Abstract: Wellbore operations include rotating a drill string in a wellbore. The drill string includes a rotary steerable system having at least three pads configured to contact the wellbore wall to steer a direction of drilling. These are simultaneously actuated while rotating the drill string to mitigate stick slip, harmonic stick slip, or backward whirl oscillations.

Abstract: A capture device which captures propagation path information communicated between the two or more wireless devices and transmits the propagation path information to a first detection device and a second detection device; and a learning model generation device which generates a learning model for object detection using supervised machine learning are provided. The first detection device performs object detection between the wireless devices using a learning model generated by the learning model generation device, the second detection device performs object detection with higher accuracy than the first detection device, and the learning model generation device generates and updates a learning model which is used by the first detection device as teacher data using determination data including object detection results of the second detection device. This makes it possible to easily generate a learning model using supervised machine learning without spending time or manpower.

Abstract: Methods and systems are provided for automated closed-loop control of drilling trajectory during directional drilling to a geological target, which employ a surface-located predictive controller that interfaces to and cooperates with a downhole trajectory control system to automatically control the drilling direction of a drilling tool during the directional drilling. The predictive controller is configured to receive data representing a new reference trajectory for a given measured depth and generate output data representing a sequence of set-points for the new reference trajectory. The predictive controller is further configured to communicate the output data to the downhole trajectory control system to automatically control the drilling direction of the drilling tool to follow the new reference trajectory.

Abstract: An apparatus, rock drilling rig and drilling method is provided. The apparatus provides position control data for controlling positioning a rock drilling unit of a rock drilling rig arranged for drilling transverse drill hole patterns in an underground tunnel. The apparatus includes a teaching feature for gathering data on manually controlled movements at the location of the drill hole pattern and to thereby detect a movement path, which is collision free. The data on the taught collision free movement path is implemented when controlling the rock drilling unit during an actual drilling phase.

Abstract: A method comprises receiving a current dataset for a current time window from at least one sensor in a wellbore created in a subsurface formation, wherein the current dataset comprises values of a number of current features of the subsurface formation at a spatial location in the wellbore. The method includes selecting at least one previous time window from a number of previous time windows that includes a previously cached dataset that was detected by the at least one sensor or a different sensor in the wellbore and that spatially overlaps with the spatial location for the current dataset. The method includes merging the current dataset with the previously cached dataset to create a merged dataset. The method includes selecting a machine learning model from a plurality of machine learning models for the spatial location in the wellbore based on the merged dataset.

Abstract: Systems and methods presented herein provide for cutting in a borehole or casing. A cutting device can include a first arm having a cutting blade, wherein the cutting blade has side cutting teeth and an axis of rotation that is substantially at a right angle with respect to an axis of the tool body. The cutting device can also include a second arm with a bumper. The first and second arms articulate away from the elongate body in different directions to reduce vibrations while cutting. A control device can automate the cut based on hydraulic pressure measurements. Additionally, the cutting device can also be extended or rotated on a rotary index. The cutting device can rotate around a J slot, in an example.

Abstract: A method of operating a drilling fluid analysis system includes obtaining multiple samples of a drilling fluid at different times over a time period. The method also includes placing the multiple samples into a capillary electrophoresis device. The method further includes determining a respective concentration of a component in each of the multiple samples of the drilling fluid with the capillary electrophoresis device.

Abstract: 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.

Abstract: A method for drilling a subterranean wellbore includes rotating a bottom hole assembly (BHA) in the subterranean wellbore to drill the wellbore, the BHA including a drill collar, a drill bit, and a triaxial accelerometer set and a triaxial magnetometer set in or coupled to the drill collar. The triaxial accelerometer set and the triaxial magnetometer set make a plurality of sets of synchronized accelerometer measurements and magnetometer measurements while drilling. These synchronized measurements are processed to compute an interference magnetic field which is in turn processed to compute at least one of a distance or a direction to a magnetic target located external to the wellbore.

