parameters using the measured force parameter(s). The downhole measured force parameters may include forces associated with an operation of a steering device such as an internal reaction force, and /or a bending moment. In variants, the method may include measuring a wellbore temperature; measuring a wellbore parameter in addition to the temperature; and correcting a survey parameter using the measured parameter and the measured temperature. These methods may include correcting survey parameters using measured wellbore diameters. Also, a processor in the wellbore may be programmed to perform the correction while in the wellbore and / or control a steering device using measurements provided by a sensor for measuring internal reaction forces.

Method and system for determining downhole object orientation

A method and tool used for determining the orientation of a downhole object, comprising providing the downhole object with a high frequency highly directional sound source 36 fixed in known relation to the object; operating the high frequency directional sound source; rotating the downhole object; and detecting the high frequency directional sound source using an optical fiber 56 acoustic sensing system 58 deployed downhole when the high frequency directional sound source is pointing at the optical fiber; wherein the rotational orientation of the downhole object with respect to the optical fiber is determined based on the detection of the sound source and the known fixed relation between the sound source and the object and the tool comprises an optical interferometer 58, which may be described as a DAS or distributed acoustic sensing system, arranged to detect optical backscatter signals from the optical fiber. In preferred embodiments the sound source is an ultrasonic source 36 operating ...

METHODS OF AND APPARATUS FOR EFFECTING LOGGING OR SERVICING OPERATIONS IN BOREHOLES

Continuous locating while drilling

Apparatus and method for processing and interpreting NMR logging data

Apparatus, method and system for processing and interpreting nuclear magnetic resonance (NMR) data acquired for a formation from within a subterranean wellbore that includes independently obtaining D - T 1 and D - T 2 from the same set of NMR data using a dual step independent 2D inversion method that provides adequate resolution in all dimensions for T 1 , T 2 , and D distributions ...

Method for completing a wellbore

Method of longitudinally splitting a pipe coupling within a wellbore

Systems and methods to determine torque and drag of a downhole string

A computer-implemented method to determine torque and draft of a downhole string, the method comprising determining an average length of a plurality of continuous segments of a downhole string, wherein the average length of the plurality of continuous segments of a downhole string is equal to a length of a curved well path divided by a number of the continuous segments of the downhole string; determining a deflection of the downhole string where the average length of the plurality of continuous segments is equal to the length of the curved well path divided by the number of the continuous segments of the downhole string; determining a location of the downhole string with respect to an upper boundary of the wellbore. In response to a determination that the downhole string reaches the upper boundary, applying a stiff string model to determine a torque and a drag of the downhole string; and in response to a determination that the downhole string does not reach the upper boundary, applying ...

Sensor device for a down hole surveying tool

Core sample orientation

Modular core orientation system.

Core Sample orientation.

DOWN HOLE SURVEYING TOOL

Core sample orientation

Modular core orientation system.

Sensor device for a down hole surveying tool

Down hole surveying tool

Process and device of diagraphics using a probe equipped with shoes of measurement.

Horizontal directional drilling in wells.

Sensor device for a down hole surveying tool

Down hole surveying tool

Down hole surveying tool

Core sample orientation

Modular core orientation system.

EXPAND DEVICE

ADJUSTMENT DEVICE FOR A NUCLEAR SAMPLE

SENSOR SYSTEM

INSULATING ELECTRICAL CONNECTION OF A DRILLING RANK

DETERMINATION OF THE ADJUSTMENT AND/OR POSITION OF THE BOREHOLE DEVICE

SENSOR PROCEDURE FOR TOOL SURFACES

PROCEDURE AND DEVICE FUER BOREHOLE MEASUREMENTS OF MEANS OF A WITH PUTTING ON SHOES MISTAKES OF PROBE EQUIPMENT.

BOREHOLE TOOL

Signaling devices for use in a drilling raw strand

Method and apparatus for a high side orienting sub for multi-lateral installations

An apparatus for indicating the orientation of a structure which includes an orienting sub (18) releasably connected at an outer case (50). The orienting sub is at a preselected orientation relative to the structure. A change in fluid pressure of a predetermined magnitude of flow rate through the orienting sub will indicate that the structure is at a desired orientation in the well.

Down hole surveying tool

A down hole surveying tool (10) for directional surveying of boreholes. The tool (10) comprises a body (11) which accommodates a two-axis gyroscope (13) and a two-axis accelerometer (15). The gyroscope (13) and accelerometer (15) are rigidly fixed with respect to each other to provide a composite sensor device (17). The sensor device (17) is supported in a rotary mount (31) for rotation about an indexing axis (4). The sensor device (17) can be indexed about the indexing axis between two indexing positions which are 180 degrees apart. An indexing mechanism (70) is provided for selectively indexing the sensor device (17) about the indexing axis (4). The indexing mechanism (70) comprises a drive portion (71) and a driven portion (72) adapted for selective interaction to impart indexing motion to the sensor device (17). The driven portion (72) is movable into and out of engagement with the drive portion (71) upon rotation of the rotary mount (31) about a pitch axis (1) using a pitch drive mechanism ...

Horizontal directional drilling in wells

Logging while drilling method and apparatus for measuring formation characteristics as a function of angular position within a borehole

Modular electromagnetic ranging system for determining location of a target well

An electromagnetic ranging system and method for location a target well. The electromagnetic ranging system may comprise a modular electromagnetic ranging tool. The electromagnetic ranging tool may comprise at least one transmitter coil and a receiver coil operable to measure at least one component of the electromagnetic field. An information handling system may be in signal communication with the modular electromagnetic ranging tool. A method for electromagnetic ranging of a target wellbore may comprise disposing a modular electromagnetic ranging tool in a wellbore, transmitting an electromagnetic field to the target wellbore from at least one transmitter coil disposed on the modular electromagnetic ranging tool, measuring at least one component of a secondary electromagnetic field, and determining a relative location of the target wellbore from at least measurements by the at least one receiver coil and one or more parameters of the at least one transmitter coil.

Integrated transmitter surveying while boring (SWB) entrenching powering device for the continuation of a guided bore hole

Reservoir management system and method

BOREHOLE INERTIAL GUIDANCE SYSTEM

Reservoir management system and method

LOGGING METHOD AND APPARATUS USING A SONDE EQUIPPED WITH MEASURING PADS

APPARATUS FOR MAKING MULTIPLE ORIENTATION MEASUREMENTS IN A DRILL STRING

CORE SAMPLE ORIENTATION

A core orientation device (10) for a core drill (12). The device (10) comprises an arrangement (14) for providing signals (16) associated with a physical orientation (18) of the core orientation device (10). Processing means (22) are provided for processing the signals (16) so as to provide processed data (23) from which a measure (24) of the physical orientation (18) of the core orientation device (10) can be established. The measure (24) is associated with the physical orientation (18) of the device (10) at a particular moment in time. A memory (26) is coupled to the processing means 22 for storing the processed data 23. To this end there is provided an interface means (27) comprising first means (28) for storing the processed data (23) in the memory (26) and second means (30) for accessing the memory (26) to provide the measure (24) of the physical orientation (18) of core orientation device (10) when required.

REMOTE ANGLE MEASUREMENT

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

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

POSITIONING AND CONVEYING WELL APPARATUS AND METHOD

In a broad aspect, the invention may include a nipple (10), a deflector (42), and a conveying tool (116). The nipple may include an upper sealing surface (26) and a lower sealing surface (28). The nipple may also include a discriminator/muleshoe (30) having an alignment profile (32) and an alignment slot (34). A protuberance/bump (40) may be disposed in the alignment slot. The deflector (42) may include an upper seal (52) and a lower seal (54) adapted for engagement with upper and lower sealing surfaces (26, 28), respectively, on the nipple. When the upper and lower seals are engaged with the upper and lower sealing surfaces, fluid circulation is substantially restricted thereby resulting in an increase in pressure that is detectable at the earth's surface. The pressure increase provides a signal that the deflector is properly positioned in the nipple. The conveying tool may include a flexible arm (122) having a latching finger (124) that is releasably engageable with a latching profile ...

ROTARY CONTROL OF ROTARY STEERABLES USING SERVO-ACCELEROMETERS

A system and method for steering a rotating downhole drilling tool is provided. The downhole tool includes an inclinometer having directional accelerometers capable of measuring drilling parameters, such as angular position and centripetal acceleration, of the downhole tool. An offset accelerometer is further included for determining centripetal acceleration of the downhole tool. Collar rotation rate and the toolface may be determined from the drilling parameters. Filters, analog to digital converters and processor devices may be used to process the signals and send commands in response thereto for steering the tool.

CORE SAMPLE ORIENTATION

... ²²²A core orientation device (10) for a core drill (12). The device (10) ²comprises an arrangement (14) for providing signals (16) associated with a ²physical orientation (18) of the core orientation device (10). Processing ²means (22) are provided for processing the signals (16) so as to provide ²processed data (23) from which a measure (24) of the physical orientation (18) ²of the core orientation device (10) can be established. The measure (24) is ²associated with the physical orientation (18) of the device (10) at a ²particular moment in time. A memory (26) is coupled to the processing means 22 ²for storing the processed data 23. To this end there is provided an interface ²means (27) comprising first means (28) for storing the processed data (23) in ²the memory (26) and second means (30) for accessing the memory (26) to provide ²the measure (24) of the physical orientation (18) of core orientation device ²(10) when required.² ...

POSITIONING AND CONVEYING WELL APPARATUS AND METHOD

In a broad aspect, the invention may include a nipple (10), a deflector (42), and a conveying tool (116). The nipple may include an upper sealing surface (26) and a lower sealing surface (28). The nipple may also include a discriminator/muleshoe (30) having an alignment profile (32) and an alignment slot (34). A protuberance/bump (40) may be disposed in the alignment slot. The deflector (42) may include an upper seal (52) and a lower seal (54) adapted for engagement with upper and lower sealing surfaces (26, 28), respectively, on the nipple. When the upper and lower seals are engaged with the upper and lower sealing surfaces, fluid circulation is substantially restricted thereby resulting in an increase in pressure that is detectable at the earth's surface. The pressure increase provides a signal that the deflector is properly positioned in the nipple. The conveying tool may include a flexible arm (122) having a latching finger (124) that is releasably engageable with a latching profile ...

METHOD AND APPARATUS FOR INITIALIZATION OF A WELLBORE SURVEY TOOL

An apparatus for initializing a wellbore survey tool comprises a base portion and a first mounting portion mechanically coupled to the base portion. The first mounting portion can be adapted to be mechanically coupled to at least one directional reference system configured to provide data indicative of an orientation of the at least one directional reference system with respect to a reference direction. The apparatus of certain embodiments further comprises a second mounting portion mechanically coupled to the base portion, the second mounting portion configured to be mechanically coupled to a wellbore survey tool such that the wellbore survey tool has a predetermined orientation with respect to the at least one directional reference system.

LOCKING ORIENTATION SUB AND ALIGNMENT HOUSING FOR DRILL PIPE CONVEYED LOGGING SYSTEM

A method and apparatus for drill pipe conveyed logging is disclosed. In a highly deviated well borehole, the apparatus comprises a hollow housing for surrounding a logging tool, lockable and releasable rotating connector joined to said housing, and weights along one side to rotate said housing against or relative to the low side of the deviated well bore. The rotating connector includes a telescoping sleeve, and can move downwardly to lock abutting shoulders, or move upwardly to permit logging tool rotation. A nonconductor housing rotatably locks with a hollow nut and compressed rings. The housing has aligned SP electrode windows aligning with SP electrodes to operate through the housing. A male wet connector enclosed in a sealed capsule is affixed at the top end of the housing and is electrically connected to the logging tool. A cooperative female wet connector in a similar closed capsule is supported on a logging cable. The logging cable is pumped down, mechanical connection is made, ...

REMOTE ANGLE MEASUREMENT

METHOD AND APPARATUS FOR TOOL ORIENTATION IN A BORE HOLE

METHOD AND APPARATUS FOR ORIENTING A BOREHOLE DEVICE

SYSTEM, METHOD AND APPARATUS FOR PETROPHYSICAL AND GEOPHYSICAL MEASUREMENTS AT THE DRILLING BIT

Measurement of petrophysical and geophysical data of formations in a wellbore using a long gauge bit having at least one sensor therewith. The at least one sensor may be installed in at least one flute of the long gauge bit and/or in the long gauge portion thereof. Data for creating images of the formations are obtained at or near the bottom of the borehole and proximate to the long gauge bit used for drilling the borehole. Orientation of the long gauge bit is also available on a real time basis. Magnetic and/or gravitational sensors may be used in determining bit orientation. The flutes of the long gauge bit and the long gauge portion thereof may have standard inserts to accommodate various types of different sensors and electronic packages therefor.

DEVICE AND METHOD FOR SURVEYING BOREHOLES OR ORIENTING DOWNHOLE ASSEMBLIES

A heading transfer unit may be used to transfer a heading from a surface base to a MWD tool. The surface base may have a master north finder to determine a heading. The heading may be transferred to the heading transfer unit, which is in turn transferred to the MWD unit. The heading on the heading transfer unit is transferred to the MWD tool.

GEOSTEERING IN A LATERAL FORMATION

Disclosed is a downhole tool and method suitable for geosteering within a lateral formation. The downhole tool includes a gamma sensor for monitoring gamma radiation within the lateral formation. The method provides for monitoring of the location of the drill bit or a RSS within a borehole and correcting the angle of inclination to maintain the drill bit or RSS within the target zone of the lateral formation.

AN INERTIAL MEASUREMENT UNIT AND METHOD OF OPERATION

The present invention relates generally to the field of inertial measurement units (IMU's) and their use in downhole applications and particularly to an IMU configured to allow a calculation of bias or drift, an encoder steering assembly and a drilling target indicator to calculate position of a downhole implement relative to an intended path.

DRILLING APPARATUS USING A SELF-ADJUSTING DEFLECTION DEVICE AND DEFLECTION SENSORS FOR DRILLING DIRECTIONAL WELLS

An apparatus for drilling a directional wellbore is disclosed that in one non-limiting embodiment includes a drive for rotating a drill bit, a deflection device that enables a lower section of the drilling assembly to tilt about a member of the deflection device within a selected plane when the drilling assembly is substantially rotationally stationary to allow drilling of a curved section of the wellbore when the drill bit is rotated by the drive and wherein the tilt is reduced when the drilling assembly is rotated to allow drilling of a straighter section of the wellbore, and a tilt sensor that provides measurements relating to tilt of the lower section. A controller determines a parameter of interest relating to the tilt for controlling drilling of the directional wellbore.

METHOD FOR DETERMINING POSITION WITH IMPROVED CALIBRATION BY OPPOSING SENSORS

The method and system for determining position with improved calibration allows a device to initiate activity at the proper location, such as navigating a drill bit through a rock formation. A pair of position sensors (30, 30') in opposite orientations generates position data signals. A temperature sensor (40) detects temperature and duration of the temperature. An adjusted plastic bias value is determined by a processor module (50) based on the temperature data signal, the duration of the temperature, and the position data signals so as to account for bias and hysteresis errors and error correction based on the opposing orientations of the pair of position sensors. A position value is set according to the adjusted plastic bias value so that the position value is more accurate. The activity of the terminal device (20) is initiated or maintained according to the position value calibrated by the adjusted plastic bias value.

PLANNING AND REAL TIME OPTIMIZATION OF ELECTRODE TRANSMITTER EXCITATION

Planning and real time optimization of one or more modules of a downhole tool provide efficient and cost-effective deployment of a measurement system, for example, for a ranging tool. Considerations of the environment and type of operation may be considered prior to the deployment of a downhole tool such that the downhole tool comprises modules that may be optimized. Certain modules may be activated for specific operations without having to extract the downhole tool as all modules necessary to perform the specific tasks for a given operation are included prior to deployment of the downhole tool. The one or more modules may be optimized in real time based, for example, on received measurements or previous survey results. The modularity of the downhole tool allows for flexibility in fine tuning the tool according to a varying formation environment and other parameters.

MODULAR ELECTROMAGNETIC RANGING SYSTEM FOR DETERMINING LOCATION OF A TARGET WELL

An electromagnetic ranging system and method for location a target well. The electromagnetic ranging system may comprise a modular electromagnetic ranging tool. The electromagnetic ranging tool may comprise at least one transmitter coil and a receiver coil operable to measure at least one component of the electromagnetic field. An information handling system may be in signal communication with the modular electromagnetic ranging tool. A method for electromagnetic ranging of a target wellbore may comprise disposing a modular electromagnetic ranging tool in a wellbore, transmitting an electromagnetic field to the target wellbore from at least one transmitter coil disposed on the modular electromagnetic ranging tool, measuring at least one component of a secondary electromagnetic field, and determining a relative location of the target wellbore from at least measurements by the at least one receiver coil and one or more parameters of the at least one transmitter coil.

ORIENTATION DEVICE FOR A CORE SAMPLE

Core orientator (10) for a core drill (24) includes a face orientator (28) and a bottom orientator (30) supported by a shaft (50) which extends into a shroud (86). A tubular extension (90) is coupled to the shroud (86) and is slidably coupled to a main body (12). The main body (12) includes first and second latches (16) and (18). The first latches (16) releasably lock the device (10) to a core lifter case assembly (20) disposed within the core drill (24), to selectively prevent the device (10) from advancing in an uphole direction within the core drill (24). The latching system (18) operates to prevent the device (10) from falling out of the core drill (24). Face orientator (28) includes a plurality of pins (32) which can move axially to provide a plurality of profile reference points to a facing surface of a hole to be drilled. The bottom orientator (30) includes a plurality of balls (60) disposed within said respective braces (62). In initial operation, the device (10) is loaded into ...

ORIENTATION DEVICE FOR A CORE SAMPLE

Core orientator (10) for a core drill (24) includes a face orientator (28) and a bottom orientator (30) supported by a shaft (50) which extends into a shroud (86). A tubular extension (90) is coupled to the shroud (86) and is slidably coupled to a main body (12). The main body (12) includes first and second latches (16) and (18). The first latches (16) releasably lock the device (10) to a core lifter case assembly (20) disposed within the core drill (24), to selectively prevent the device (10) from advancing in an uphole direction within the core drill (24). The latching system (18) operates to prevent the device (10) from falling out of the core drill (24). Face orientator (28) includes a plurality of pins (32) which can move axially to provide a plurality of profile reference points to a facing surface of a hole to be drilled. The bottom orientator (30) includes a plurality of balls (60) disposed within said respective braces (62). In initial operation, the device (10) is loaded into ...

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

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

SELF-GUIDED GEOSTEERING ASSEMBLY AND METHOD FOR OPTIMIZING WELL PLACEMENT AND QUALITY

A self-guided geosteering assembly having an on-board, automated guidance system that incorporates a detailed subsurface earth model and well path to geosteer the assembly along a formation. While advancing along the formation, the guidance system continually monitors data related to formation characteristics and the formation/tool location, compares the data to the earth model and well path, and adjusts the direction of the assembly accordingly. In addition, the data may be utilized to update the earth model in real-time.

SELF-GUIDED GEOSTEERING ASSEMBLY AND METHOD FOR OPTIMIZING WELL PLACEMENT AND QUALITY

A self-guided geosteering assembly having an on-board, automated guidance system that incorporates a detailed subsurface earth model and well path to geosteer the assembly along a formation. While advancing along the formation, the guidance system continually monitors data related to formation characteristics and the formation/tool location, compares the data to the earth model and well path, and adjusts the direction of the assembly accordingly. In addition, the data may be utilized to update the earth model in real-time.

SYSTEM AND METHODOLOGY FOR RUNNING CASING STRINGS THROUGH A CONDUCTOR TUBE

A technique facilitates running of casing strings in a multilateral well. A conductor tube may be placed into a hole formed in a seabed. A plurality of oriented casings is deployed in the conductor tube and the oriented casings have a specific exit angle and azimuthal orientation. The orientation of each oriented casing is used to direct a corresponding drilling of a borehole and placement of a casing in the borehole in a manner which does not interfere with other boreholes and casings.

METHOD AND APPARATUS FOR CASING THICKNESS ESTIMATION

Various embodiments include apparatus and methods to provide an estimation of casing wear. One method determines values of casing and drill string variables and constants. These constants and variables are used to dynamically generate an estimate of casing wear, based on a stress theory. The drilling operation can be halted when the estimate of casing wear reaches a predetermined value.

SURFACE COIL FOR WELLBORE POSITIONING

A system may include a surface coil positioned at a known surface position, the surface coil including at least one loop of a conductor. The system may also include a coil controller coupled to the surface coil and adapted to inject a current into the surface coil such that the surface coil generates an electromagnetic field. In addition, the system may include a sensor package positioned within a wellbore adapted to detect the electromagnetic field and determine the position of the wellbore relative to the surface coil.

Скважинный прибор для измерения параметров траектории ствола скважины в процессе бурения

Полезная модель относится к бурению нефтяных и газовых скважин и предназначена для контроля забойных параметров при бурении и геофизических исследованиях скважины.Скважинный прибор для измерения параметров траектории ствола скважины в процессе бурения подключен к турбогенератору через кабельную секцию, а также к скважинному прибору подключены датчик инклинометрический и модуль гамма-каротажа. Скважинный прибор включает в себя силовой модуль, управляемый микроконтроллером, который помимо управления силовым модулем принимает данные от датчика тока, датчика температуры, а также контролирует напряжение на нагрузке. Источник вторичного электропитания запитывается от слаботочной обмотки генератора, вырабатывает требуемое напряжение, которое подается на модуль управления питанием. Модуль управления питанием управляется микроконтроллером регистратора данных. Модуль управления питанием вырабатывает все необходимые напряжения питания для заряда аккумуляторов и питания модулей. Модуль регистратора данных получает информацию от инклинометрического модуля и модуля гамма-каротажа по стандартному CAN интерфейсу, хранит информацию во FLASH памяти. Для чтения информации из FLASH памяти применяется скоростной USB контроллер, который соединяется через USB коннектор с персональным компьютером.Полезная модель позволяет повысить надежность, ремонтопригодность, увеличить ресурс работы скважинного прибора. Применять модули инклинометрии и гамма-каротажа различных конструкций и производителей. Современные схемотехнические решения увеличивают надежность прибора. Возможность хранения значительного объема информации во внутренней FLASH памяти (по принципу «черного ящика») обеспечивает возможность анализа процессов, происходящих в скважинном приборе во время бурения. 1 ил. РОССИЙСКАЯ ФЕДЕРАЦИЯ (19) RU (11) (13) 172 009 U1 (51) МПК E21B 47/022 (2012.01) ФЕДЕРАЛЬНАЯ СЛУЖБА ПО ИНТЕЛЛЕКТУАЛЬНОЙ СОБСТВЕННОСТИ (12) ФОРМУЛА ПОЛЕЗНОЙ МОДЕЛИ К ПАТЕНТУ РОССИЙСКОЙ ФЕДЕРАЦИИ (21)(22) Заявка: 2016133653, 16 ...

System and method for direction drilling

A system and a method for directional drilling may generate a model of steering behavior which may be used to estimate a position and an orientation of the drill bit during directional drilling. The estimated position and the estimated orientation may be compared to the well plan to determine desired drilling behavior, and the desired drilling behavior may be used to determine a recommended toolface orientation and/or recommended intervals of sliding and rotating to conform the directional drilling to the well plan.

Apparatus and Method for Tool Face Control Using Pressure Data

A method, apparatus and computer-readable medium for drilling a wellbore is disclosed. A fluid is pumped to rotate a drilling assembly at an end of a drill string in the wellbore. A plurality of measurements of pressure of the fluid is obtained. A standard deviation of the mud pressure is estimated from the plurality of fluid pressure measurements, and a variation of a tool face angle of the drilling assembly to the pumped fluid is estimated from a comparison of the estimated standard deviation of pressure to a selected criterion. A drilling parameter can be altered to drill the wellbore based on the estimated variation of the tool face angle.

Electromagnetic depth/orientation detection tool and methods thereof

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

Drilling apparatus with shutter

The present disclosure relates to a drilling apparatus including a cutting unit defining at least one through-hole that provides fluid communication between a distal side and a proximal side of the cutting unit. The cutting unit includes a plurality of cutting elements at the distal side of the cutting unit. The cutting unit also includes a shutter for selectively opening and blocking the through-hole of the cutting unit.

Realtime dogleg severity prediction

A method for estimating an inclination and azimuth at a bottom of a borehole includes forming a last survey point including a last inclination and a last azimuth; receiving at a computing device bending moment and at least one of a bending toolface measurement and a near bit inclination measurement from one or more sensors in the borehole; and forming the estimate by comparing possible dogleg severity (DLS) values with the bending moment value.

Apparatus and Method for Determining the Direction East

In one aspect a method of determining direction east is provided that in one embodiment includes dropping objects under influence of gravity, determining locations where the objects drop, and determining the direction east from the locations where the objects drop.

Boring tool control using remote locator

A drilling system performs underground boring using a drill rig and a boring tool which is configured for moving through the ground under control of the drill rig to form an underground bore. A monitoring arrangement, forming part of the system, includes a detection arrangement at the drill rig for monitoring at least one operational parameter to produce a data signal relating to at least one of a utility to be installed in the underground bore, the drill rig and the boring tool. A portable device forms another part of the system for receiving the data signal relating to the operational parameter for use by the portable device. A communication arrangement, for example using telemetry, transfers the data signal from the drill rig to the portable device. The operational parameter may be monitored for the purpose of preventing equipment failure.

Directional drilling target steering apparatus and method

An apparatus and method are used in conjunction with a system for performing horizontal directional drilling, the system including a drill string extending from a drill rig to a boring tool such that the boring tool is steerable based on a roll orientation. The system also includes an arrangement for generating steering commands for guiding the boring tool to a target position. Responsive at least in part to the steering commands, a display is configured to selectively indicate each of a rotate command, a push command and a spin command. A steering indicator is described which indicates a current roll orientation of the boring tool. A 3-D grid can be animated and centered on either a steering or target indicator. Rounding of a steering command ratio can limit the display of target roll orientations to only those that a given boring tool transmitter is capable of sensing and indicating.

Horizontal directional drilling area network and methods

A drilling area network hub is located proximate to a drill rig and includes an uphole transceiver in bidirectional communication with a downhole transceiver by utilizing the drill string as an electrical conductor. Certain information is collected including rig-based and/or location information. At least one field report is generated based on the certain information to characterize at least one of an inground operation, an operational condition of the downhole transceiver, an operational condition of the uphole transceiver, and an operational condition of the drill rig. A drilling area network server receives the field report from the Internet at a remote location and can generate a custom report and/or recommended actions based on field data. Region specific parameters can be applied to the operation of a drilling system. The drilling area network hub can transfer data logs to the remote location according to assigned priorities.

APPARATUS AND METHOD FOR DRILLING A WELL

A system for drilling at least one well of interest proximate a reference well comprises at least one sensor in a drill string in the at least one well of interest to detect at least one parameter of interest related to a distance and a direction to the reference well. A controller is operatively coupled to the at least one sensor to determine the distance and the direction from the sensor to the reference well based at least in part on the at least one detected parameter of interest. A steerable assembly is operatively coupled to the controller to receive commands from the controller to adjust the path of the at least one well of interest being drilled based at least in part on the distance and direction from the sensor to the reference well. 1. A method for drilling at least one well of interest comprising:calculating a desired path for the at least one well of interest relative to at least one reference well;measuring a position of the at least one well of interest relative to the at least one reference well at at least one location along a wellbore of the at least one well of interest;calculating an actual path of the at least one well of interest based at least in part on the measured position of the at least one well of interest relative to the at least one reference well;comparing the actual path of the at least one well of interest to the desired path of the at least one well of interest; andadjusting a drilling system to modify the actual path of the at least one well of interest based at least in part on a deviation between the actual path of the at least one well of interest and the desired path of the at least one well of interest.2. The method of wherein measuring the position of the at least one well of interest relative to the at least one reference well at at least one location along the wellbore of the at least one well of interest comprises measuring the position using at least one measurement chosen from the group consisting of: an active magnetic ...

SYSTEM AND METHOD FOR KICKING-OFF A ROTARY STEERABLE

A method and system for steering a rotary steerable tool in a borehole. A method includes determining an azimuthal angle between a reference direction and a reference point on a direction determination component of a tool string. The direction control component is remote from the rotary steerable tool. The azimuthal angle and a time at which the angle was determined are communicated to a rotary steerable tool direction control system. A steerable shaft of the rotary steerable tool is deflected based on the azimuthal angle and the time at which the angle was determined, thereby directing the rotary steerable tool in a predetermined direction. 1. A method for steering a rotary steerable tool in a borehole , comprising:determining an azimuthal angle between a reference direction and a reference point on a direction determination component of a tool string;communicating the azimuthal angle and a time at which the angle was determined to a rotary steerable tool direction control system; anddeflecting a steerable shaft of the rotary steerable tool based on the azimuthal angle and the time at which the angle was determined, thereby directing a the rotary steerable tool in a predetermined direction;wherein the direction determination component is remote from the rotary steerable tool.2. The method of claim 1 , further comprising synchronizing a clock of the direction determination component and a clock of the direction control system.3. The method of claim 1 , further comprising storing periodically determined time-stamped rotary position information for the steerable shaft.4. The method of claim 1 , further comprising:identifying stored rotary position information corresponding to the time at which the azimuthal angle was determined; anddetermining the position of a rotation resistant housing surrounding the steerable shaft relative to the reference direction at the time at which the azimuthal angle was determined based on the information.5. The method of claim 1 , further ...

Systems and Methods for Locating Wellbore Servicing Tools Within a Wellbore

Disclosed are methods and systems for accurately locating wellbore servicing tools within a wellbore. A positioning system includes an elongate housing defining a piston bore with first and second axial ends, a sleeve arranged within the piston bore and having an upset extending radially outward therefrom, one or more lugs arranged within the elongate housing and radially movable when acted upon by the upset, a first biasing device arranged within the piston bore at the second axial end, and at least one RFID tag arranged on the production tubular and configured to communicate with at least one RFID reader arranged on the elongate housing, the at least one RFID reader being configured to deploy the first biasing device upon communicating with the at least one RFID tag, and thereby force the sleeve toward the first axial end and the upset into engagement with the lugs which engage a profile. 1. A positioning system for locating a wellbore servicing tool within a production tubular , comprising:an elongate housing defining a piston bore having a first axial end and a second axial end;a sleeve arranged within the piston bore and being axially translatable between the first and second axial ends, the sleeve having at least one upset extending radially outward therefrom;one or more lugs arranged within the elongate housing and being radially movable when acted upon by the at least one upset;a first biasing device arranged within the piston bore at the second axial end and movable between a stowed configuration and a deployed configuration; andat least one RFID tag arranged on the production tubular and configured to communicate with at least one RFID reader arranged on the elongate housing, the at least one RFID reader being configured to deploy the first biasing device upon communicating with the at least one RFID tag.2. The positioning system of claim 1 , wherein claim 1 , as the first biasing device expands axially claim 1 , it forces the sleeve toward the first axial ...

RESERVOIR RECOVERY SIMULATION PROCESS AND SYSTEM

A method and system for simulating reservoir recovery include taking into account inaccuracies in well spacing due to wellbore positional uncertainty. 1. A method of simulating reservoir recovery , comprising:with a processor, receiving a request including input parameters for a reservoir recovery simulation, the input parameters comprising a description of a reservoir, a description of planned wells, and one or more tool codes, each tool code corresponding to a survey tool error model;with the processor, developing a model of the reservoir from the input parameters;with the processor, computing an ideal recovery for the reservoir assuming the planned wells are drilled accurately in the reservoir model;with the processor, simulating an actual recovery for the reservoir a plurality of times for each tool code, each simulating comprising generating actual wellbore trajectories in the reservoir model taking into account wellbore positional uncertainty specified by the survey tool error model corresponding to the tool code and computing a simulated recovery from simulated wells having the actual wellbore trajectories;with the processor, computing a simulated recovery loss for each simulation from the difference between the simulated recovery computed during the simulation and the ideal recovery;with the processor, computing an average recovery loss for each tool code from the simulated recovery losses; andwith the processor, at least one of updating a display with the average recovery loss for each tool code and storing the average recovery loss for each tool code in a non-transitory computer readable medium.2. The method of claim 1 , further comprising claim 1 , with the processor claim 1 , computing expected wellbore crossovers for each simulation of the actual recovery.3. The method of claim 1 , further comprising claim 1 , with the processor claim 1 , computing expected wellbore collisions for each simulation of the actual recovery.4. The method of claim 1 , further ...

METHOD FOR MEASURING UNDERGROUND BORING POSITION AND UNDERGROUND BORING POSITION MEASURING APPARATUS

The rotation angle around x axis, inclination angle and directional angle of a boring bit are obtained from the value measured with an accelerometer () and a three axis magnetic sensor integrally provided within the boring bit attached to the top of a rod array for boring. From these obtained values and the length corresponding to a rod, the amount of varied position according to boring by a length corresponding to a rod is obtained for each directional component. Further, the position of boring corresponding to boring in plural times with successive addition of rods is obtained through accumulating the amount of varied position for each directional component in respect of boring in plural times. 1. A method for measuring underground boring position using a posture detecting sensor and a three axis magnetic sensor for measuring a terrestrial magnetism provided integrally within a boring bit disposed at the top of a rod array in measuring a position of boring at the time of underground boring using a boring system for non-open cut working method that is equipped with the rod array with the boring bit attached at the top thereof and performs underground boring with successive addition of rods , comprising steps of:establishing an xyz-coordinate system with z axis in the direction of gravity and x axis in the direction to the magnetic north and measuring the terrestrial magnetism on the ground with the three axis magnetic sensor to obtain a depression angle I of the terrestrial magnetism before boring,obtaining an inclination angle φ of the boring bit from a horizontal plane and a rotation angle ω of the boring bit around x axis from a value measured by an accelerometer integral with the boring bit at the time of boring,obtaining a directional angle θ of the boring bit from the obtained inclination angle φ and the rotation angle ω around x axis along with the measured value by the three axis magnetic sensor and the depression angle I of the terrestrial magnetism ...

APPARATUS AND METHODS FOR GEOSTEERING

Various embodiments include apparatus and methods to generate geosignal responses. Geosignal responses may be generated that include a representation of a determination of variation between a XX coupling component and a YY coupling component from acquired signals. Such geosignals may be used to 5 address a blindspot problem suffered in conventional geosteering in a drilling condition where the logging tool is located at layered formations with symmetric resistivity profiles. Additional apparatus, systems, and methods are disclosed. 1. A method comprising:acquiring signals generated from operating a tool in a borehole;processing the acquired signals in a processing unit;generating a geo signal including a representation of a determination of variation between a XX coupling component and a YY coupling component; anddirecting a drilling-related operation using the geo signal.2. The method of claim 1 , wherein processing the acquired signals includes decoupling coupling components from the acquired signals and using the decoupled coupling components to generate the geo signal.3. The method of claim 1 , wherein acquiring signals generated from operating the tool includes using a tool having an arrangement of one or more transmitting sensors tilted substantially with respect to a longitudinal axis of the tool and one or more receiving sensors tilted substantially with respect to the longitudinal axis such that the acquired signals provide decoupled coupling components.4. The method of claim 1 , wherein generating the geo signal includes basing the geo signal on a difference between XX and YY coupling component claim 1 , a ratio between XX and YY coupling component claim 1 , or a square root of XX and YY coupling components.5. The method of claim 1 , wherein generating the geo signal includes basing the geo signal on a combination of coupling components related to (XX−YY)/(XX+YY+2ZZ) claim 1 , (XX−YY)/(XX+YY−2ZZ) claim 1 , XX/ZZ and YY/ZZ claim 1 , (XX−YY)/ZZ and (XX+YY)/ ...