Abstract: A rock porosity prediction method based on small-sample while-drilling data inversion is provided, including: collecting while-drilling parameters during laboratory or field drilling processes, including parameters such as torque M, propulsion F, rotational speed N, drilling speed V, drill pipe amplitude A, and vibration acceleration a; inputting the different types of multi-stage denoised while-drilling parameter data into a backpropagation regression-genetic algorithm (BP-GA) model for discrete point elimination, data augmentation, and iterative calculation to form a new while-drilling dataset; inputting the time-frequency domain feature graphs of while-drilling parameters for rocks with different porosities into a rock porosity convolutional neural network (VG-CNN) prediction model, obtaining an inversion model between the time-frequency domain features of while-drilling parameters and porosity through training and learning, ultimately achieving inversion prediction of rock porosity according to real-time

Abstract: A variety of methods and apparatus are disclosed, including, in one embodiment, detecting a drilling event, involving flowing a drilling fluid from a wellbore being drilled through a separator, removing rock cuttings from the drilling fluid by the separator, discharging the drilling fluid from the separator without the rock cuttings removed to a mud pit, measuring a first viscosity of the drilling fluid upstream of the mud pit with a single point viscometer, measuring a second viscosity of the drilling fluid in the mud pit or downstream of the mud pit with a second viscometer that is not a single point viscometer, and detecting a drilling event associated with drilling of the wellbore by comparing the first viscosity with the second viscosity.

Abstract: A method can include a computing device receiving a drill plan for the borehole. The drill plan can include survey information providing formation information for one or more sections of the borehole. The method can include accessing a plurality of capability data for one or more bottom hole assemblies that may include: a neutral capability score, a steering capacity score, and a sliding ratio score. The method can include determining an overall score for each of the one or more bottom hole assemblies based at least in part on the neutral capability score, the steering capacity score, and the sliding ratio score. The method can include determining, by the computing device, a select bottom hole assembly of the one or more bottom hole assemblies based at least in part on the overall score. The method may include displaying the overall score and an identification of the select bottom hole assembly.

Abstract: A method and system that include receiving sensor data that is indicative of an operational status of a well construction equipment that is being utilized to construct a planned well that include receiving a well construction plan that includes information that is indicative of the planned well and the well construction equipment. The method and system additionally include accessing a database of operational sequences that are executable to be performed by the well construction equipment to construct a plurality of wells and selecting from the database an operational sequence to construct the planned well. The method and system further include electronically controlling the well construction equipment to autonomously perform the plurality of physical or mechanical operations of the selected operational sequence to drill at least one of: a selected portion of the planned well and a path along the selected portion of the planned well through a subterranean formation.

Abstract: In one embodiment, a method includes accessing a first series of first magnetic values that represents a first magnetic recording that includes a first set of first magnetic measurements. Each of the first magnetic values represents one of the first magnetic measurements. The method includes accessing a second series of second magnetic values that represents a second magnetic recording that includes a second set of second magnetic measurements. Each of the second magnetic values represents one of the second magnetic measurements. The method includes approximately aligning the first and second series with each other; calculating a difference between the first and second series as aligned with each other; and determining a similarity between the first and second series based on the difference.

Abstract: A method for a physics-driven deep learning-based inversion coupled to fluid flow simulators may include obtaining measured data for a subsurface region, obtaining prior subsurface data for the subsurface region, and obtaining a physics-driven standard regularized joint inversion for at least two model parameters. The method may further include obtaining a case-based deep learning inversion characterized by a contracting path and an expansive path. The method may further include forming the physics-driven deep learning inversion with the physics-driven standard regularized joint inversion, the case-based deep learning inversion, and a coupling operator based on a penalty function. The method may further include forming a feedback loop between the physics-driven standard regularized joint inversion and the case-based deep learning inversion for re-training the case-based deep learning inversion. The method may further include generating an inversion solution for reservoir monitoring.

Abstract: A system and method may include receiving data acquired by a downhole tool of a tool string disposed at least in part in a borehole in a subsurface region. The system and method may also include inverting the data using a trained machine learning model to generate a structural feature of the subsurface region. The system and method may further include controlling operation of the tool string based at least in part on the structural feature of the subsurface region.

Abstract: A system and method of real-time optimization of drilling performance metrics during a well drilling operation, for oil and gas as well as geothermal wells, or wells drilled for any other purpose. In a preferred form, the system receives information about allowable drilling metrics and real-time information of performance indicators. The drilling performance metrics and performance indicators are used to build a model to predict drilling parameters likely to optimize one or more drilling performance metrics.