Automatic Wellbore Survey Evaluation

A method for automatically evaluating a survey of a subterranean wellbore includes receiving downhole navigation sensor measurements and automatically evaluating surface sensor data obtained at substantially the same time as the navigation sensor measurements to determine whether or not the navigation sensor measurements were obtained during satisfactory wellbore survey conditions. The navigation sensor measurements are evaluated to determine whether or not they meet certain predetermined conditions necessary for obtaining a satisfactory survey. A survey recommendation is automatically generating based on the automatic evaluations performed. 1. A method for surveying a subterranean wellbore , the method comprising:(a) deploying a drill string in the subterranean wellbore, the drill string including one or more navigation sensor sets;(b) performing survey preparation operations to promote satisfactory wellbore survey conditions based upon a position of the drill string within the wellbore and specific requirements of the navigation sensor sets for taking and communicating a survey;(c) causing the downhole navigation sensor sets to obtain navigation sensor measurements;(d) automatically evaluating surface sensor measurements obtained at substantially the same time as the navigation sensor measurements to determine whether or not the navigation sensor measurements were obtained during satisfactory wellbore survey conditions;(e) automatically evaluating the navigation sensor measurements to determine whether or not the navigation sensor measurements meet certain predetermined conditions necessary for obtaining a satisfactory survey; and(f) automatically generating a survey recommendation based on said automatic evaluations performed in (d) and (e).2. The method of claim 1 , wherein the survey preparation operations comprise (i) lifting the drill string such that the drill bit is off bottom and (ii) holding the drill string rotationally stationary with respect to the ...

Multi-Directionally Rotating Downhole Drilling Assembly and Method

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

SYSTEM AND METHOD FOR IMPROVING ROTATING SURVEY ACCURACY

The disclosed embodiments include a rotating survey tool. The rotating survey tool includes a first sensor array that in operation collects a first set of survey measurements during a downhole drilling operation. Additionally, the rotating survey tool includes a second sensor array directly coupled to the first sensor array that in operation collects a second set of survey measurements while a drill bit drills during the downhole drilling operation. Further, the second set of survey measurements has a greater base accuracy than the first set of survey measurements. 1. A rotating survey tool , comprising:a first sensor array configured to collect a first set of survey measurements during a downhole drilling operation; anda second sensor array directly coupled to the first sensor array and configured to collect a second set of survey measurements while a drill bit drills during the downhole drilling operation, wherein the second set of survey measurements has a greater base accuracy than the first set of survey measurements.2. The rotating survey tool of claim 1 , comprising a steering system communicatively coupled to the first sensor array and the second sensor array claim 1 , wherein the steering system is configured to receive the first set of survey measurements and the second set of survey measurements and to steer the drill bit based on the first set of survey measurements and the second set of survey measurements.3. The rotating survey tool of claim 2 , wherein the steering system is configured to calibrate the first sensor array based on the second set of survey measurements claim 2 , and to steer the drill bit based on the first set of survey measurements after the first sensor array is calibrated.4. The rotating survey tool of claim 1 , wherein the first sensor array and the second sensor array each comprise an accelerometer claim 1 , a magnetometer claim 1 , a gyroscope claim 1 , or any combination thereof.5. The rotating survey tool of claim 1 , wherein ...

Downhole Rate of Penetration Measurement

A method for determining a rate of penetration of a drill bit during an earth drilling operation may comprise first urging an element to extend out from a working face of the drill bit. As drilling progresses, this extended element may then be forced back into the drill bit by an internal surface of a borehole being formed. A rate at which the element retracts back into the working face may be measured to aid in estimating a rate of penetration of the drill bit into the earth. 1. A method for determining a rate of penetration of a downhole drilling operation , comprising:urging an element to extend from a working face of a drill bit; andmeasuring a rate of retraction of the element into the working face due to force from an internal surface of a borehole.2. The method of claim 1 , further comprising repeatedly alternating between urging and measuring.3. The method of claim 2 , wherein urging the element to extend is performed once a specific retraction displacement is reached.4. The method of claim 2 , wherein urging the element to extend is performed at intervals selected to increase a rate of penetration of the drill bit.5. The method of claim 2 , further comprising detecting variation in a maximum extension of the element.6. The method of claim 2 , further comprising:altering a force urging the element to extend;comparing the measured rate of retraction during application of different urging forces; andprojecting the compared measured rates to a point of zero rate to estimate a weight on bit.7. The method of claim 1 , wherein urging the element to extend displaces a portion of the internal surface.8. The method of claim 7 , wherein displacing the portion of the internal surface increases a rate of penetration of the drill bit.9. The method of claim 7 , wherein displacing the portion of the internal surface comprises crushing the portion.10. The method of claim 1 , wherein the internal surface of the borehole comprises a terminus of the borehole.11. The method of ...

ADVANCED PASSIVE INTERFERENCE MANAGEMENT IN DIRECTIONAL DRILLING SYSTEM, APPARATUS AND METHODS

A transmitter for inground use controls a depth signal transmit power in relation to a data signal transmit power such that one reception range of the depth signal at least approximately matches another, different reception range of the data signal. A portable device can form a system with the transmitter in which the portable device scans a plurality of frequencies within at least one low frequency depth signal range to measure the electromagnetic noise at each one of the plurality of frequencies and identify at least one of the frequencies as a potential depth frequency for the transmitter. The portable device can include a dual mode filter having a rebar mode and a normal mode filter. The depth signal frequency is dynamically positionable in relation to low frequency noise. 1. A transmitter for use in conjunction with a horizontal directional drilling system that includes a drill string that extends from a drill rig to an inground tool which supports the transmitter such that extension and retraction of the drill string moves the inground tool through the ground during an inground operation , said transmitter comprising:an antenna;one or more sensors for generating sensor data;an antenna driver for electrically driving said antenna to emit a depth signal responsive to a depth drive input for aboveground reception for use in determining a depth of the inground tool and for electrically driving the antenna responsive to a data drive input to emit at least one data signal characterizing the sensor data using at least one data signal frequency, that is higher in frequency than the depth signal, for aboveground recovery of the sensor data; anda processor configured for generating the depth drive input at the depth signal frequency and for generating the data drive input, characterizing the sensor data, in a way that controls a depth signal transmit power in relation to a data signal transmit power such that one reception range of the depth signal at least ...

Horizontal Directional Drilling Tool

An apparatus () for determining an azimuth of a drilling tool () during drilling of a borehole. The apparatus () comprises a rate sensor () configured to collect rate sensor data indicative of a component of a rate of rotation of the earth for determining the azimuth by gyrocompassing. The rate sensor () is further configured for communication with a surface unit (). The apparatus () also comprises a drill pipe extension detector () configured to detect a process associated with extension of a drill pipe () connecting the drilling tool () to the surface unit (). The rate sensor () is configured to transmit collected rate sensor data to the surface unit () based on the detected process associated with extension of the drill pipe (). 1. An apparatus for determining an azimuth of a drilling tool during drilling of a borehole , and comprising:a rate sensor configured to collect rate sensor data indicative of a component of a rate of rotation of the earth for determining the azimuth by gyrocompassing, and further configured for communication with a surface unit; anda drill pipe extension detector configured to detect a process associated with extension of a drill pipe connecting the drilling tool to the surface unit,wherein the rate sensor is configured to transmit collected rate sensor data to the surface unit based on the detected process associated with extension of the drill pipe.2.3. An apparatus according to claim 1 , wherein the drill pipe extension detector is configured to detect initiation of the process associated with extension of the drill pipe and control the rate sensor to commence collection of the rate sensor data.4. An apparatus according to any claim 1 , wherein the drill pipe extension detector is configured to determine that the apparatus is stationary during the process associated with the extension of the drill pipe.5. An apparatus according to claim 1 , wherein the process associated with extension of the drill pipe comprises one or more of: a ...

Surface Ranging Technique with a Surface Detector

A system for electromagnetic wellbore surface ranging to determine the location of a second wellbore relative to a first wellbore utilizing i) a current source configured to directly inject electrical current into a conductive member disposed in each wellbore and ii) an electromagnetic senor positioned on the surface of a formation, the sensor configured to measure electromagnetic fields at the formation surface emanating from the conductive member within each wellbore. 1. An electromagnetic (EM) wellbore surface ranging system comprising:a first wellbore extending from the surface of a formation, the first wellbore having a first elongated conductive member disposed therein;an EM sensor disposed on the surface of the formation;a current injection system in direct electrical contact with the elongated conductive member; anda location system configured to identify a surface location of the EM sensor.2. The system of claim 1 , further comprising:a second wellbore extending from the surface of a formation, the second wellbore having a second elongated conductive member disposed therein; anda current injection system in direct electrical contact with the second conductive member.3. The system of claim 2 , wherein the current injection system in direct electrical contact with the first conductive member is the same current injection system in direct electrical contact with the second conductive member.4. The system of any one of claim 2 , or claim 2 , wherein a location system comprises a GPS.5. The system of any one of claim 2 , or claim 2 , wherein the EM sensor comprises a magnetometer.6. 4. The system of any one of claim 2 , or claim 2 , wherein the EM sensor comprises two spaced apart magnetometers.7. The system of any one of claim 2 , or claim 2 , wherein the EM sensor comprises a magnetic gradiometer.8. The system of any one of claim 2 , or claim 2 , further comprising a wellhead installation claim 2 , wherein the current injection system is in electrical contact ...

Pulsed-Electric Drilling Systems and Methods with Formation Evaluation and/or Bit Position Tracking

Pulsed-electric drilling systems can be augmented with multi-component electromagnetic field sensors on the drillstring, at the earth's surface, or in existing boreholes in the vicinity of the planned drilling path. The sensors detect electrical fields and/or magnetic fields caused by the electrical pulses and derive therefrom information of interest including, e.g., spark size and orientation, bit position, at-bit resistivity and permittivity, and tomographically mapped formation strictures. The at-bit resistivity measurements can be for anisotropic or isotropic formations, and in the former case, can include vertical and horizontal resistivities and an orientation of the anisotropy axis. The sensors can illustratively include toroids, electrode arrays, tilted coil antennas, magnetic dipole antennas aligned with the tool axes, and magnetometers. The use of multiple such sensors increases measurement accuracy and the number of unknown model parameters which can be derived using an iterative inversion technique. 1. A pulsed-electric drilling system that comprises:drillstring terminated by a bit that extends a borehole through a formation ahead of the bit by passing pulses of electrical current into the formation;one or more multi-component electromagnetic field sensors positioned on the drillstring to measure fields caused by said pulses; anda processor that receives measurements representative of said fields and derives, based at least in part on said measurements, at least one electrical property of the formation;wherein the at least one electrical property includes anisotropy.2. The system of claim 1 , wherein the at least one electrical property includes resistivity.3. The system of claim 1 , wherein the at least one electrical property includes an isotropic formation resistivity claim 1 , and wherein as part of deriving said resistivity claim 1 , the processor determines a magnitude of the electromagnetic field at each of said one or more multi-component ...

Communication protocol in directional drilling system, apparatus and method utilizing multi-bit data symbol transmission

A system includes a transmitter for use in conjunction with a horizontal directional drilling system that transmits a multi-bit symbol stream that characterizes sensor symbols for receipt by an aboveground portable device. The portable device receives the symbol stream for aboveground recovery of the sensor signals. The transmitter can precisely place the symbol frequencies at least to avoid a noise environment, as well as to avoid powerline harmonics, and can utilize wave shaping for transmitted symbols at least to provide for transmission power control, spectral content control and wideband antenna matching. The receiver can measure the noise environment to identify the symbol frequencies used by the transmitter. The noise can be scanned at an incremental resolution across a wide frequency bandwidth for display or automatic symbol frequency selection.

METHOD FOR NEAR REAL TIME SURFACE LOGGING OF A GEOTHERMAL WELL, A HYDROCARBON WELL, OR A TESTING WELL USING A MASS SPECTROMETER

A method for providing geological trends and real time mapping of a geological basin by forming a geochemical surface well log. The method provides in real time, information from a mass spectrometer on fluid samples from a wellbore, into a geochemical well log template using computer instructions to create a plurality of graphical tracks. The dataset includes geochemical, engineering, and geological information. The geochemical surface well log is transmitted to and viewable on a client device. The geochemical surface well log provides information on well fluids and rock. The mass spectrometer receives fluid samples and performs analysis on the fluid samples, and then communicates fluid testing data in real time to a geochemical surface well log with a plurality of graphical tracks which is then further communicated to a client device via a network. 1. An automatic method for creating a geochemical surface well log for a wellbore in near real time for a geothermal well , a hydrocarbon well , or testing well , using a well fluid processor to collect analyzed data from fluid analyzers , form the geochemical surface well log , and communicate the geochemical surface well log to at least one client device using a network , the method comprising:a. electronically connecting a well fluid processor and well fluid data storage to a network: i. a mass spectrometer processor;', 'ii. a mass spectrometer data storage;', 'iii. computer instructions in the mass spectrometer data storage to measure a mass to charge ratio of molecular weights for components in fluid samples from the wellbore; and', 'iv. computer instructions in the mass spectrometer data storage to communicate the measured mass to charge ratios in fluid samples from the wellbore to the well fluid processor;, 'b. electronically connecting a mass spectrometer to the network and fluidly connecting the mass spectrometer to receive fluid samples from at least one of a total hydrocarbon analyzer and a wellbore, the mass ...

Advanced Inground Device Power Control and Associated Methods

A transmitter is powered by a regulated battery voltage and is installable in one of a plurality of different housings, each housing is characterized by a different design and each can form part of an inground tool for performing an inground operation in which a drill string extends from a drill rig to the inground tool. An antenna driver drives an antenna based on the regulated voltage to emanate an electromagnetic signal for remote reception. A controller limits power consumption from the regulated voltage so as not to exceed a power consumption threshold, irrespective of installation of the transmitter in any one of the housings when the transmitter would otherwise exhibit a different power consumption for each housing design. A corresponding method is described. Features relating to power consumption threshold modification based on temperature as well as mechanical shock and vibration are described. 1. A transmitter that is powered by a battery and the transmitter is receivable in a housing to form part of an inground tool for performing an inground operation in which a drill string extends from a drill rig to the inground tool , said transmitter comprising:a regulator for generating a regulated voltage from said battery;an antenna driver powered from the regulated voltage for electrically driving an antenna to emanate an electromagnetic signal for remote reception based on power consumption from the regulator;an accelerometer for generating accelerometer readings responsive to mechanical shock and vibration of the inground tool during the inground operation; anda controller that monitors the power consumption and selectively limits the power consumption based on at least one power consumption threshold while continuing to drive the antenna to emanate the electromagnetic signal and that changes the power consumption threshold based on the accelerometer readings.2. The transmitter of wherein the controller is configured to lower the power consumption threshold ...

BOUNDARY TRACKING CONTROL MODULE FOR ROTARY STEERABLE SYSTEMS

A rotary steerable bottom hole assembly includes a drill bit disposed at a distal end thereof, and azimuthal resistivity antennas and electronics configured to measure a distance to a formation boundary. 1. A rotary steerable bottom hole assembly comprising:a drill bit disposed at a distal end thereof;azimuthal resistivity antennas and electronics configured to measure a distance to a formation boundary, the azimuthal resistivity antennas comprising:an axial antenna including a wire winding for generating an axial magnetic moment parallel with the longitudinal axis;a transverse antenna including an antenna body having a longer axis disposed longitudinally in the housing, and a wire coil having a central axis disposed around the antenna body, wherein the wire coil central axis is substantially perpendicular to the longer axis of the antenna body, and wherein the wire coil is configured to generate a transverse magnetic moment orthogonal to the housing longitudinal axis.2. The rotary steerable bottom hole assembly of claim 1 , further comprising a stabilizer disposed in the bottom hole assembly uphole from the drill bit.3. The rotary steerable bottom hole assembly of claim 2 , further comprising a steerable housing having a longitudinal axis and disposed between the stabilizer and the drill bit claim 2 , wherein the azimuthal resistivity antennas and electronics are in the housing.4. The rotary steerable bottom hole assembly of claim 3 , further comprising a control module in the housing configured to steer the drill bit along a well path and claim 3 , based on measurements from the azimuthal resistivity antennas claim 3 , to steer the housing and maintain a distance between the housing and the formation boundary.5. The rotary steerable bottom hole assembly of claim 4 , wherein the housing further encloses a hydraulic pump and pump drive for operating one or more rams to steer the drill bit.6. The rotary steerable bottom hole assembly of claim 4 , wherein the control ...

PHASE ESTIMATION FROM ROTATING SENSORS TO GET A TOOLFACE

Methods may include conveying a BHA comprising magnetic material in the borehole to a first borehole depth; using a magnetic sensor disposed on the BHA to produce a first magnetic measurement of a component of a magnetic field at the first borehole depth, the magnetic field including an axial component of the magnetic field oriented along a longitudinal axis of the BHA and a plurality of non-axial components unaligned with the axial component, wherein the magnetic field is affected by the magnetic material and wherein the first magnetic measurement is representative of at least one non-axial component of the plurality; estimating the axial component at the first borehole depth in dependence upon the first magnetic measurement; estimating an azimuth of the BHA at the first borehole depth using the axial component; and controlling drilling operations with the BHA in in dependence upon the azimuth. 120.-. (canceled)21. A method of estimating an azimuth of at least a part of a bottomhole assembly (BHA) in a borehole intersecting an earth formation , the BHA comprising magnetic material , the method comprising:conveying the BHA comprising the magnetic material into the borehole;using a first sensor disposed on the BHA to produce a first measurement of a component of a magnetic field at a first borehole depth, the magnetic field including an axial component of the magnetic field oriented along a longitudinal axis of the BHA and a plurality of non-axial components of the magnetic field unaligned with the axial component, wherein the magnetic field is affected by the magnetic material and wherein the first measurement is representative of at least one non-axial component of the plurality;estimating the axial component at the first borehole depth in dependence upon the first measurement;estimating an azimuth of at least a part of the BHA at the first borehole depth using the axial component; andcontrolling drilling operations with the BHA in dependence upon the azimuth.22. ...

ROTARY STEERABLE SYSTEM WITH ROLLING HOUSING

A directional drilling device for drilling a wellbore having a wall, the device including an outer housing, a driveshaft located at least partially within and selectively rotatable with respect to the outer housing. The device also includes extendable members oveable to extend radially outwardly from the outer housing and so as to apply a force onto the wellbore wall and move the device off-center in the wellbore in a direction. The device further includes a hydraulic actuation system operable to control hydraulic fluid to extend and retract of the extendable members. The rotational orientation of the extendable members is controllable by rotation of the outer housing by the driveshaft and the rotational orientation of the extendable members and the outer housing and thus the direction may be maintained by extension of the extendable members into contact with the borehole to restrain the outer housing from rotating. 1. A directional drilling device for drilling a wellbore having a wall , comprising: an outer housing , a driveshaft located at least partially within and selectively rotatable with respect to the outer housing , extendable members moveable to extend radially outwardly from the outer housing and so as to apply a force onto the wellbore wall and move the device off-center in the wellbore in a direction , a hydraulic actuation system operable to control hydraulic fluid to extend and retract of the extendable members , wherein the rotational orientation of the extendable members is controllable by rotation of the outer housing by the driveshaft , and wherein the rotational orientation of the extendable members and the outer housing and thus the direction may be maintained by extension of the extendable members into contact with the borehole to restrain the outer housing from rotating.2. The device of claim 1 , wherein the extendable members are extendable in unison.3. The device of claim 1 , wherein the extendable member is extendable radially outwardly ...

AUTOMATED DRILLING METHODS AND SYSTEMS USING REAL-TIME ANALYSIS OF DRILL STRING DYNAMICS

Methods and apparatus for identifying downhole dynamics in a drilling system are provided. Acceleration-detecting sensors are mounted at multiple locations near to a drill bit, such as at a drill collar. The sensors may be spaced 90° apart along a circumference of the drill collar. The sensors detect acceleration measurements in a plane orthogonal to the drill string's axis of rotation, with respect to a first reference frame that moves with the drill string. The acceleration measurements are received by a processor and processed to determine rotational and revolution positions of the drill string within the wellbore with respect to a static reference frame. Whirl dynamics may, in particular, be determined based on the results in real time. 161.-. (canceled)62. A drilling system comprising:a plurality of sensors mounted to a drill string at a plurality of sensor locations, the sensors configured to sense a plurality of acceleration measurements corresponding to a plurality of locations in a first two-dimensional reference frame, the first two-dimensional reference frame coincident with a plane orthogonal to a rotational axis of the drilling system and based on a position of the drilling system in the plane, the plurality of acceleration measurements comprising measurements in a plurality of non-parallel directions lying in the plane;a processor in communication with the plurality of sensors, the processor configured to:receive the plurality of acceleration measurements;determine a rotational position of the drilling system in the first two-dimensional reference frame based on the plurality of acceleration measurements, the rotational position describing rotation of the drilling system in the plane about the rotational axis;convert a first location of the plurality of locations to a corresponding second location of the drilling system in a second two-dimensional reference frame based on the plurality of acceleration measurements, the second two-dimensional reference ...

Automated drilling methods and systems using real-time analysis of drill string dynamics

Methods and apparatus for identifying downhole dynamics in a drilling system are provided. Acceleration-detecting sensors are mounted at multiple locations near to a drill bit, such as at a drill collar. The sensors may be spaced 90° apart along a circumference of the drill collar. The sensors detect acceleration measurements in a plane orthogonal to the drill string's axis of rotation, with respect to a first reference frame that moves with the drill string. The acceleration measurements are received by a processor and processed to determine rotational and revolution positions of the drill string within the wellbore with respect to a static reference frame. Whirl dynamics may, in particular, be determined based on the results in real time.

ADJUSTMENT MECHANISMS FOR ADJUSTABLE BENT HOUSINGS

Adjustable drill string housings are described for use in the directional drilling of wellbores, e.g. wellbores for hydrocarbon recovery wells. The adjustable drill string housings permit adjustment of a bend angle in the housings without removing the housings from a wellbore. In some exemplary embodiments, the bend angle can be adjusted by changing the internal stresses in a support member carried by the housings. In other embodiments, the bend angle may be adjusted by causing failure of sacrificial support members carried by the housings, and the failure may be caused by delivering chemicals through a chemical delivery system to the sacrificial support members. Methods of operating the adjustable drill string housings include multi-lateral drilling operations wherein the bend angle is adjusted when a casing window has been detected. 1. An adjustable drill string housing , comprising:an annular member having an upper end and a lower end, the annular member defining an upper longitudinal axis extending through the upper end and a lower longitudinal axis extending through the lower end, the annular member deformable about a bend axis between a first configuration wherein the upper and lower longitudinal axes are disposed at a first bend angle with respect to one another and a second configuration wherein the upper and lower longitudinal axes are disposed at a second bend angle with respect to one another; andan adjustment mechanism comprising at least one support member carried by the annular member radially offset from the upper and lower longitudinal axes and extending across the bend axis, the adjustment mechanism selectively movable between a first arrangement for maintaining the annular member in the first configuration and a second arrangement for maintaining the annular member in the second configuration, wherein the adjustment mechanism changes an real stress in the at least one support member to move between the first and second arrangements.2. The ...

DRILL POSITIONING SYSTEM UTILIZING DRILL OPERATION STATE

A method, system, and non-transitory computer-readable storage medium for estimating pose of a drill are disclosed. The method may include receiving a location signal from a locating device, receiving a first signal indicative of an angular rate of the drill, and receiving a second signal indicative of an acceleration of the drill. The method may further include determining an operation state of the drill. The method may further include determining the pose of the drill based on the received location signal, first signal, second signal, and the determined operation state of the drill.

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

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

CORE ORIENTATION SYSTEMS AND METHODS

Methods and systems for evaluating the subterranean formation of a wellbore are provided. In one embodiment, a geographical orientation of a downhole tool relative to Earth may be determined. The downhole tool may include a coring tool positioned to extract a core sample from a formation of the Earth. The orientation of the core sample with respect to the down hole tool also may be determined. Further, based on the geographical orientation of the downhole tool and the orientation of the coring sample, a geographical orientation of the core sample with respect to the Earth may be determined. 1. A method comprising:determining a geographical orientation of a downhole tool relative to Earth, wherein the downhole tool comprises a coring tool positioned to extract a core sample from a formation of the Earth;determining an orientation of the core sample with respect to the downhole tool; anddetermining, based on the geographical orientation of the downhole tool and the orientation of the coring sample, a geographical orientation of the core sample with respect to the Earth.2. The method of claim 1 , wherein determining a geographical orientation of a downhole tool comprises measuring a magnetic field position of the downhole tool and measuring a gravitational field position of the downhole tool.3. The method of claim 2 , wherein determining a geographical orientation comprises determining a depth of the downhole tool in a wellbore.4. The method of claim 1 , wherein determining a geographical orientation of a downhole tool comprises determining a three-dimensional geographical orientation.5. The method of claim 1 , wherein determining an orientation of the core sample comprises determining an angle of a coring bit of the coring tool.6. The method of claim 1 , wherein determining an orientation of the core sample comprises determining a rotational position of the core sample in the formation based on a mark disposed on the core sample by the coring tool.7. The method of ...

APPARATUS AND METHODS FOR UNINTERRUPTED DRILLING

In at least one embodiment, a control system may include a processor coupled to the database. The control system may include a memory accessible to the processor and storing instructions executable by the processor for: during slide drilling, detecting an increase to a first differential pressure (ΔP) that is greater than a first threshold pressure. In at least one embodiment, the control system may responsive to detecting the first ΔP, determining a time duration for which the first ΔP exceeds the first threshold pressure. In at least one embodiment, the control system may responsive to the first ΔP exceeding the first threshold pressure for less than a first threshold time, continuing the slide drilling without modifying a drilling parameter. 1. A control system for controlling a drilling operation , the control system comprising:a database comprising a plurality of data relating to a plurality of drilling parameters, wherein the database is updated during drilling of a borehole;a processor coupled to the database; during slide drilling, detecting an increase to a first differential pressure (ΔP) that is greater than a first threshold pressure;', 'responsive to detecting the first ΔP, determining a time duration for which the first ΔP exceeds the first threshold pressure; and', 'responsive to the first ΔP exceeding the first threshold pressure for less than a first threshold time, continuing the slide drilling without modifying a drilling parameter., 'a memory accessible to the processor and storing instructions executable by the processor for2. The control system of claim 1 , wherein the instructions further comprise:determining if the first ΔP exceeds a second threshold pressure; andresponsive to the first ΔP exceeding the second threshold pressure, generating an output indicating that a control action should be performed.3. The control system of claim 1 , wherein the plurality of drilling parameters comprise at least one of: weight on bit claim 1 , rate of ...

Surface steerable drilling system for use with rotary steerable system

A method for rotary steerable drilling, comprising calculating a first plurality of convergence plans if an estimated position of a drill bit is not within a defined margin of error of a desired point along a planned path for a borehole, calculating a second plurality of convergence plans if the estimated position of the drill bit is not within the margin of error, selecting a convergence plan that best satisfies a set of target parameters from the first and second plurality of convergence plans, producing a set of control parameters representing the selected convergence plan, transmitting one or more commands to one or more rotary steering components to actuate the one or more rotary steering components, in order to alter the planned path for the borehole in accordance with the set of control parameters, and drilling at least a portion of the borehole based on the set of control parameters.

Underground Guidance Using Above-Ground Mesh Network

A tracking system for communicating a location of a beacon in order to drill a bore path. The beacon is carried by a drill string in a drilling operation. Above-ground trackers are arranged in a path to define an intended underground bore path. The trackers form a multi-node mesh network in communication with a display unit at a drilling rig. A drilling operator guides the drill string in response to tracking data sent from the tracking system. 1. A system , comprising:a movable underground magnetic dipole source; and at least two ground-contacting portable trackers, each tracker forming a node of the mesh network; and', 'a display unit in communication with the above-ground tracking system., 'an above-ground tracking system formed as a multi-node mesh network in communication with the magnetic dipole source, comprising2. The system of in which each tracker within the mesh network is configured to receive dipole tracking data from the dipole source and from adjacent trackers within the mesh network claim 1 , and to relay dipole tracking data to an adjacent node within the mesh network.3. The system of in which each tracker within the mesh network is configured to store calibration data characteristic of that tracker claim 1 , and to receive and store calibration data originating from another tracker within the mesh network.4. The system of in which the mesh network comprises:at least one client node that communicates only with adjacent nodes; andone and only one server node that communicates with adjacent client nodes and with the display unit.5. The system of in which the mesh network includes a plurality of client nodes.6. The system of in which the tracking system is configured to select a single tracker for active status claim 1 , and in which dipole tracking data relayed between nodes of the mesh network is limited to that originating from the tracker then in active status.7. The system of in which the tracking system is configured to select a different tracker ...

Tracker With Electronic Compass And Method Of Use

An underground signal transmitter is located near a drill bit on a downhole tool. An above-ground tracker determines the relative orientations of the transmitter and tracker. The tracker also has a compass for determining the tracker's orientation relative to magnetic north. A central processing unit within the tracker uses compass and relative orientation data to calculate the orientation of the transmitter relative to magnetic north. This information can be used to map the bore path and make course corrections. 1. A tracker comprising:a portable housinga tri-axial antenna situated within the housing and configured to detect the magnetic field of a dipole source;a compass situated within the housing; anda processor situated within the housing and configured to receive signals from the antenna and the compass and to calculate the orientation for the underground transmitter relative to magnetic north.2. The tracker of further comprising an accelerometer.3. A horizontal directional drilling system comprising:a horizontal directional drill;a drill string having a horizontal directional drill at a first end and a downhole tool at a second end;{'claim-ref': {'@idref': 'CLM-00001', 'claim 1'}, 'an underground transmitter located proximate the downhole tool, wherein the underground transmitter emits a dipole magnetic field detectable by the tracker of ; and'}{'claim-ref': {'@idref': 'CLM-00001', 'claim 1'}, 'the tracker of .'}4. The horizontal directional drilling system of wherein the processor logs the orientation of the underground transmitter relative to magnetic north.5. The horizontal directional drilling system of wherein the processor maps the orientation and position of the transmitter.6. The horizontal directional drilling system of wherein the processor transmits a corrective steering signal to the horizontal directional drill in response to the orientation of the underground transmitter.7. The tracker of wherein the compass comprises a microelectromechanical ...

EXTENDABLE ORIENTING TOOL FOR USE IN WELLS

An orienting tool for use in wells can include a flow control device which controls flow between an interior and an exterior of a body of the tool to thereby transmit a signal indicative of an orientation of the body, the flow control device being outwardly extendable relative to the body. A method of orienting a structure in a well can include transmitting at least one signal from an orienting tool, the signal being indicative of an orientation of the orienting tool, and displacing a housing of the tool outward relative to a generally tubular body of the tool. A well system can include an orienting tool connected to a structure and positioned in a wellbore, the tool including a housing which is outwardly extendable relative to a generally tubular body, the tool being configured to transmit at least one signal indicative of an orientation of the structure. 1. A well system , comprising:an orienting tool connected to a structure and positioned in a wellbore, the orienting tool including a housing which is outwardly extendable relative to a generally tubular body, the orienting tool being configured to transmit at least one signal indicative of an orientation of the structure.2. The well system of claim 1 , wherein the orienting tool further includes a flow control device which controls flow between an interior and an exterior of the body to thereby transmit the signal.3. The well system of claim 2 , wherein the flow control device is contained in the housing.4. The well system of claim 1 , wherein outward extension of the housing increases an interior dimension in the body.5. The well system of claim 1 , wherein the housing extends outwardly in response to a biasing force applied by an object which displaces in the body.6. The well system of claim 1 , wherein the housing extends outwardly in response to application of a predetermined pressure to an interior of the body.7. The well system of claim 1 , wherein the housing extends outwardly in response to application of ...

Determining Directional Data for Device within Wellbore using Contact Points

A system and method for providing information regarding the tortuosity of a wellbore path is provided. The method includes receiving data from a plurality of survey stations of a wellbore survey. The method further includes determining a plurality of tortuosity parameter values for the wellbore path within a corresponding plurality of analysis windows, wherein each analysis window has at least one tortuosity parameter value.

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

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

Dynamic Calibration of Axial Accelerometers and Magnetometers

A method to perform a drilling operation. The method includes calibrating an axial survey sensor of a bottom hole assembly (BHA) by obtaining, from the axial survey sensor, a data log as a first function of azimuthal angle within a borehole, generating, by a computer processor of the BHA and using a pre-determined algorithm, a fitted curve as a second function of the azimuthal angle, wherein the fitted curve is generated based on the data log to represent a calibration error of the axial survey sensor, and extracting, by the computer processor of the BHA, a calibration parameter from the fitted curve. Accordingly, the drilling operation is performed using at least the axial survey sensor based on the calibration parameter. 1. A method to perform a drilling operation , comprising: obtaining, from the axial survey sensor, a data log as a first function of azimuthal angle within a borehole,', 'generating, by a computer processor of the BHA and using a pre-determined algorithm, a fitted curve as a second function of the azimuthal angle, wherein the fitted curve is generated based on the data log to represent a calibration error of the axial survey sensor, and', 'extracting, by the computer processor of the BHA, a calibration parameter from the fitted curve; and, 'calibrating an axial survey sensor of a bottom hole assembly (BHA) byperforming the drilling operation using at least the axial survey sensor based on the calibration parameter.2. The method of claim 1 , further comprising:rotating a drill string within the borehole,wherein the calibrating is performed when the axial survey sensor is at least one selected from a group consisting of rotating with the drill string and rotating independent of the drill string.3. The method of claim 1 , further comprising:stopping rotation of a drill string within the borehole,wherein the calibrating is performed when the axial survey sensor is at least one selected from a group consisting of not rotating and rotating independent ...

CROSS-PLOT ENGINEERING SYSTEM AND METHOD

In one embodiment, a method includes facilitating a real-time cross-plot display of drilling-performance data for a current well. The real-time cross-plot display includes a plurality of data plots represented on a common graph such that each data plot specifying at least two drilling parameters. Each data plot includes a plurality of data points such that each data point is expressible as Cartesian coordinates in terms of the at least two drilling parameters. The method further includes receiving new channel data for the current well from a wellsite computer system. In addition, the method includes creating, from the new channel data, new data points for the plurality of data plots as the new channel data is received. Moreover, the method includes updating the plurality of data plots with the new data points as the new data points are created. 1. A method comprising:on a central computing system comprising at least one server computer, facilitating a real-time cross-plot display of drilling-performance data for a current well;wherein the real-time cross-plot display comprises a plurality of data plots represented on a common graph, each data plot specifying at least two drilling parameters;wherein each data plot comprises a plurality of data points, each data point expressible as Cartesian coordinates in terms of the at least two drilling parameters;the central computing system receiving new channel data for the current well from a wellsite computer system;the central computing system creating, from the new channel data, new data points for the plurality of data plots as the new channel data is received; andthe central computing system updating the plurality of data plots with the new data points as the new data points are created.2. The method of claim 1 , wherein claim 1 , for each of the plurality of data plots claim 1 , the central computing system maps the at least two drilling parameters to data sources for the current well.3. The method of claim 1 , ...

Wellbore Survey Tool Using Coriolis Vibratory Gyroscopic Sensors

Various implementations described herein may refer to a wellbore survey tool using Coriolis vibratory gyroscopic sensors. In one implementation, a method may include receiving one or more reference values corresponding to the Earth's rotation rate and one or more reference values corresponding to a local latitude of a survey tool disposed in a wellbore. The method may also include receiving rotation rate measurements from one or more quartz Coriolis vibratory gyroscopic (CVG) sensors of the survey tool. The method may further include determining bias-corrected rotation rate measurements using one or more statistical estimation processes and based on the one or more reference values corresponding to the Earth's rotation rate, the one or more reference values corresponding to the local latitude, and the rotation rate measurements. The method may additionally include determining azimuth values of the survey tool based on the bias-corrected rotation rate measurements. 1. A method , comprising:receiving one or more reference values corresponding to the Earth's rotation rate and one or more reference values corresponding to a local latitude of a survey tool disposed in a wellbore;receiving a plurality of rotation rate measurements from one or more quartz Coriolis vibratory gyroscopic (CVG) sensors of the survey tool;determining a plurality of bias-corrected rotation rate measurements using one or more statistical estimation processes and based on the one or more reference values corresponding to the Earth's rotation rate, the one or more reference values corresponding to the local latitude, and the plurality of rotation rate measurements; anddetermining a plurality of azimuth values of the survey tool based on the plurality of bias-corrected rotation rate measurements.2. The method of claim 1 , wherein receiving the plurality of rotation rate measurements comprises receiving the plurality of rotation rate measurements about an x-axis claim 1 , a y-axis claim 1 , and a z- ...