Abstract: Method for controlling the state of an operation in a hydrocarbon exploration and recovery environment, including creating at least one function model, said function model including at least one function, executing at least one function within said function model, defining a plurality of function controls, a pre-determined combination of given function controls within said plurality of function controls defining a signature event, an occurrence of said signature event being indicative of a specific state of said operation, and monitoring the occurrence of said signature event during execution of a certain function included in said at least one function model.

Abstract: Embodiments use a torque-and-drag model or fluid friction model for predicting a zero tension or zero pressure for various operations such as rotary drilling and sliding, in vertical, curve, and lateral sections of a well, without using a downhole sensor. By adjusting coefficients of friction, the model can be used to match the predicted hook load, torque, and pressure values with the measured hook load, torque, and pressure values, respectively. A control system can thus determine more accurate zero values for weight on bit and/or differential pressure, which can be used to maintain, alter, plan, modify, and/or predict drilling parameters and conditions.

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

Abstract: A wellbore assembly that includes a drill string and a housing. The drill string defines a first fluid pathway extending from the drill string, through the drill bit, and out the drill bit to flow a first lost circulation material. The housing stores a second lost circulation material including at least one parameter different from the first lost circulation material. The drill string defines a second fluid pathway extending from the drill string, through the housing, and out the housing to direct, with the first fluid pathway blocked, fluid along the second fluid pathway to flow the second lost circulation material out the housing to a lost circulation zone of the wellbore. The drill string directs, with the second fluid pathway blocked, fluid along the first fluid pathway to flow the first lost circulation material out the drill bit to the lost circulation zone to plug the lost circulation zone.

Abstract: A method for optimizing drilling performance of a drilling operation is discloses. The method includes determining, while advancing a drill bit during the drilling operation based on drilling parameters specified by a user, a rate of penetration (ROP), acquiring, using sensors disposed throughout a rig of a well, sensor measurement data related to circulation of drilling fluid, generating, using a drilling hydraulics model based on at least the sensor measurement data of the circulation of drilling fluid, modeled rig and bit hydraulics data, displaying, on a driller console of the rig, the modeled rig and bit hydraulics data as a real-time drilling hydraulics profile, in response to a user viewing the displayed real-time drilling hydraulics profile, receiving an adjustment to the drilling parameters from the user, and further performing the drilling operation based on the adjustment to optimize the ROP.

Abstract: A downhole traction system includes a driving system and a downhole wheeled tractor. The driving system is connected with the downhole wheeled tractor; the downhole wheeled tractor comprises a tractor body, a power unit and a plurality of traction units; the plurality of traction units are arranged along the extension direction of the tractor body; each of the traction units comprises a driving arm, a supporting arm, a supporting wheel, a driving assembly and a supporting assembly; the driving arm and the supporting arm are movably connected with the tractor body; and the supporting wheel is connected with the driving arm and the supporting arm. When the supporting assembly drives the supporting arm to extend along the radial direction of the tractor body under the hydraulic drive action of the hydraulic power unit, the supporting wheel can be abutted against the well wall.

Abstract: A tool health manager may receive surface contextual data of the downhole drilling system. A tool health manager may receive downhole contextual data of the downhole drilling system, the downhole contextual data including downhole operating data for a downhole tool. A tool health manager may synchronize the downhole contextual data with the surface contextual data to generate synchronized data. A tool health manager may prepare a historical comparison between historical data and the synchronized data. A tool health manager may, based on the historical comparison, generate a tool health status of the downhole tool.

Abstract: A drilling system, assembly, and method may help optimize drilling in a system that involves more than one rotary tool that engages the formation. A rotary tool may be a rotary cutting tool, such as a drill bit or reamer, or some other rotary tool (e.g. stabilizer or rotary steerable tool) that has the potential to drag on the wall of the hole being drilled and take energy away from cutting. In an example, a wellbore or portion thereof is formed by rotating a first rotary cutting tool having a first cutting structure in engagement with one portion of the formation together with a second rotary cutting tool having a second cutting structure in engagement with another portion of the formation. Forces are obtained above and below the second cutting structure. One or more drilling parameter or drill bit design parameter are adjusted in relation to a force differential between the forces above and below the second cutting structure.

Abstract: Methods and apparatus pertaining to scaling of the proportional gain and the integral gain in PI controllers of an autodriller based on drilling context. For example, a proportional gain and an integral gain are each determined for utilization by a PI controller of an autodriller controlling operation of equipment to be utilized for a drilling operation to drill a borehole into a subterranean formation. During the drilling operation, the integral gain is updated in real-time utilizing current values of drilling parameters that change with respect to time.

Abstract: A position detection device for detecting the position of a bucket of an excavator having a cab and one or more booms is disclosed. A boom is rotatably attached to the cab by a mounting structure that is rotatably attached to the cab by a shaft having a longitudinal axis extending basically vertically during normal use of the excavator. The bucket is rotatably mounted to a stick that is rotatably attached to the boom. The mounting structure is arranged and configured to allow the boom to be rotated with respect to the longitudinal axis of the shaft. The position detection device comprises one or more antennas arranged and configured to receive satellite signals. The position detection device comprises a sensor assembly configured to detect the angular position of the boom with respect to rotation about the longitudinal axis of the shaft.

Abstract: A method of connecting tubular components includes positioning a first tubular component at a surface location and a second tubular component at least partially disposed in a borehole to initiate a threaded connection, and rotating the first tubular component relative to the second tubular component by a tubular connection system, and during the rotating, measuring at least one of a rotational position of the first tubular component and/or a component of the tubular connection system, relative to the second tubular component, and a rotational speed of the first tubular component and/or the component of the tubular connection system. The method further includes measuring a torque, estimating a number of turns remaining to reach a target torque on the first tubular component, and controlling a rotational speed of the first tubular component based on the estimated number of turns remaining to connect the first tubular component to the second tubular component.

Abstract: A system can flush a drilling fluid sample with a hydrocarbon blend, which includes a determined concentration of at least one chemical species to generate a flushed drilling fluid sample. The system can extract a dissolved gas from the flushed drilling fluid sample. The system can determine a concentration over time of at least one chemical species of the dissolved gas. The system can generate an area per concentration curve based on the concentration over time of the at least one chemical species. The system can determine at least one concentration value of the at least one chemical species. The system can modify the at least one concentration value based on the area per concentration curve. The system can then correct bias caused by the gas extractor and fluid sampling system.

Abstract: The invention relates to an arrangement for controlling a rock drilling machine during an extraction of a drill string from a drilled bore, the rock drilling machine being movably arranged on a feeder, the arrangement comprising an actuator arranged to move the rock drilling machine in a direction opposed to a drilling direction along the feeder, a rotation motor arranged to rotate the drill string, and an actuator controller arranged to control the actuator during the extraction of the drill string from a drilled bore, the actuator controller being arranged to control the actuator according to a first or a second mode in dependence of an operational parameter, such as a torque generated by the rotation motor to rotate the drill string.

Abstract: A system and methods for petro-steering methodologies are provided. An exemplary method obtains rock fabric data, and integrate rock fabric data with dynamic productivity data to identify patterns between the rock fabric data and dynamic productivity data. Gas rates and steering values are predicted across UBCT wells based on the patterns.

Abstract: The present invention relates to a downhole self-propelling wireline tool string for being connected to and powered by a wireline for propelling a tool forward in a well and/or for providing weight on a bit while performing an operation, comprising a first downhole self-propelling wireline tool, comprising a first tool body, a first electric motor operating at a rotational speed, a first electric control unit for controlling the rotational speed of the electric motor, one first drive section, comprising a plurality of projectable arm assemblies movably connected at a first arm end with the tool body and projectable from the tool body by means of a first fluid having a first fluid pressure, and a plurality of wheels for contacting a wall of the well, each wheel comprising a hydraulic motor for rotation of the wheel to provide a self-propelling movement, and each wheel being connected with a second arm end of one of the arm assemblies, a first hydraulic pump driven by the electric motor for generation of a seco

Abstract: Disclosed is an automatic hole-processing method with self-adapting adjustment of processing parameters, including the following steps: performing tool feeding, detecting whether the rotate speed changes or not, if changes, judging the type of the processing material according to the new rotate speed after stabilization (if not, the tool feeding is continued); feeding the tool according to the processing parameters suitable for the material, detecting whether the rotate speed changes or not, if changes, judging whether the hole processing has been completed or not according to the new rotate speed after stabilization (if not, the tool feeding is continued), if completed, retracting the tool with the set parameters (if not, judging the type of the processing material according to the new rotate speed after stabilization, and repeating the above steps), completing the hole processing.