Multi-Directionally Rotating Downhole Drilling Assembly and Method

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

SENSOR-ENABLED CUTTING ELEMENTS FOR EARTH-BORING TOOLS, EARTH-BORING TOOLS SO EQUIPPED, AND RELATED METHODS

Sensor-enabled cutting elements for an earth-boring drilling tool may comprise a substrate base, and a cutting tip at an end of the substrate base. The cutting tip may comprise a tapered surface extending from the substrate base and tapering to an apex of the cutting tip, and a sensor coupled with the cutting tip. The sensor may be configured to obtain data relating to at least one parameter related to at least one of a drilling condition, a wellbore condition, a formation condition, and a condition of the earth-boring drilling tool. The sensor-enabled cutting elements may be included on at least one of an earth-boring drill bit, a drilling tool, a bottom-hole assembly, and a drill string. 1. A sensor-enabled cutting element for an earth-boring drilling tool , the sensor-enabled cutting element comprising:a substrate base;a cutting tip at an end of the substrate base, the cutting tip comprising a tapered surface extending from the substrate base and tapering to an apex of the cutting tip centered about a longitudinal axis of the cutting tip; anda sensor embedded within the cutting tip and at least substantially entirely surrounded by the cutting tip, wherein the sensor is configured to obtain data relating to at least one parameter related to at least one of a drilling condition, a wellbore condition, a formation condition, and a condition of the earth-boring drilling tool.2. The sensor-enabled cutting element of claim 1 , wherein the at least one parameter includes at least one of temperature claim 1 , pressure claim 1 , strain claim 1 , stress claim 1 , and resistivity.3. The sensor-enabled cutting element of claim 1 , wherein the cutting tip includes a hard material selected from the group consisting of polycrystalline diamond claim 1 , diamond-like carbon claim 1 , and cubic boron nitride.4. The sensor-enabled cutting element of claim 1 , wherein the substrate base includes a tungsten-carbide material.5. The sensor-enabled cutting element of claim 1 , wherein ...

SYSTEM AND METHOD FOR REMOTELY CONTROLLED SURFACE STEERABLE DRILLING

A system and method for surface steerable drilling are provided. In one example, the system receives feedback information from a drilling rig and calculates an estimated position of a drill bit in a formation based on the feedback information. The system compares the estimated position to a desired position along a planned path of a borehole. The system calculates multiple solutions if the comparison indicates that the estimated position is outside a defined margin of error relative to the desired position. Each solution defines a path from the estimated position to the planned path. The system calculates a cost of each solution and selects one of the solutions based at least partly on the cost. The system produces control information representing the selected solution and outputs the control information for the drilling rig. 1. A method for identifying potential issues while drilling comprising:monitoring, by a surface steerable system located remotely at a location separate from a drilling rig, a plurality of operating parameters for drilling rig equipment that is part of the drilling rig and bottom hole assembly (BHA) equipment for a BHA coupled to the drilling rig and positioned in a borehole that is being drilled, wherein the operating parameters control the drilling rig equipment and BHA equipment;receiving, by the surface steerable system located remotely at the location separate from the drilling rig, a plurality of current inputs corresponding to performance data of the drilling rig equipment and BHA equipment during a drilling operation of the borehole;determining, by the surface steerable system located remotely at the location separate from the drilling rig, that an amount of change between any of the plurality of current inputs and a corresponding plurality of previously received inputs exceeds a defined threshold;determining, by the surface steerable system located remotely at the location separate from the drilling rig, whether a modification to the ...

ADJUSTABLE BENT HOUSINGS WITH MEASUREMENT MECHANISMS

Adjustable drill string housings are described for use in the directional drilling of wellbores, e.g. wellbores for hydrocarbon recovery wells. The adjustable drill string housings permit adjustment of a bend angle in the housings without removing the housings from a wellbore. In some exemplary embodiments, the bend angle can be adjusted by changing the internal stresses in a support member carried by the housings. In other embodiments, the bend angle may be adjusted by causing failure of sacrificial support members carried by the housings, and the failure may be caused by delivering chemicals through a chemical delivery system to the sacrificial support members. Methods of operating the adjustable drill string housings include multi-lateral drilling operations wherein the bend angle is adjusted when a casing window has been detected. 1. An adjustable drill string housing , comprising:an annular member having an upper end and a lower end, the annular member defining an upper longitudinal axis extending through the upper end and a lower longitudinal axis extending through the lower end, wherein a bend angle is defined between the upper and lower longitudinal axes;an adjustment mechanism operable to deform the annular member between a first operational configuration wherein the bend angle defines a first bend angle and a second operational configuration wherein the bend angle defines a second bend angle different from the first bend angle; anda measurement mechanism for determining the bend angle of the annular member, the measurement mechanism comprising a feedback device supported between the upper and lower ends of the annular member, the feedback device operable to measure a characteristic of the annular member and to provide a signal from which the bend angle is determinable.2. The adjustable drill string housing of claim 1 , wherein the feedback device is supported between upper and lower flanges extending from the annular member claim 1 , and wherein the ...

ROTARY STEERABE TOOL WITH PROPORTIONAL CONTROL VALVE

A rotary steering tool includes a steering member configured to move between a retracted configuration and an extended configuration. The rotary steering tool also includes a pump configured to pump a fluid, a power source independent of the downhole motor, the power source configured to power the pump, and a piston in fluid communication with the pump. The piston is configured to apply a force to the steering member to move the steering member from the retracted configuration to the extended configuration when the pump pumps the fluid at an operating system pressure. The rotary steering tool includes a controller to operate the pump at a range of operating system pressures, and a variable pressure control valve. The variable pressure control valve adjusts the operating system pressure between the range of operating system pressures to adjust the force applied to the steering member. 1. A rotary steering tool configured to control directional orientation of a drill bit along a drill string drilling into an earthen formation , the rotary steering tool comprising:a steering member configured to move between a retracted configuration and an extended configuration;a pump configured to pump a fluid;a piston in fluid communication with the pump, the piston being configured to apply a variable force to the steering member to manipulate the steering member between the retracted configuration and the extended configuration;a variable pressure control valve in fluid communication with the pump; anda controller configured to operate the variable pressure control valve to adjust an operating system pressure between a range of operating system pressures in order to adjust the force applied to the steering member by the piston.2. The rotary steering tool of claim 1 , further comprising a power source independent of the downhole motor claim 1 , the power source configured to power the pump.3. The rotary steering tool of claim 1 , wherein the range of operating system pressures ...

METHOD AND APPARATUS FOR TRANSITIONING BETWEEN ROTARY DRILLING AND SLIDE DRILLING WHILE MAINTAINING A BIT OF A BOTTOM HOLE ASSEMBLY ON A WELLBORE BOTTOM

A method of transitioning from rotary to slide drilling while maintaining a bit of a bottom hole assembly (“BHA”) on a wellbore bottom includes (a) recording a first toolface value of the BHA that is coupled to a drill string; (b) identifying a correlation between the first toolface value and a first quill position of a quill coupled to the drill string; (c) identifying a breakover torque for the drill string; (d) performing rotary drilling; (e) recording a second toolface value while the bit remains on the wellbore bottom; (f) receiving, while the bit remains on the wellbore bottom, a target toolface value; (g) calculating, while the bit remains on the wellbore bottom, an unwind amount to unwind the drill string; and (h) unwinding the drill string by the unwind amount to bring the second toolface value closer to the target toolface value while the bit remains on the bottom. 1. A method of transitioning from rotary drilling to slide drilling while maintaining a bit of a bottom hole assembly on a wellbore bottom , wherein the method comprises:(a) recording a first measured toolface value of the bottom hole assembly, wherein the bottom hole assembly is coupled to a drill string;(b) identifying a correlation between the first measured toolface value and a first quill position of a quill coupled to the drill string;(c) identifying a breakover torque for the drill string;(d) performing rotary drilling;(e) recording a second measured toolface value while the bit remains on the wellbore bottom;(f) receiving, while the bit remains on the wellbore bottom, a target toolface value;(g) calculating, while the bit remains on the wellbore bottom, an unwind amount to unwind the drill string; and(h) unwinding the drill string by the unwind amount to bring the second measured toolface value closer to the target toolface value while the bit remains on the wellbore bottom.2. The method of claim 1 ,wherein each of the second measured toolface value, the unwind amount, and the target ...

STEERABLE DRILLING BI-DIRECTIONAL COMMUNICATIONS SYSTEM AND METHODS

An apparatus and method of operating a drilling system with a directional guidance system and a drilling operation system is described. The directional guidance system and drilling operation system may engage in bi-directional communication during a slide drilling operation. This communication may be continual during the drilling operation. Parameters of the drilling instructions and the drilling operation system may be changed in response to these communications resulting in new instructions and changed slide drilling operations. 1. A method of operating a drilling system , comprising:inputting a drill plan into a directional guidance system of the drilling system, the drill plan comprising a slide drilling operation;sending a drilling instruction from the directional guidance system to a drilling execution system in communication with a BHA of the drilling system to conduct a slide drilling operation;conducting, with the drilling execution system, the slide drilling operation according to the drilling instruction;{'claim-text': ['sending a first signal from the drilling execution system to the directional guidance system comprising a parameter of the slide drilling operation;', 'assessing the first signal with the directional guidance system to determine whether the parameter is within an acceptable range;', 'if the parameter is not within the acceptable range, sending a second signal from the directional guidance system to the drilling execution system to change an aspect of the slide drilling operation; and', 'conducting, with the drilling execution system, the slide drilling operation according to the second signal before the slide drilling operation is completed.'], '#text': 'conducting bi-directional communication between the directional guidance system and the drilling execution system during the slide drilling operation, the bi-directional communication comprising:'}2. The method of claim 1 , wherein the parameter of the slide drilling operation is one of a ...

Multimode steering and homing system, method and apparatus

A boring tool is movable through the ground. A transmitter supported by the boring tool transmits an electromagnetic homing signal. A portable device monitors the electromagnetic homing signal and receives the electromagnetic homing signal in a homing mode for guiding the boring tool to a target position. A processor generates steering commands for guiding the boring tool based on a bore plan in a steering mode such that at least some positional error is introduced without using the electromagnetic homing signal. Switching from the steering mode to the homing mode is based on monitoring of the electromagnetic homing signal as the boring tool approaches the portable device to then guide the boring tool to the target position location in compensation for the positional error. Intermediate target positions are described as well as guiding the boring tool based on the homing signal so long as the portable device receives the signal.

Rotary Steerable System Having Multiple Independent Actuators

A fully rotating bias unit for directional drilling rotates at bit speed while providing proportional control of directional response and steering force. The unit also provides added reliability by having increased redundancy (multiple independently controlled actuators). The unit disposed on a drillstring transfers rotation to a drill bit and has a bore communicating fluid from the drillstring to the drill bit. Directors are disposed on the unit to rotate with it. Each of the directors is independently movable between extended and retracted conditions relative to the unit's housing. Actuators of the unit are in fluid communication between the bore and the borehole or some other low pressure. Each actuator is independently operable to direct communicated fluid from the bore to extend a respective one of the directors toward the extended condition. Meanwhile, venting of the communicated fluid from the directors to the borehole or other low pressure dump allows the respective director to retract toward the retracted condition. 1. A drilling assembly disposed on a drillstring for deviating a borehole advanced by a drill bit , the assembly comprising:a housing disposed on the drillstring and transferring rotation to the drill bit, the housing having a bore communicating fluid from the drillstring to the drill bit;a plurality of directors disposed on the housing, each of the directors being movable between a retracted condition and an extended condition relative to the housing;a plurality of valve members disposed on the housing, each of the valve members moveable between first and second conditions and configured to control fluid communication of the communicated fluid from the bore to a respective one of the directors; anda plurality of actuators disposed on the housing, each of the actuators configured to actuate a respective one of the valve members,each of the actuators being independently operable to actuate the respective valve member between the first and second ...

An alignment system

An apparatus for use in maintaining a desired orientation of an implement is provided. The apparatus includes orientation sensing equipment operable to sense the orientation of the implement, and an orientation indicator operable to be mounted relative to the implement, the orientation indicator having a plurality of indication portions, and when the orientation indicator is mounted relative to the implement, the indication portions are positioned so as to be visible from different locations around the implement. In use, when the orientation of the implement deviates from the desired orientation, one or more indication portions provide a visible indication of a direction in which the implement has deviated from the desired orientation.

LASER-INDUCED PLASMA TOOL

An example plasma tool is configured to operate within a wellbore of a hydrocarbon-bearing rock formation. The plasma tool includes a laser head that includes one or more optical components. The laser head is configured to receive one or more laser beams at the one or more optical components and to output the one or more laser beams via the one or more optical components. The plasma tool includes a laser beam generator to generate the one or more laser beams. The laser beam is configured to induce a plasma in a volume of fluid. The plasma is for producing shock waves in the volume of fluid. The plasma tool includes a deformable acoustic mirror that confines the volume of fluid at least in part. The deformable acoustic mirror is configured to receive the shock waves to produce destructive reflected waves in the volume of fluid. 1. A system comprising:a downhole unit configured to operate within a wellbore, the downhole unit comprising a laser head comprising one or more optical components;a laser beam generator to generate one or more laser beams, the laser head of the downhole unit being configured to receive the one or more laser beams at the one or more optical components and to output the one or more laser beams via the one or more optical components, where the one or more laser beams are output to induce a plasma in a volume of fluid, the plasma for producing shock waves in the volume of fluid;a deformable acoustic mirror at least in part confining the volume of fluid and configured to receive the shock waves to produce destructive reflected waves in the volume of fluid;one or more sensors in the wellbore to sense one or more environmental conditions within the wellbore during operation of the downhole unit; andone or more processing devices to generate at least some information based on the one or more environmental conditions.2. The system of claim 1 , where the laser beam generator is integrated into the downhole unit.3. The system of claim 1 , where the ...

DEVICE FOR CONTROLLING A DRILLING ACCESSORY EQUIPPED WITH AN ANGLE MEASUREMENT DEVICE

The control device is configured to remotely control a drilling accessory mounted on a support arm of a carrier machine, the control device including a control casing and an angle measurement device comprising a rotary member movably mounted in rotation on the control casing about an axis of rotation, the rotary member being equipped with a sighting device and the angle measurement device being configured to measure a predetermined angle (α) between a reference angular position of the rotary member and a selected angular position of the rotary member wherein the sighting device points towards a sighting point selected by an operator. 1. A control device which is portable and which is configured to remotely control a drilling accessory mounted on a support arm of a carrier machine , the control device including a control casing and an angle measurement device comprising a rotary member movably mounted in rotation on the control casing about an axis of rotation , the rotary member being equipped with a sighting device and the angle measurement device being configured to measure a predetermined angle between a reference angular position of the rotary member and a selected angular position of the rotary member in which the sighting device points towards a sighting point selected by an operator.2. The control device according to claim 1 , wherein the angle measurement device is disposed on an upper face of the control casing.3. The control device according to claim 2 , wherein the angle measurement device is configured so that the sighting device points in a reference direction substantially perpendicular to a front edge of the upper face of the control casing when the rotary member is in the reference angular position.4. The control device according to claim 1 , wherein the angle measurement device is configured so that the axis of rotation of the rotary member is substantially vertical when the control casing is positioned on a horizontal support.5. The control device ...

BEND MEASUREMENTS OF ADJUSTABLE MOTOR ASSEMBLIES USING STRAIN GAUGES

A wellbore assembly is provided that can include a first motor housing assembly member and a second motor housing assembly member that can bend relative to the first motor housing assembly at a bend location. The assembly can also include a strain gauge positioned on a first side of the bend location to determine an amount of bend of the second motor housing assembly member relative to the first motor housing assembly member by determining a strain. Based on the strain, the amount of bend or bend direction of the second motor housing assembly member relative to the first motor housing assembly member can be determined. 1. A downhole system , comprising:a first motor housing assembly member;a second motor housing assembly member coupled to the first motor housing assembly member and bendable relative to the first motor housing assembly member at a bend location in a wellbore;a strain gauge positioned on the second motor housing assembly to determine an amount of bend of the second motor housing assembly member relative to the first motor housing assembly member by determining a strain.2. The downhole system of claim 1 , wherein the strain gauge is positioned on the exterior of the second motor assembly housing member.3. The downhole system of claim 2 , wherein the strain gauge is included in a plurality of strain gauges.4. The downhole system of claim 3 , wherein the plurality of strain gauges are equidistant around a circumference of the second motor assembly housing member.5. The downhole system of claim 1 , further comprising a communication device operable to communicate data from one or more strain gauges to a computing device.6. The downhole system of claim 5 , wherein the strain gauge is communicatively coupled to the communication device.7. The downhole system of claim 5 , wherein the computing device is operable to compare one or more measurements to a calibrated strain measurement associated with a bend amount or bend direction.8. The downhole system of ...

System and method for communicating complex downhole information

A system and method for communicating downhole information through a wellbore to a surface location includes a drill string with a downhole tool, a pump for flowing drilling mud through the drill string and wellbore, a valve for flow restriction of the drilling mud, a sensing module for measuring downhole conditions in first and second orientations of the downhole tool, an actuator between two static positions, and a detector for measurement values at the surface location correlative to time between changes of pressure of the drilling mud. The time between pressure changes, as the actuator moves between static positions, conveys encoded data to the detector. The encoded data is compiled from downhole conditions measured by the sensing module, in addition to orientation of the downhole tool. Complex downhole conditions dependent on knowing the multiple orientations of the sensing module can now be communicated by a pressure releasing encoding system.

TOOL FACE CONTROL OF A DOWNHOLE TOOL WITH REDUCED DRILL STRING FRICTION

A system and method for drilling is disclosed, the system including a drill string with at least one drill pipe, a bottom hole assembly and a drill bit. The bottom hole assembly includes a downhole mud motor for rotating the drill bit, and a steering motor coupled between the mud motor and the drill pipe. The downhole mud motor includes a bent housing. The drill pipe is continuously rotated to minimize friction, regardless of whether the drill bit is turned using rotary drilling or drilling with the downhole mud motor. Tool face orientation may be controlled by operating the steering motor at the drill pipe speed, but in an opposite rotational direction to thereby hold the mud motor and bent housing stationary with respect to the formation. Steering motor speed may be increased or decreased to adjust tool face orientation. 1. A drilling system comprising:a drill string including at least one drill pipe and a drill bit;a first motor carried along said drill string and coupled between said at least one drill pipe and said drill bit so as to selectively rotate said drill bit in a first direction with respect to said at least one drill pipe, said first motor including a bent housing, anda steering motor coupled between said first motor and said at least one drill pipe so as to selectively rotate said first motor in a second direction opposite said first direction.2. The drilling system of wherein:said at least one drill pipe is in fluid communication with said first motor; andsaid first motor is a downhole mud motor.3. The drilling system of wherein:said steering motor is an electric motor.4. The drilling system of wherein:said at least one drill pipe is in fluid communication with said steering motor.5. The drilling system of wherein:said drill string includes an inner pipe and an outer pipe, said inner pipe being disposed within said outer pipe and defining an annular flow path therebetween; andthe drilling system further comprises a flow diverter that fluidly couples ...

AUTOMATED SLIDING DRILLING

Automated control of a drillstring in a borehole, which is not in continuous rotation, the drillstring comprising an angled component (a bent sub or the like) and a downhole means of rotating the bit, such as a motor or turbine, which rotates the bit independently of drillstring rotation. Near the distal end of the drillstring are measurement devices, at least one and in some aspects two or more, which are used to measure the orientation of the drillstring/bent sub/bottomhole assembly/drill bit with respect to a geophysical field of the earth, such as magnetism (magnetic toolface) or gravity (gravitational toolface). These measurement devices may be connected to a communications module which transmits the downhole toolface information to the surface. The drillstring is controlled to provide that based upon the downhole measurements the drilling system drills the borehole in a desired trajectory. 1. An automated method for controlling a drilling system—the drilling system comprising a drillstring extending from a surface location down into a borehole being drilled by the drilling system , an angled component , a bottomhole assembly including a bit and a downhole means for rotating the bit—to perform sliding drilling , the method comprising:measuring a downhole toolface from an orientation of the drillstring with respect to a geophysical field of the earth;communicating the downhole toolface to the surface;processing a trajectory of the borehole from the downhole toolface;determining whether the trajectory is within an acceptable range relative to a planned trajectory; andif the trajectory is outside of the acceptable range, applying a first impulse to the drillstring to change the downhole toolface.2. The method of claim 1 , wherein the orientation of the drillstring with respect to a geophysical field of the earth comprises one of magnetic toolface or gravitational toolface.3. The method of claim 1 , wherein the downhole means for rotating the bit comprises one of a ...

Reluctance Sensor for Measuring a Magnetizable Structure in a Subterranean Environment

A drilling apparatus, sensor, system and method. The drilling apparatus includes a drill bit and a steering controller that steers the drill bit. The drilling apparatus includes a reluctance sensor system that measures changes in magnetic flux. The reluctance sensor includes two or more magnets creating a bucking effect. The drilling apparatus includes a processor in communication with the reluctance sensor that receives the measurements made by the reluctance sensor to determine a distance or direction to a target object. The distance is utilized by the steering controller to steer the drill bit. 1. A drilling apparatus , the drilling apparatus comprising:a drill bit;a downhole steering system coupled to the drill bit and comprising a steering controller;a reluctance sensor system comprising at least one sensor and two or more magnets positioned to create a bucking effect; anda surface computer communicably coupled to the at least one sensor and the steering controller, where the surface computer contains a set of instructions that, when executed by the surface computer, cause the surface computer to receive magnetic flux measurements from the sensor, determine a distance or direction to a target object based in part on the magnetic flux measurement; and transmit the determined distance or direction to the steering controller.2. The drilling apparatus according to claim 1 , wherein the bit is a milling bit.3. The drilling apparatus according to claim 1 , wherein the reluctance sensor system is integrated with the drill bit.4. The drilling apparatus according to claim 1 , wherein the surface computer determines an azimuthal profile associated with the changes in magnetic flux to determine a direction of the drill bit relative to the target object.5. The drilling apparatus according to claim 1 , wherein the two or magnets are connected to actuators for positioning the two or magnets relative to each other in response to commands from the surface computer.6. The ...

Surface Excitation Ranging Methods and Systems Employing a Customized Grounding Arrangement

A surface excitation ranging method includes installing a customized grounding arrangement for a power supply located at earth's surface, wherein the customized grounding arrangement fulfills an impedance criteria or ranging performance criteria. The method also includes conveying an electrical current output from the power supply along a target well with a metal casing. The method also includes sensing electromagnetic (EM) fields emitted from the target well due to the electrical current. The method also includes using distance or direction information obtained from the sensed EM fields to guide drilling of a new well relative to the target well. 1. A surface excitation ranging method that comprises:installing a customized grounding arrangement for a power supply located at earth's surface, wherein the customized grounding arrangement fulfills an impedance criteria or ranging performance criteria;conveying an electrical current output from the power supply along a target well with a metal casing;sensing electromagnetic (EM) fields emitted from the target well due to the electrical current; andusing distance or direction information obtained from the sensed EM fields to guide drilling of a new well relative to the target well.2. The method of claim 1 , wherein installing the customized grounding arrangement comprises connecting the power supply to a metal casing installed in a well separate from the target well and the new well.3. The method of claim 1 , wherein installing the customized grounding arrangement comprises connecting the power supply to a ground stake deployed entirely below earth's surface.4. The method of claim 3 , further comprising drilling an open borehole or using an available open borehole to deploy the ground stake entirely below earth's surface.5. The method of claim 3 , further comprising drilling a pilot hole to deploy the ground stake entirely below earth's surface.6. The method of claim 1 , wherein installing the customized grounding ...

Systems and Methods for Controlling a Drilling Path Based on Drift Estimates

In a drilling system, a control system coupled to a drilling rig controls a bottom hole assembly (BHA) to drill a borehole through a geological formation along a drilling path. The control system determines a present position of the BHA and calculates a toolface vector to create a convergence path from the present position of the BHA to a desired target path. The control system also receives geological information and compensates the toolface vector to account for an estimated geologic formation drift. The control system causes at least one control parameter to be modified in order to alter a drilling direction of the BHA based on the calculated toolface vector and transmits the at least one control parameter to the drilling rig to target the BHA in accordance with the calculated toolface vector. The control system iteratively performs this process until convergence with the desired target path is achieved. 1. A method for controlling a drilling operation , comprising:(a) determining, by a computer system coupled to a drilling rig, a present position of a bottom hole assembly (BHA) in a borehole;(b) calculating, by the computer system, a toolface vector needed for the borehole to converge with a desired target path;(c) determining, by the computer system, a compensated toolface vector that is responsive to the toolface vector and a geological formation drift estimate;(d) orienting the BHA responsive to the compensated toolface vector;(e) repeating steps (a)-(d) until the borehole converges with the desired target path.2. The method of claim 1 , wherein the toolface vector is calculated using information comprising build rate claim 1 , present error vector claim 1 , and well plan information.3. The method of claim 2 , wherein the calculating the toolface vector step further comprises the steps of:determining, by the computer system, a look ahead point that is a fixed distance ahead of the BHA; andcalculating, by the computer system, a direction of drilling toward the ...

Drilling Planning System

A drilling system has one or more drilling machines at a drilling site, in communication with a drill planning computer. The drill planning computer includes one or more processors, and a non-transitory computer readable medium in communication with the one or more processors having encoded thereon a set of instructions executable by the one or more processors to receive drill plan parameters, generate a drill plan based on the drill plan parameters, communicate the drill plan to one or more drilling machines, execute the drill plan with the one or more drilling machines, update at least one of the drill plan parameters based on an identified change in drilling conditions, update the drill plan in real-time based on an updated drill plan parameter, and adjust operation of the one or more drilling machines to reflect the changes in the updated drill plan. 1. A method , comprising:receiving, with a computer system, one or more drill plan parameters;generating, with the computer system, a drill plan based on the one or more drill plan parameters, the drill plan comprising a three-dimensional model specifying positions, depths, and inclinations for a plurality of holes to be drilled in a construction project;communicating, via the computer system, the drill plan to one or more machines;executing, with the one or more machines, the drill plan to drill one or more holes in a material, in accordance with the drill plan;identifying, with at least one of the one or more machines, a change in at least one of the one or more drill plan parameters corresponding to at least one of a calculation or measurement based on conditions at a project site;receiving, with the computer system, an at least one updated drill plan parameter, the at least one updated drill plan parameter being based on the at least one of the calculation or measurement of conditions at the project site;updating, with the computer system, the drill plan in real-time based on the at least one updated drill plan ...

Downhole Triaxial Electromagnetic Ranging

A ranging system calculates the distance, direction and orientation of a target well through rotationally invariant analysis of triaxial electric and magnetic field measurements from a bottom hole assembly (“BHA”) having electromagnetic sensors. The triaxial electric and magnetic field sensors can be deployed in any downhole device without explicitly needing to process or retrieve rotational information about the downhole BHA or wireline device. Also, the distance, direction and orientation of the target well can be retrieved from a single measurement position. 1. A method for downhole ranging , comprising:drilling a first wellbore, the first wellbore comprising an elongated conductive body;deploying an electric field sensor in a second wellbore;inducing a current along the first wellbore that results in an electromagnetic field being emitted from the first wellbore;receiving the electromagnetic field utilizing the electric field sensor, wherein an electric field of the electromagnetic field is measured; and a distance between the first and second wellbores; or', 'a direction of the first wellbore in relation to the second wellbore., 'utilizing the measured electric field to thereby calculate2. A method as defined in claim 1 , wherein the direction of the first wellbore is a direction of the measured electric field.3. A method as defined in claim 1 , further comprising determining an orientation of the first wellbore using the measured electric field.4. A method as defined in claim 1 , further comprising calculating a gradient of the measured electric field.5. A method as defined in claim 4 , further comprising:calculating a ratio of the measured electric field to the gradient of the measured electric field; andcalculating the distance between the first and second wellbores using the ratio.6. A method as defined in claim 1 , wherein a magnetic field sensor is also deployed in the second wellbore claim 1 , the method further comprising:measuring a magnetic field of ...

ESTIMATION OF DOWNHOLE TORQUE BASED ON DIRECTIONAL MEASUREMENTS

A method of estimating torque includes disposing at least one measurement assembly at a downhole component, the at least one measurement assembly including a first set of directional sensors disposed at a first axial location along the downhole component, and a second set of directional sensors disposed at a second axial location along the downhole component. The method also includes collecting directional measurement data from the first set of directional sensors and the second set of directional sensors during rotation of the downhole component, and estimating, by a processing device, an amount of torque on the downhole component based on the directional measurement data. 1. A method of estimating torque , comprising:disposing at least one measurement assembly at a downhole component, the at least one measurement assembly including a first set of directional sensors disposed at a first axial location along the downhole component, and a second set of directional sensors disposed at a second axial location along the downhole component;collecting directional measurement data from the first set of directional sensors and the second set of directional sensors during rotation of the downhole component; andestimating, by a processing device, an amount of torque on the downhole component based on the directional measurement data.2. The method of claim 1 , wherein the first set of directional sensors and the second set of directional sensors each include at least one of a magnetometer and an accelerometer.3. The method of claim 1 , wherein estimating the amount of torque includes calculating an angle of torsion based on a calculated angle between an orientation of the first set of directional sensors and an orientation of the second set of directional sensors.4. The method of claim 3 , wherein collecting the directional measurement data includes measuring a first static toolface angle of the first set of directional sensors and a second static toolface angle of the second ...

PULLBACK SYSTEM FOR DRILLING TOOL

A pullback system for a drilling tool includes features to retain a pulling cable. The drilling tool includes a drill bit body for carrying a plurality of cutting teeth. The drill bit body has a first side and an opposite second side. The drill bit body also defines a first pullback device passage that extends through the drill bit body from the first side to the second side. The first pullback device passage extends generally along a passage axis that extends through the drill bit body. The first pullback device passage includes at least a portion adjacent to the first side that curves as the surface extends in a direction along the passage axis. The passage axis is positioned along a reference plane that generally bisects the drill bit body. 1. A drilling tool comprising:a drill bit body carrying a plurality of cutting teeth, the drill bit body having a first side and an opposite second side, the drill bit body defining a first pullback device passage that extends through the drill bit body from the first side to the second side, the first pullback device passage being configured to receive a portion of a pullback device therein, the first pullback device passage extending generally along a passage axis that extends through the drill bit body, the first pullback device passage including at least a portion adjacent to the first side that is at least one of curved and beveled as the surface extends in a direction along the passage axis, the passage axis being positioned along a reference plane that generally longitudinally bisects the drill bit body.2. The drilling tool of claim 1 , further comprising a pullback device positionable within the first pullback device passage.3. The drilling tool of claim 1 , further comprising an inflexible pullback device having a pullback loop at a first end and a drilling tool hook at a second end claim 1 , wherein the drilling tool hook is positionable within the first pullback device passage.4. The drilling tool of claim 3 , ...

DOWNHOLE TOOL FOR MEASURING ANGULAR POSITION

A downhole tool for measuring angular positions at a location within a subterranean borehole. The tool is rotatable around the longitudinal direction of the borehole. The tool includes two or more magnetometers which measure the Earth's magnetic field along respective magnetometer axes. Each magnetometer is arranged such that its measurement includes a component of the Earth's magnetic field normal to the longitudinal direction of the borehole. The magnetometers are further arranged such that these normal components are at an angle to each other around the longitudinal direction. The tool further includes a device which measures the rotational speed of the tool or the time derivative thereof. The tool includes a processor unit that calculates angular positions of the downhole tool around the longitudinal direction relative to the direction of the Earth's magnetic field from the measurements of the Earth's magnetic field and the tool rotational speed or time derivative thereof. 1. A downhole tool for measuring angular positions at a location within a subterranean borehole , the downhole tool being configured to be rotatable around a longitudinal direction of the borehole , the downhole tool comprising:two or more magnetometers configured to obtain measurements of the Earth's magnetic field along respective magnetometer axes, wherein each magnetometer is arranged such that the measurements of the Earth's magnetic field include a component of the Earth's magnetic field normal to the longitudinal direction of the borehole, and wherein the magnetometers are arranged such that the normal components are at an angle to each other around the longitudinal direction;a device configured to measure a rotational speed of the tool or a time derivative thereof; anda processor unit configured to combine the measurements of the Earth's magnetic field and the tool rotational speed or time derivative thereof to calculate angular positions of the downhole tool around the longitudinal ...

DRILL PLANNING TOOL FOR TOPOGRAPHY CHARACTERIZATION, SYSTEM AND ASSOCIATED METHODS

A planning tool plans movement of a boring tool for an underground drilling operation. The planning tool includes one or more wheels for rolling on a surface of the ground along a path responsive to movement by an operator to characterize the surface contour and to generate guidance for the boring tool to reach a target position. Planning can additionally be based on waypoints. The planning tool can be rolled unidirectionally or bidirectionally to characterize the surface contour. Bidirectional movement cancels accelerometer fixed bias. Path stitching is used to plan around obstacles. The planning tool can facilitate tracker placement. The planning tool can collect noise information for frequency selection purposes. A described technique maximizes linear drilling in an underground plan. Compensation and/or warnings are provided for unsteady, fast and slow movement of the planning tool while measuring the surface contour. 1. A planning tool for planning movement of a boring tool during an underground drilling operation , the boring tool forming part of a system for horizontal directional drilling in which a drill rig advances the boring tool through the ground using a drill string that extends from the drill rig to the boring tool , said planning tool comprising:one or more wheels for rolling on a surface of the ground along a path responsive to movement by an operator, the path at least including (i) an initial surface position proximate to a current position of the boring tool with the boring tool at a current orientation and (ii) a subsequent surface position proximate to a user specified target position for the boring tool that is ahead of the current position;an encoder for generating an encoder output responsive to the rolling of one of the wheels between the initial surface position and the subsequent surface position;an accelerometer including at least one measurement axis for generating an accelerometer output during said rolling of the wheels along the path ...

Directional drilling device and method for calibrating same

The invention relates to a reliably functioning directional drilling device for continuous operation, with automatic, precision-controlled monitoring of targeted drilling at great depths with specification of a selectable directional path of the wellbore, comprising a housing, a bit drive shaft, which preferably rotates in the housing and which bears a rotary drill bit at its end, a control device located in the body section of the housing, and direction control devices for generating directing forces having radially alignable force components for the alignment of the directional drilling device during drilling operations, and magnetic field sensors that are connected to the control device, the magnetic field sensors being arranged in the head section, more specifically in the forward region of the housing facing the rotary drill bit, in close proximity to the rotary drill bit, i.e. near the rotary drill bit, and being calibrated by means of the method of the invention using a homogeneous magnetic field generated by a Helmholtz coil.

ADVANCED UNDERGROUND HOMING SYSTEM, APPARATUS AND METHOD

A boring tool that is moved by a drill string to form an underground bore. A transmitter transmits a time varying dipole field as a homing field from the boring tool. A pitch sensor detects a pitch orientation of the boring tool. A homing receiver is positionable at a target location for detecting the homing field to produce a set of flux measurements. A processing arrangement uses the pitch orientation and flux measurements with a determined length of the drill string to determine a vertical homing command for use in controlling depth in directing the boring tool to the target location such that the vertical homing command is generated with a particular accuracy at a given range between the transmitter and the homing receiver and which would otherwise be generated with the particular accuracy for a standard range, different from the particular range. An associated system and method are described. 1. In a system including a boring tool that is moved by a drill string using a drill rig that selectively extends the drill string to the boring tool to form an underground bore such that the drill string is characterized by a drill string length which is determinable , a homing apparatus comprising:a transmitter, supported by the boring tool, for transmitting a time varying dipole field as a homing field and including a pitch sensor for detecting a pitch orientation of the boring tool;a receiver that is positionable at least proximate to a target location for detecting the homing field to produce a set of flux measurements;a processor that is configured to generate a vertical homing command and a horizontal homing command by combining the detected pitch orientation and the set of flux measurements with a determined length of the drill string; anda display for displaying the vertical homing command and the horizontal homing command for guiding the boring tool to the target location.2. The homing apparatus of wherein the processor is configured for generating the vertical ...