Abstract: A drilling rig includes a carrier, a ground support attached to the carrier for supporting the carrier on the ground, a drilling boom attached at a first end to the carrier, a feed beam attached to a second end of the drilling boom, a drilling unit attached movably along the feed beam, a ground pin attached to the feed beam for supporting the feed beam onto the ground, and control means configured for performing the steps of at least: receiving ground support force information indicative of force applied by the ground support to the ground, and detecting ground contact state of the ground pin on the basis of the received ground support force information.

Abstract: Systems and methods for monitoring slide drilling operations and providing advisory information includes a Bayesian network having a slide drilling dysfunction output node and six input nodes including: a downhole mechanical specific energy (MSE) trend node; a downhole bit aggressiveness trend node; a differential pressure trend node; a minimum buckling load node; a downhole weight on bit (DWOB) vs surface weight on bit (SWOB) ratio node, and a toolface efficiency index node. When one or more dysfunctions are detected based on the information provided to one or more nodes, the system sends out one or more alerts and provides one or more corrective actions to return to efficient drilling.

Abstract: A pitch data processing system of a horizontal directional drilling system can include a sonde, an offset and range calibration unit, a pitch speed limiter, and a low pass filter. The sonde can include an accelerometer configured to measure and output a raw pitch signal. The offset and range calibration unit can receive and process the raw pitch signal and output a calibrated pitch signal. The pitch speed limiter can receive the calibrated pitch signal. The pitch speed limiter is configured to set upper and lower pitch change speed limits. The pitch speed limiter can yield a speed-change limited pitch signal. The low pass filter can receive the speed-change limited pitch signal and attenuate the received speed-change limited pitch signal above a selected cutoff frequency of the low pass filter, the low pass filter configured to output an adjusted pitch signal.

Abstract: An integrated data recorder may be positioned within a slot in a tool. The integrated data recorder includes a sensor package that includes one or more drilling dynamics sensors, a processor in data communication with the one or more drilling dynamics sensors, a memory module in data communication with the one or more drilling dynamics sensors, a wireless communications module in data communication with the processor, and an electrical energy source in electrical communication with the memory module, the one or more drilling dynamics sensors, and the processor.

Abstract: A method for well integrity assessment using machine-trained prediction of physical characteristics related to well integrity across a depth interval of a cased wellbore having one or more casing strings. The method includes collecting scattered X-ray signals from a plurality of X-ray detectors arranged within a well logging tool, learning trained weights to predict wellbore characteristics from the scattered X-ray signals, collecting further scattered X-ray signals from the X-ray detectors, using the trained weights to quantitatively predict the wellbore characteristics from the further X-ray signals, and using the predicted wellbore characteristics to assess well integrity.

Abstract: Methods, systems, and computer-readable media for controlling a toolface of a downhole tool are described. The toolface of the downhole tool, and a toolface setpoint, are determined. Based on the toolface and the toolface setpoint, a toolface error is determined. Based on the toolface error, one or more drilling parameter setpoints are selected from among multiple drilling parameter setpoints. The selected one or more drilling parameter setpoints are adjusted. The adjusted one or more drilling parameter setpoints are inputted to one or more drilling controllers for controlling the toolface of the downhole tool.

Abstract: A tool, e.g. a downhole tool, utilizes at least one actuator which may be actuated rapidly between positions during operation of the tool. The actuator is moved via flow of an actuating fluid controlled by a main valve which, in turn, is controlled via a pilot valve. The pilot valve is operated to selectively control flow of the actuating fluid to the main valve so as to shift the main valve between desired operational positions.

Abstract: A line of coherent radiation is projected on a bed on which one or more particles is located, the one or more particles flowing produced as a result of a downhole operation in the borehole. An image of the bed is captured wherein one or more particles on the bed deflect the line of coherent radiation. One or more image edges is detected based on the captured image. A subset of the one or more image edges is identified as corresponding to edges of the one or more particles, based in part on changes in intensity of the captured image. Information about the one or more particles, including information about of size, shape and volume, can be determined from the one or more image edges corresponding to the edges of the one or more particles.

Abstract: Systems and methods determine friction in a borehole during drilling operations. A drilling system applies oscillatory angular movement at the top of a drill string in a wellbore during drilling by the drilling system, and measures a torque applied to the drill string and an angular position of the drill string. Based on the measured torque and the measured angular position, the drilling system computes a friction between the borehole and the drill string. This can be repeated during drilling of the wellbore to determine multiple friction values, corresponding to various depths of the borehole. Based on the computed friction, the drilling system can perform one or more actions resulting in modified drilling operation. The systems and methods also include oscillating a casing in the borehole, measuring the torque and angular position of the casing, and determining a friction value, which can be repeated to develop a wellbore friction profile.

Abstract: A method for controlling a drilling trajectory of a wellbore includes receiving a target trajectory reference of a drill bit within a wellbore from a formation model. The method also includes receiving real-time formation evaluation measurements from at least one sensor positioned within the wellbore and computing a target trajectory set-point change based on the real-time formation evaluation measurements. Further, the method includes generating a target trajectory from the target trajectory reference and the target trajectory set-point change and steering the drill bit using the target trajectory.

Abstract: An example hybrid power system includes a mobile platform comprising: a generator set comprising: a reciprocating engine configured to convert natural gas into rotational mechanical energy; and a generator configured to convert rotational mechanical energy sourced from the reciprocating engine into electrical energy; an electrical energy storage system (ESS) configured to store electrical energy; an electrical motor configured to convert electrical energy sourced from a combination of the generator set and the ESS into rotational mechanical energy; and a pump configured to operate using rotational mechanical energy sourced from the electrical motor.

Abstract: Drilling operations may be monitored to detect and quantify potential drilling dysfunctions. Using a Bayesian network, potential improvements to drilling operation may be made depending upon the type of dysfunction detected. Suggestions for improved drilling performance may comprise increasing, decreasing, or maintaining one or both of RPM and weight on bit. Suggestions may be presented to an operator as a cone having an apex at the current RPM and weight on bit drilling parameters, with suggestions for modifications to one or both of the RPM and weight on bit corresponding to a cone extending from that apex.

Abstract: A flow measurement apparatus can include a main flow passage, a variable flow restrictor, a bypass flow passage having an inlet connected with the main flow passage upstream of the variable flow restrictor and an outlet connected with the main flow passage downstream of the variable flow restrictor, and a mass flowmeter connected in the bypass flow passage between the inlet and the outlet. A method can include connecting a flow measurement apparatus, so that a fluid flow in a well also flows through the flow measurement apparatus, and varying a restriction to the fluid flow through the variable flow restrictor in response to a change in a flow rate of the fluid flow.

Abstract: 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.

Abstract: A support gate device that allows iron tubes to be loaded efficiently into a pipe holding bin of a directional drilling machine. The support gate device is a rectangular cartridge the houses a swiveling gate. The swiveling gate has a stop plate and a spring. The support gate device attaches to an end of a horizontal bar of the directional drilling machine. The directional drilling machine has a pair of horizontal bars that are linearly opposed to each other that lead into the pipe holding bin. A pair of support gate devices are installed on the horizontal bars of the directional drilling machine.

Abstract: Methods and systems are provided that combine NMR and IR spectroscopy measurements on a rock sample to determine data representing at least one property of the rock sample. In one embodiment, cuttings can be split into first and second lots. Results of an NMR measurement performed on the first lot of cuttings without cleaning can be analyzed to determine pore volume of the cuttings. Results of an IR spectroscopy measurement performed on the second lot of cuttings after solvent cleaning can be analyzed to determine matrix density of the cuttings. Porosity can be determined from the pore volume and matrix density of the cuttings. In another embodiment, combined NMR and IR spectroscopy measurements can be performed on an unprepared rock sample (without solvent cleaning) to characterize properties of kerogen in the rock sample and porosity. In another aspect, a method is provided that employs multi-nucleic NMR measurements to determine porosity.

Abstract: An example method for monitoring drilling includes releasing a wireless data retrieval device within a drill string in a wellbore, forcing fluid downhole through the drill string such that the data retrieval device travels in the fluid through a fluid outlet in a drill bit connected to the drill string, receiving data in the data retrieval device from a wireless sensor disposed on or in a body of the drill bit, and transferring the data from the data retrieval device after the data retrieval device travels in the fluid through the fluid outlet. An example wellbore drilling system includes a drill bit that includes a body, a fluid outlet, one or more wireless sensors disposed on or in the body, and a waterproof data retrieval device configured to receive data wirelessly from the wireless sensor(s), the data retrieval device having a size smaller than an opening in the fluid outlet.