PROBE FOR EXCAVATION-FREE GUIDANCE INSTRUMENT

A probe for a non-excavation guide can include an outer casing and a transmitting antenna. The transmitting antenna can be disposed in the outer casing, with the transmitting antenna including a magnetic core and a coil. The magnetic core can include a plurality of magnetic core segments. The magnetic core segments can be annular in shape and thereby define a hollow segment interior. The magnetic core segments can be sequentially arranged within the outer casing, with the coil located around an outside of the plurality of magnetic core segments. The probe assembly can facilitate the manufacture of the magnetic cores, reduce the disposition of insulating members, facilitate the assembly of the transmitting antenna, and/or reduce production costs. 18-. (canceled)9. A probe for a non-excavation guide , comprising:an outer casing; anda transmitting antenna disposed in the outer casing, the transmitting antenna including a magnetic core and a coil, the magnetic core comprising a plurality of magnetic core segments, the magnetic core segments sequentially arranged in a longitudinal direction of the probe, the coil being wound around the plurality of magnetic core segments.10. The probe of claim 9 , wherein each magnetic core segment is annular in shape.11. The probe of claim 9 , wherein each magnetic core segment is comprised of a magnetic material.12. The probe of claim 11 , wherein the magnetic material is a ferrite.13. The probe of claim 9 , wherein the probe defines a probe axis claim 9 , the plurality of magnetic core segments axially arranged with respect to the probe axis.14. The probe of claim 9 , wherein the outer casing includes a power supply and antenna region and a control circuit region claim 9 , the transmitting antenna located in the power supply and antenna region claim 9 , the control circuit region provided with a control circuit board claim 9 , the coil electrically connected to the control circuit board.15. The probe of claim 14 , wherein the power ...

DOWNHOLE DETERMINATION OF DRILLING STATE

A method for determining a drilling state of a bottom hole assembly in a wellbore includes acquiring one or more downhole sensor measurements and processing the sensor measurements using a downhole processor to determine a drilling state of the bottom hole assembly. An operating state of the bottom hole assembly may be automatically changed in response to the determined drilling state. A method for computing a dynamic drilling energy of a bottom hole assembly includes acquiring at least one sensor measurement and processing the sensor measurements to obtain at least one of (i) an energy of axial motion of the bottom hole assembly, (ii) an energy of rotational motion of the bottom hole assembly, and (iii) an energy of lateral motion of the bottom hole assembly. 1. A method for determining a drilling state of a bottom hole assembly in a wellbore , the method comprising:(a) acquiring one or more downhole sensor measurements;(b) processing the sensor measurements acquired in (a) using a downhole processor to determine a drilling state of the bottom hole assembly; and(c) automatically changing an operating mode of at least one component in the bottom hole assembly in response to the drilling state determined in (b).2. The method of claim 1 , wherein the downhole sensor measurements comprise at least one of measurement while drilling claim 1 , logging while drilling claim 1 , and strain gauge measurements.3. The method of claim 1 , wherein the drilling state of the BHA is selected from the group consisting of rotary drilling claim 1 , slide drilling claim 1 , in slips claim 1 , reaming claim 1 , running in while pumping claim 1 , running in while rotating claim 1 , running in claim 1 , tripping out claim 1 , back reaming claim 1 , pulling up while pumping claim 1 , pulling up while rotating claim 1 , pulling up claim 1 , rotating off bottom claim 1 , pumping off bottom claim 1 , rotating and pumping off bottom claim 1 , and stationary.4. The method of claim 1 , wherein ...

DOWNHOLE TOOL FOR MEASURING ACCELERATIONS

A downhole tool is provided for measuring accelerations at a location within a subterranean borehole. The tool is rotatable around the longitudinal direction of the borehole. The tool includes four accelerometers, each accelerometer measuring acceleration in a respective direction and being arranged such that at least a component of its measured acceleration is normal to the longitudinal direction. The accelerometers are further arranged such that no more than any two of the four accelerometers have their respective components parallel to the same direction. The tool also includes a first device which measures the rotational speed of the tool. The tool also includes a processor unit which relates the acceleration measured by each accelerometer to the true acceleration at that accelerometer by a respective scaling term and a respective offset, and combines the measured accelerations and the tool rotational speed to re-calibrate the scaling terms as the tool rotates. 1. A downhole tool for measuring accelerations at a location within a subterranean borehole , the tool being rotatable around a longitudinal direction of the borehole , the downhole tool comprising:four accelerometers, each accelerometer configured to measure acceleration in a respective direction and arranged such that at least a component of the measured acceleration is normal to the longitudinal direction of the borehole, wherein the accelerometers are arranged such that no more than any two of the four accelerometers have components that are parallel;a first device which measures the rotational speed of the tool; anda processor unit which relates the acceleration measured by each accelerometer to the true acceleration at that accelerometer by a respective scaling term and a respective offset, and combines the measured accelerations and the tool rotational speed to re-calibrate the scaling terms as the tool rotates.2. The downhole tool according to claim 1 , wherein the accelerometers are further ...

BORE TRAJECTORY SYSTEM

A method includes acquiring trajectory information; based at least in part on a portion of the trajectory information, generating a set of candidate trajectories with associated performance indicator values; rendering a graphical user interface to a display; via the graphical user interface, receiving input that adjusts one of the performance indicator values; and, responsive to the adjustment of the one of the performance indicator values, selecting one of the set of candidate trajectories. 1. A method comprising:acquiring trajectory information;based at least in part on a portion of the trajectory information, generating a set of candidate trajectories with associated performance indicator values;rendering a graphical user interface to a display;via the graphical user interface, receiving input that adjusts one of the performance indicator values; andresponsive to the adjustment of the one of the performance indicator values, selecting one of the set of candidate trajectories.2. The method of wherein the generating the set of candidate trajectories comprises solving a multi-objective optimization problem.3. The method of wherein the set of candidate trajectories comprises a Pareto efficient set.4. The method of wherein the generating the set of candidate trajectories comprises implementing at least one evolutionary processes.5. The method of comprising claim 1 , responsive to the selecting one of the set of candidate trajectories claim 1 , rendering a graphical representation of the selected one of the set of candidate trajectories to a display.6. The method of comprising receiving additional input that adjusts one of the performance indicator values; responsive to the receiving additional input claim 5 , selecting another one of the set of candidate trajectories; and claim 5 , responsive to the selecting of the other one of the set of candidate trajectories claim 5 , rendering the selected other one of the set of candidate trajectories to the display.7. The ...

CROSS-PLOT ENGINEERING SYSTEM AND METHOD

In one embodiment, a method includes facilitating a real-time cross-plot display of drilling-performance data for a current well. The real-time cross-plot display includes a plurality of data plots represented on a common graph such that each data plot specifying at least two drilling parameters. Each data plot includes a plurality of data points such that each data point is expressable as Cartesian coordinates in terms of the at least two drilling parameters. The method further includes receiving new channel data for the current well from a wellsite computer system. In addition, the method includes creating, from the new channel data, new data points for the plurality of data plots as the new channel data is received. Moreover, the method includes updating the plurality of data plots with the new data points as the new data points are created. 1. A method comprising:on a central computing system comprising at least one server computer, facilitating a real-time cross-plot display of drilling-performance data for a current well;wherein the real-time cross-plot display comprises a plurality of data plots represented on a common graph, each data plot specifying at least two drilling parameters;wherein each data plot comprises a plurality of data points, each data point expressable as Cartesian coordinates in terms of the at least two drilling parameters;the central computing system receiving new channel data for the current well from a wellsite computer system;the central computing system creating, from the new channel data, new data points for the plurality of data plots as the new channel data is received; andthe central computing system updating the plurality of data plots with the new data points as the new data points are created.2. The method of claim 1 , wherein claim 1 , for each of the plurality of data plots claim 1 , the central computing system maps the at least two drilling parameters to data sources for the current well.3. The method of claim 1 , ...

Apparatus and Method for Milling/Drilling Windows and Lateral Wellbores Without Locking Using Unlocked Fluid-Motor

In one aspect, a method of performing a downhole operation is disclosed that in one embodiment may include running a downhole tool including an anchor, a whipstock, a cutting device, and an unlocked fluid-operated motor into a wellbore; wirelessly transmitting signals relating to orientation of the downhole tool from a sensor associated with the downhole tool; orienting the whipstock in response to the transmitted signals and without flowing a fluid through the cutting device; setting the anchor in the wellbore without flowing the fluid through the cutting device; and performing the downhole operation using the motor. 1. A method of performing an operation in a wellbore , comprising:conveying a downhole tool that includes an anchor, a whipstock, a cutting device, and an unlocked fluid-operated motor configured to operate the cutting device into a wellbore;wirelessly transmitting signals relating to orientation of the downhole tool from a sensor associated with the downhole tool;determining orientation of the whipstock in response to the transmitted signals;orienting the whipstock to a desired orientation based on the determined orientation, without flowing a fluid through the cutting device;setting the anchor in the wellbore without flowing the fluid through the motor; andperforming the operation using the cutting device by flowing fluid through the motor.2. The method of further comprising orienting the whipstock and setting the anchor without locking the motor.3. The method of claim 1 , wherein transmitting wireless signals comprises sending signals selected from a group consisting of: acoustic signals; and electromagnetic signals along a member conveying the downhole tool into the wellbore.4. The method of further comprising providing a repeater in the wellbore that receives the transmitted signals claim 3 , conditions the received signals and retransmits the conditioned signals to the surface.5. The method of claim 1 , wherein setting the anchor comprises ...

DETERMINING FLUID PARAMETERS

A method of determining a fluid parameter includes receiving, by a processor and from a plurality of sensors coupled to a flexible tube, fluid information. The flexible tube includes a throat arranged in a first position with respect to a fixed end. The fluid information includes a strain or pressure at a first portion of the flexible tube and a strain or pressure at a second portion of the flexible tube. The method also includes determining a first fluid parameter of the fluid and transmitting, from the processor to a controller operationally coupled to the throat, second position information including a second position of the throat different than the first position. The method also includes receiving, with the throat in the second position, second fluid information and determining, based on the second fluid information, a second fluid parameter of the fluid. 1. A method comprising:receiving, by a processor and from a plurality of sensors coupled to a flexible tube, fluid information, the flexible tube fluidically coupled to and configured to flow fluid received from a pipe, the flexible tube comprising an end fixed to the pipe and a throat in a first position with respect to the fixed end, the throat residing between a first portion of the flexible tube converging along a flow direction of the fluid and a second portion of the flexible tube diverging along the flow direction of the fluid, the fluid information including a strain or pressure at the first portion of the flexible tube and a strain or pressure at the second portion of the flexible tube;determining, by the processor and based on the fluid information, a first fluid parameter of the fluid;transmitting, from the processor to a controller operationally coupled to the throat, second position information including a second position of the throat different than the first position to change a position of the throat from the first position to the second position;receiving, with the throat in the second ...

Ifr1 survey methodology

An improved IFR1 technique wherein a single mid-lateral well measurement of local magnetic field is used instead of single wellhead or BHA points of measurement, or a plurality of wellbore measurement methods.

NEAR-BIT TOOL ATTITUDE MEASUREMENT WHILE DRILLING APPARATUS AND METHOD

A near-bit tool attitude MWD apparatus includes measurement sensors and a measurement circuit. The measurement sensors transmit measured signals to the measurement circuit, and the measurement circuit processes and calculates the signals to obtain attitude data. The measurement sensors include a triaxial accelerometer, a triaxial gyroscope, a triaxial magnetic sensor and a temperature sensor, the measured data of the triaxial accelerometer, the triaxial gyroscope and the triaxial magnetic sensor are respectively corrected using the measured data of the temperature sensor, a first attitude angle is calculated using the corrected measured data of the triaxial accelerometer and the triaxial magnetic sensor. Quaternions are initialized using the first attitude angle, and the initialized quaternions are subjected to time updating according to the measured data of the triaxial gyroscope, and further an attitude angle is calculated utilizing the updated quaternions. The quaternions are periodically initialized to eliminate cumulative errors of the triaxial gyroscope, so as to improve the near-bit tool attitude MWD accuracy. 1. A near-bit tool attitude measurement while drilling (MWD) apparatus , comprising:a plurality of measurement sensors coupled to a measurement circuit,wherein the plurality of measurement sensors include a triaxial accelerometer, a triaxial gyroscope, a triaxial magnetic sensor, and a temperature sensor,wherein the measurement circuit comprises a plurality of low-pass filters coupled to an analog-to-digital converter, a field programmable gate array coupled to the analog-to-digital convertor, a processor coupled to the field programmable gate array, a memory coupled to the processor, andwherein each of the triaxial accelerometer, the triaxial gyroscope, the triaxial magnetic sensor, and the temperature sensor is coupled to one of the plurality of low-pass filters.2. The near-bit tool attitude MWD apparatus according to claim 1 , wherein the triaxial ...

HORIZONTAL DIRECTIONAL DRILLING AREA NETWORK AND METHODS

A drilling area network hub is located proximate to a drill rig and includes an uphole transceiver in bidirectional communication with a downhole transceiver by utilizing the drill string as an electrical conductor. Certain information is collected including rig-based and/or location information. At least one field report is generated based on the certain information to characterize at least one of an inground operation, an operational condition of the downhole transceiver, an operational condition of the uphole transceiver, and an operational condition of the drill rig. A drilling area network server receives the field report from the Internet at a remote location and can generate a custom report and/or recommended actions based on field data. Region specific parameters can be applied to the operation of a drilling system. The drilling area network hub can transfer data logs to the remote location according to assigned priorities. 1. An apparatus as part of a horizontal directional drilling system , said system including a drill rig and a portable locator for monitoring the location of an inground tool along an underground borepath , said apparatus comprising:a telemetry system for wireless bidirectional communication between the portable locator and the drill rig, configured to transmit at least one telemetry signal having a transmission power and a transmit frequency;a geographic database of region specific parameters that specifies operational parameters based on location of said horizontal directional drilling system;an arrangement for identifying a current location of the system and for correlating the current location with said geographic database to identify a set of local requirements for the telemetry signal at the current location that specify at least one of a maximum transmission power and at least one transmission frequency for the telemetry signal; anda controller for setting at least one of the transmission power and the transmit frequency to conform ...

DOWNHOLE ROBOTIC ARM

An apparatus for manipulating an object in a borehole in an earthen formation includes a body configured to be conveyed along the borehole and a plurality of linear actuators disposed in the body and operatively connected to the object. The plurality of linear actuators applies a translational and rotational movement to the object. A related method includes applying a translational and rotational movement to the object using the plurality of linear actuators. 1. An apparatus for manipulating an object in a borehole in an earthen formation , comprising:a body configured to be conveyed along the borehole; anda plurality of linear actuators disposed in the body and operatively connected to the object, the plurality of linear actuators applying a translational and rotational movement to the object.2. The apparatus of claim 1 , wherein the plurality of linear actuators includes a first and a second linear actuator claim 1 , the first and the second linear actuator each having a first end operatively connected to the object claim 1 , and a second end operatively connected to the body claim 1 , at least one of the first and second linear actuators operatively connected to the body including a joint allowing relative rotational movement.3. The apparatus of claim 1 , wherein the plurality of linear actuators includes a first and a second actuator claim 1 , the first linear actuator having an end operatively connected to the body claim 1 , the second linear actuator having a first end operatively connected to the first linear actuator and a second end operatively connected to the body.4. The apparatus of claim 1 , further comprising at least one fluid channel through the body claim 1 , the at least one fluid channel conveying a fluid during borehole operation.5. The apparatus of claim 1 , further comprising at least one sensor associated with the plurality of linear actuators or the object claim 1 , the at least one sensor measuring a movement of at least one of the plurality ...

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

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

DRILLING WITH INFORMATION CHARACTERIZING LATERAL HETEROGENEITIES BASED ON DEEP DIRECTIONAL RESISTIVITY MEASUREMENTS

A method and system is provided for drilling a wellbore that traverses a geological formation using a drilling tool. The method and system derives a plurality of formation models that characterize the geological formation. The number of formation models represent layer structures with a heterogeneity (such a fault) offset laterally at variable distance relative to position of the drilling tool. Simulated directional resistivity data of the drilling tool is derived from the plurality of formation models. Certain simulated directional resistivity data are combined or selected for processing as multi-dimensional cross-plot data. Measured directional resistivity data obtained by the drilling tool is used to evaluate the multi-dimensional cross-plot data to determine distance of the heterogeneity relative to position of the drilling tool. The determined distance of the heterogeneity relative to position of the drilling tool can used for controlling drilling direction and can be stored in computer memory and used in other reservoir analysis. 1. A method of drilling a wellbore that traverses a geological formation using a drilling tool , the method comprising:deriving a plurality of formation models that characterize the geological formation, wherein the plurality of formation models represents layer structures with a heterogeneity offset laterally at variable distances relative to position of the drilling tool, and wherein the plurality of formation models have variable distance from the drilling tool to the heterogeneity as well as variability in at least one additional model parameter;deriving simulated directional resistivity data of the drilling tool based the plurality of formation models;combining or selecting simulated directional resistivity data derived from the plurality of formation models for processing as multi-dimensional cross-plot data;using measured directional resistivity data obtained by the drilling tool to evaluate the multi-dimensional cross-plot ...

WELLBORE TOOL POSITIONING SYSTEM AND METHOD

Embodiments of the present disclosure include a system for positioning a section of a tool in a section of a wellbore including a first arm coupled to a motor actuator at a first end and a positioning component at a second end. The system also includes a second arm coupled to a biasing member at a first end and the positioning component at a second end. The motor actuator drives rotation of the first end of the first arm about a rotation axis to change a radial position of the positioning component with respect to a tool axis at the section of the tool. 1. A system for performing downhole operations , the system comprising:a tool string;a downhole tool forming at least a first portion of the tool string; and 'a plurality of adjustable arm devices (AADs), the AADs driving respective positioning components radially outward from an axis of a section of the tool string toward a wellbore wall, wherein each AAD of the plurality of AADs is individually actuatable in response to a deployment command and driven radially outward by a respective external motive force.', 'a positioning system forming at least a second portion of the tool string, the positioning system comprising2. The system of claim 1 , wherein the AAD comprises:a first arm coupled to a motor actuator at a first end of the first arm and to the positioning component at a second end of the first arm;a second arm coupled to a biasing member at a first end of the second arm and to the positioning component at a second end of the second arm; andwherein the motor actuator drives rotation of the first arm about a rotation axis, the rotation of the first arm driving the positioning component radially outward from the axis of the section of the tool string.3. The system of claim 2 , wherein the AAD further comprises:a communication device communicatively coupled to the motor actuator, the communication device sending and receiving instructions to and from the motor actuator; andan actuator sensor, the actuator sensor ...

Communication protocol in directional drilling system, apparatus and method utilizing multi-bit data symbol transmission

A system includes a transmitter for use in conjunction with a horizontal directional drilling system that transmits a multi-bit symbol stream that characterizes sensor symbols for receipt by an aboveground portable device. The portable device receives the symbol stream for aboveground recovery of the sensor signals. The transmitter can precisely place the symbol frequencies at least to avoid a noise environment, as well as to avoid powerline harmonics, and can utilize wave shaping for transmitted symbols at least to provide for transmission power control, spectral content control and wideband antenna matching. The receiver can measure the noise environment to identify the symbol frequencies used by the transmitter. The noise can be scanned at an incremental resolution across a wide frequency bandwidth for display or automatic symbol frequency selection.

STEERING HEAD FOR AN AUGER CASING

A steering head for use with a casing, the steering head having a body with a first body end with a lead edge, a second body end with a rear edge, and a body surface extending from the lead edge to the rear edge, an outer tube with an internal side generally facing the body surface, the outer tube extending from the first body end to the second body end, and a steering flap disposed on an external side of the outer tube having a first flap face facing radially inwardly and a second flap face facing radially outwardly. A fluid dispenser is disposed in a void defined between the outer tube and the body. 1. A steering head for use with a casing , the steering head comprising:a body defining a longitudinal body axis and having a body surface extending from a lead edge to a rear edge of the body;an outer tube having an internal side and an external side, the internal side generally facing the body surface such that the outer tube and the body define a void therebetween;at least one steering flap disposed on the outer tube and having a distal end, a first flap face facing radially inwardly toward the body surface and an opposing second flap face facing radially outwardly away from the longitudinal body axis, the at least one steering flap being moveable between an extended position and a retracted position;a spring disposed operatively between the steering flap and the outer tube, biasing the steering flap toward the retracted position; anda fluid dispenser being in fluid communication with the void for selectively dispensing a fluid into the void,wherein the void is in fluid communication with the external environment when the steering flap is in the extended position.2. The steering head as in claim 1 , further comprising a powered actuator mounted to the steering flap and the body surface claim 1 , the powered actuator being disposed in the void and operative to extend the steering flap to the extended position from the retracted position.3. The steering head as in ...

APPARATUS AND METHODS FOR UNINTERRUPTED DRILLING

During slide drilling, certain transient variances in differential pressure may indicate that a subsequent and temporary variance in a toolface angle error does not indicate that drilling should be interrupted. The transient variances in the differential pressure may be within a range of particular threshold pressures. 1. A control system for controlling a drilling operation , the control system comprising:a database comprising a plurality of data relating to a plurality of drilling parameters, wherein the database is updated during drilling of a borehole;a processor coupled to the database; during slide drilling, detecting an increase to a first differential pressure (ΔP) that is greater than a first threshold pressure and less than a second threshold pressure;', 'responsive to detecting the first ΔP, detecting a variance in a toolface angle error greater than a first threshold variance;', 'responsive to detecting the variance of the toolface angle, detecting within a first threshold period, a reduction in the variance greater than the first threshold variance; and', 'responsive to detecting the reduction in the variance, generating an output to a user indicating that the variance of the toolface angle is not associated with interrupting the slide drilling., 'a memory accessible to the processor and storing instructions executable by the processor for2. The control system of claim 1 , wherein the instructions detecting the reduction in the variance further comprise instructions for detecting a decrease to a second ΔP that is less than the first threshold pressure.3. The control system of claim 1 , wherein the plurality of drilling parameters comprise at least one of: weight on bit claim 1 , rate of penetration claim 1 , differential pressure claim 1 , mud flow rate claim 1 , torque claim 1 , and rate of oscillation.4. The control system of claim 1 , wherein the database further comprises information relating to equipment used for the drilling claim 1 , and ...

PERMANENT OR REMOVABLE POSITIONING APPARATUS AND METHOD FOR DOWNHOLE TOOL OPERATIONS

A location connector connects a first tubular to a second tubular, and includes a cylindrical main body extending in a longitudinal direction. An outer surface extends around a circumference of the main body, and an inner surface faces the central bore of the main body. A first connector is on a first end of the main body and is configured to attach to the first tubular. A second connector on an opposite second end of the main body is configured to attach to the second tubular. A female profile is provided on the inner surface, and includes a plurality of grooves for selective engagement with a discrete complementary profile comprising one or more protruding members of a downhole tool. Each of the grooves comprises a no-go shoulder that prevents movement of the tool in one direction, and each of the grooves permits clocking movement of the tool in an azimuthal direction. 1. A location connector for connecting a first tubular to a second tubular , the location connector comprising:a cylindrical main body extending in a longitudinal direction and comprising a central bore extending through the cylindrical main body in the longitudinal direction;an outer surface around a circumference of the cylindrical main body, and an inner surface facing the central bore;a first connector on a first end of the cylindrical main body and configured to attach to an end of the first tubular, and a second connector on an opposite second end of the cylindrical main body and configured to attach to an end of the second tubular; anda female profile on the inner surface, the female profile comprising a plurality of grooves for selective engagement with a discrete complementary profile comprising one or more protruding members of a tool, wherein each of the grooves in the plurality of grooves comprises a no-go shoulder configured to prevent movement of the tool in one direction, and each of the grooves permits clocking movement of the tool in an azimuthal direction.2. The location connector ...

DRILLING APPARATUS USING A SELF-ADJUSTING DEFLECTION DEVICE AND DEFLECTION SENSORS FOR DRILLING DIRECTIONAL WELLS

An apparatus for drilling a directional wellbore is disclosed that in one non-limiting embodiment includes a drive for rotating a drill bit, a deflection device that enables a lower section of the drilling assembly to tilt about a member of the deflection device within a selected plane when the drilling assembly is substantially rotationally stationary to allow drilling of a curved section of the wellbore when the drill bit is rotated by the drive and wherein the tilt is reduced when the drilling assembly is rotated to allow drilling of a straighter section of the wellbore, and a tilt sensor that provides measurements relating to tilt of the lower section. A controller determines a parameter of interest relating to the tilt for controlling drilling of the directional wellbore. 1. A drilling assembly for drilling a wellbore , comprising:a drive for rotating a drill bit;a deflection device that enables a lower section of the drilling assembly to tilt about a member of the deflection device within a selected plane when the drilling assembly is substantially rotationally stationary to allow drilling of a curved section of the wellbore when the drill bit is rotated by the drive and wherein the tilt is reduced when the drilling assembly is rotated to allow drilling of a straighter section of the wellbore; anda tilt sensor that provides measurements relating to tilt of the lower section.2. The drilling assembly of claim 1 , wherein the tilt sensor is selected from a group consisting of: an angular position sensor; a rotary encoder sensor; a Hall Effect sensor;and a magnetic marker.3. The drilling assembly of further comprising a directional sensor that provides measurement relating to a direction of the drilling assembly.4. The drilling assembly of further comprising a force sensor that provides measurements relating to force applied by the lower section on an element of the upper section.5. The drilling assembly of claim 5 , wherein the force sensor is positioned at an ...

Evaluating a Condition of a Downhole Component of a Drillstring

Methods, systems and products for evaluating a downhole component condition for a drilling assembly in a borehole. Methods include estimating a bending moment on the component at a selected depth along the borehole; estimating a number of rotations of the component at the selected depth; and estimating the condition of the component using the estimated bending moment and the estimated number of rotations at the selected depth. Estimated bending moment may be derived from a borehole model using an estimated deviation on a selected length of the borehole about the selected depth. The condition may be accumulated fatigue or estimated remaining useful life. Estimating the condition may include tracking a total estimated number of rotations wherein the component is subjected to bending moment values in a corresponding moment window, which may be greater than a predetermined threshold bending moment. Weight factors may be associated with at least one moment window. 1. A method for evaluating a condition of a downhole component of a drilling assembly in a borehole , the method comprising:estimating a bending moment on the component at a selected depth along the borehole;estimating a number of rotations of the component at the selected depth; andestimating the condition of the component using the estimated bending moment and the estimated number of rotations at the selected depth.2. The method of further comprising deriving the estimated bending moment using an estimated deviation on a selected length of the borehole about the selected depth.3. The method of further comprising deriving the estimated deviation from a borehole model.4. The method of claim 1 , wherein the method further comprises deriving the estimated location of the component in the borehole using an axial offset of the component from a distal end of the drilling assembly.5. The method of claim 1 , wherein the condition is at least one of: i) accumulated fatigue of the component; and ii) estimated remaining ...

Extendable orienting tool for use in wells

An orienting tool for use in wells can include a flow control device which controls flow between an interior and an exterior of a body of the tool to thereby transmit a signal indicative of an orientation of the body, the flow control device being outwardly extendable relative to the body. A method of orienting a structure in a well can include transmitting at least one signal from an orienting tool, the signal being indicative of an orientation of the orienting tool, and displacing a housing of the tool outward relative to a generally tubular body of the tool. A well system can include an orienting tool connected to a structure and positioned in a wellbore, the tool including a housing which is outwardly extendable relative to a generally tubular body, the tool being configured to transmit at least one signal indicative of an orientation of the structure.

HORIZONTAL DIRECTIONAL DRILLING AREA NETWORK AND METHODS

A drilling area network hub is located proximate to a drill rig and includes an uphole transceiver in bidirectional communication with a downhole transceiver by utilizing the drill string as an electrical conductor. Certain information is collected including rig-based and/or location information. At least one field report is generated based on the certain information to characterize at least one of an inground operation, an operational condition of the downhole transceiver, an operational condition of the uphole transceiver, and an operational condition of the drill rig. A drilling area network server receives the field report from the Internet at a remote location and can generate a custom report and/or recommended actions based on field data. Region specific parameters can be applied to the operation of a drilling system. The drilling area network hub can transfer data logs to the remote location according to assigned priorities. 1. An apparatus for customizing a telemetry system of a horizontal directional drilling system based on region specific parameters , said horizontal directional drilling system including a drill rig and an inground tool that is movable by the drill rig along an underground borepath , said apparatus comprising:a portable locator for monitoring the position and/or orientation of the inground tool on the borepath and configured at least to transmit a telemetry signal;a geographic database that provides the region specific parameters for the telemetry signal;an arrangement for correlating a current location of the system with the geographic database to identify at least one local requirement for the telemetry signal; anda controller for setting the telemetry signal to conform to the local requirement.2. The apparatus of wherein the region specific parameters include the local requirement as at least one of a maximum transmission power and at least one transmission frequency for said telemetry signal at the current location and the controller ...

METHOD OF DETERMINING WHEN TOOL STRING PARAMETERS SHOULD BE ALTERED TO AVOID UNDESIRABLE EFFECTS THAT WOULD LIKELY OCCUR IF THE TOOL STRING WERE EMPLOYED TO DRILL A BOREHOLE AND METHOD OF DESIGNING A TOOL STRING

A method of determining when tool string parameters should be altered to avoid undesirable effects that would likely occur if the tool string were employed to drill a borehole includes, modeling portions or an entirety of the tool string in the borehole under steady state loading conditions, identifying deflections of the tool string with the modeling when buckling would occur for specific tool string parameters, and calculating whether whirl exhibiting similar deflections of the tool string to those identified during buckling would be undesirable. 1. A method of determining when tool string parameters should be altered to avoid undesirable effects that would likely occur if the tool string were employed to drill a borehole , comprising:modeling portions or an entirety of the tool string in the borehole under steady state loading conditions;identifying deflections of the tool string with the modeling when buckling would occur for specific tool string parameters; andcalculating whether whirl exhibiting similar deflections of the tool string to those identified during buckling would be undesirable.2. The method of claim 1 , further comprising varying the specific tool string parameters during the modeling.3. The method of claim 1 , further comprising determining a contribution that a dimension between adjacent stabilizers has to buckling of the tool string.4. The method of claim 1 , further comprising determining a contribution that radial clearance between the tool string and walls of the borehole has to buckling of the tool string.5. The method of claim 1 , further comprising calculating where the tool string will make contact with walls of the borehole.6. The method of claim 1 , further comprising calculating individual and/or cumulative normal forces between the tool string and walls of the borehole.7. The method of claim 1 , further comprising calculating fatigue of the tool string.8. The method of claim 1 , further comprising calculating frictional wear of the ...

TVD CORRECTED GEOSTEER

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

REDUCING ERROR CONTRIBUTIONS TO GYROSCOPIC MEASUREMENTS

A method and system for reducing error contributions to gyroscopic measurements is provided. The method includes receiving a plurality of signals indicative of at least one component of the Earth's rotation substantially perpendicular to a portion of a wellbore and a component of the Earth's rotation substantially parallel to the portion of the wellbore. The plurality of signals is generated by one or more gyroscopic sensors within the portion of the wellbore. The method further includes calculating, using the plurality of signals and using one or more signals indicative of the Earth's rotation rate and one or more signals indicative of the latitude of the one or more gyroscopic sensors within the portion of the wellbore, a mass unbalance offset for the one or more gyroscopic sensors. 123-. (canceled)24. A method , comprising:receiving a plurality of angular rotation rate measurements about a first axis of a survey tool disposed in a wellbore from one or more first gyroscopic sensors of the survey tool, wherein the one or more first gyroscopic sensors are positioned in a first plurality of index positions;receiving a plurality of angular rotation rate measurements about a second axis of the survey tool from the one or more first gyroscopic sensors positioned in the first plurality of index positions;receiving a plurality of angular rotation rate measurements about a third axis of the survey tool from a second gyroscopic sensor of the survey tool, wherein the second gyroscopic sensor is positioned in a second plurality of index positions; anddetermining one or more bias values based on the plurality of angular rotation rate measurements about the first axis, the plurality of angular rotation rate measurements about the second axis, the plurality of angular rotation rate measurements about the third axis, or combinations thereof.15. The method of claim 24 , wherein the one or more first gyroscopic sensors comprise one or more Coriolis vibratory gyroscopic sensors ...

Displaying Steering Response with Uncertainty in A Heat Map Ellipse

A computer-implemented method including receiving a steering command identifying a tool face orientation in which the steering command is expected to produce an intended steering response of an intended drilling trajectory. The method further includes receiving an actual steering response result of the steering command in which the actual steering response result identifies an actual drilling trajectory. The method further includes storing a dataset comparing the actual steering response result in relation to the intended steering response, determining an uncertainty level of the tool face orientation based on the stored dataset, and outputting a visual representation of steering response with the uncertainty level. 1. A computer-implemented method comprising:receiving a steering command identifying a tool face orientation, wherein the steering command is expected to produce an intended steering response of an intended drilling trajectory;receiving an actual steering response result of the steering command, wherein the actual steering response result identifies an actual drilling trajectory;storing a dataset comparing the actual steering response result in relation to the intended steering response;determining an uncertainty level of the tool face orientation based on the stored dataset; andoutputting a visual representation of steering response with the uncertainty level.2. The method of claim 1 , wherein the visual representation comprises at least one of:a steering response ellipse having a heatmap; anda steering response ellipse with an uncertainty band.3. The method of claim 1 , wherein the uncertainty level represents a level of confidence that the actual steering response result matches the intended steering response.4. The method of claim 1 , wherein the steering response command further identifies a build rate and a turn rate claim 1 , wherein the uncertainty level is further based on the build rate and the turn rate.5. The method of claim 1 , further ...

SYSTEM AND METHOD FOR MITIGATING STICK-SLIP

A method for drilling a well. The method may include detecting stick-slip vibrations at a frequency via a downhole sensor. The method may further include determining a reflection coefficient of a drill bit for the frequency based on at least one of a rotational speed of the drill bit or a torque of the drill bit. The method may also include determining a reflection coefficient of a top drive for the frequency based on at least one of a rotational speed of the top drive or a torque produced by the top drive. The method may further include adjusting a control system in electronic communication with the top drive based on the reflection coefficient of the drill bit for the frequency and the reflection coefficient of the top drive for the frequency. 1. A method for drilling a well , the method comprising:detecting stick-slip vibrations at a frequency via a downhole sensor;determining a reflection coefficient of a drill bit for the frequency based on at least one of a rotational speed of the drill bit or a torque of the drill bit;determining a reflection coefficient of a top drive for the frequency based on at least one of a rotational speed of the top drive or a torque produced by the top drive; andadjusting a control system in electronic communication with the top drive based on the reflection coefficient of the drill bit for the frequency and the reflection coefficient of the top drive for the frequency.2. The method of claim 1 , further comprising:determining a reflection coefficient of the drill bit via a bottom-hole assembly (BHA) computer system; andcommunicating the reflection coefficient of the drill bit to a surface detector in electronic communication with the control system via a telemetry system.3. The method of claim 1 , further comprising:determining a mechanical impedance of the drill bit for the frequency via a BHA computer system based on at least one of the drill bit rotational speed or the drill bit torque; andcommunicating the mechanical impedance of ...