Abstract: A disclosed drilling method includes: obtaining a formation model representing formation properties to be encountered by a drilling assembly being steered towards a target; identifying at least one path-dependent drilling dynamics model for predicting the drilling assembly's response to one or more operating parameters; characterizing uncertainties associated with said formation model and said at least one drilling dynamics model, said characterizing yielding a probability density function for each uncertainty; representing an acceptable range for each of said one or more operating parameters as a probability density function; employing the probability density functions to determine random samples of said uncertainties and of said one or more operating parameters; applying a cost function to the random samples to determine an expected cost as a function said one or more operating parameters; and displaying the randomly sampled operating parameters having a minimum expected cost as optimized operating paramete

Abstract: An electric stator surrounds an electric rotor. A magnetic coupling is attached to an end of the electric rotor. The magnetic coupling is configured to transmit rotational force to or from a separate rotational device. A housing surrounds and isolates the electrical rotor, the electric stator, and a portion of the magnetic coupling from a wellbore fluid. A pressure within the housing is lower than a pressure within a wellbore environment.

Abstract: Methods and systems for controlling drilling operations are provided. The methods and systems include conveying a drilling tool into a bore and operating the drilling tool to drill in a direction, creating, with an azimuthal sensing device, a first signal at a first time and a second signal at a second time, wherein each of the first signal and the second signal are indicative of the direction of the drilling tool, and each of the first signal and the second signal are affected by at least one of an unknown but substantially constant offset error or an unknown but substantially constant scale factor error, comparing the first signal with the second signal, and adjusting the drilling direction based on the comparison of the first signal with the second signal.

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

Abstract: A system includes a light source, a detector, and a processor. The light source is configured to emit light onto a target. The detector is configured to receive light interaction between the emitted light and the target. The processor is configured to receive the light interaction between the emitted light and the target and further configured to process the light interaction to determine an edge profile associated with the target.

Abstract: A steering tool is movable by a drill string to form an underground bore along an intended path. A sensing arrangement of the steering tool detects its pitch and yaw orientations at a series of spaced apart positions along the bore, each position is characterized by a measured extension of the drill string. The steering tool further includes a receiver. At least one marker is positioned proximate to the intended path, for transmitting a rotating dipole field to expose a portion of the intended path to the field for reception by the receiver. The detected pitch orientation, the detected yaw orientation and the measured extension of the drill string are used in conjunction with magnetic information from the receiver to locate the steering tool. The steering tool may automatically use the magnetic information when it is available. A customized overall position determination accuracy can be provided along the intended path.

Abstract: A downhole assembly includes a tool-orienting device including an operating unit that obtains downhole measurements and a pulse-generating device that transmits the downhole measurements to orient a downhole tool. A restrictor sub is coupled to the tool-orienting device and includes a nozzle that restricts fluid flow therethrough, and a circulating valve is coupled to the restrictor sub and includes a nozzle that restricts fluid flow therethrough. A liner running tool is coupled to the circulating valve to convey a liner and a pressure-activated tool into the wellbore. The pulse-generating device operates with a fluid at a first pressure and the restrictor sub is actuatable by increasing the first pressure to a second pressure. The circulating valve is actuated by the fluid at a third pressure and the pressure-activated tool is activated by increasing third pressure to a fourth pressure.

Abstract: Methods for determining oil-water contact positions and water zone resistivities are provided. In one example, the method may involve performing a 1D inversion on data collected by a resistivity logging tool. Further, the method may involve scanning a resistivity profile of a reservoir generated by the 1D inversion for a boundary position below the resistivity logging tool. Furthermore, the method may involve applying a local residual weighted average on the boundary position to generate an initial estimation of an oil-water contact position and inverting the initial estimation of the oil-water contact to generate water zone resistivity and a modified oil-water contact position. Additionally, the method may involve running a smoothing local post-processing operation to generate a layered model and performing a 2D inversion on the layered model.

Abstract: Apparatus, systems, and methods may operate to couple a power supply to a ground point associated with a well, and to a lower portion of a conductive casing disposed within the well, where the lower portion of the conductive casing is separated by an insulating gap from an upper portion of the conductive casing, the upper portion of the conductive casing being at a higher elevation of the first well than the lower portion of the conductive casing. Further activity may include injecting an excitation signal into the lower portion of the conductive casing to induce a magnetic field in a geological formation surrounding the first well. Additional apparatus, systems, and methods are disclosed.

Abstract: A method for steering a downhole tool in a wellbore includes measuring a tool face when the drill bit is off-bottom, measuring an angular position of a drill string when the drill bit is off-bottom, and measuring a torque on the drill string when the drill bit is off-bottom. Measuring the tool face when the drill bit is on-bottom and measuring the torque on the drill string when the drill bit is on-bottom. Determining a transfer function comprising the angular position of the quill, the difference between the tool face when the drill bit is on-bottom and off-bottom, and the difference between the torque when the drill bit is on-bottom and off-bottom. The angular position of the drill string is varied at the surface, based upon the transfer function, to reduce an angle between the tool face when the drill bit is on-bottom and a target tool face.

Abstract: An accelerometer arrangement and method are described for determining accelerations of an inground tool. First and second triaxial accelerometers are supported such that a normal sensing axis of the first triaxial accelerometer is at least generally orthogonal to the normal sensing axis of the second triaxial accelerometer for determining the accelerations along the three orthogonal axes based on a combination of sensing axis outputs from one or both of the triaxial accelerometers. A weaker sensing axis of one triaxial accelerometer can be supported at least approximately normal to a weaker sensing axis of another triaxial accelerometer such that the weaker axes are not used. The triaxial accelerometers can be supported such that one axis of one accelerometer can be redundant with respect to another axis of another accelerometer. One triaxial accelerometer can be mounted on a tilted plane with respect to another triaxial accelerometer.

Abstract: 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.

Abstract: An automated slide drilling system (ASDS) may be used with a drilling rig system to control slide drilling. The ASDS may autonomously control slide drilling without user input during the slide drilling. The ASDS may further support a transition from rotary drilling to slide drilling to rotary drilling without user input during the transitions. The ASDS may also support user input and user notifications for various steps to enable manual or semi-manual control of slide drilling by a driller or an operator.

Abstract: A power winch overcurrent (overload) safety device includes a display panel with an overcurrent (overload) warning display zone. Simultaneously, amperages used in the power winch is set with an upper limit current setting value, and a current actual value is set for an actual amperage. The current setting value and the current actual value are displayed on the display panel. A first plug socket is plugged by a plug head of a controller to perform operating of the power winch, and a second plug socket is further disposed on the electrical control set of the power winch and connected to a circuit set for the current setting value in the electrical control set, and which using for the plug of a current regulator to regulate the current setting value.

Abstract: A method and system are provided for performing magnetic anomaly sensing. Each of two magnetometers generates magnetic field measurements. The magnetometers define a one-dimensional gradiometer having a baseline between them. A difference value is generated using the magnetic field measurements. The magnetometers are independently moved to maintain the baseline when the difference value is unchanging. Detection of a magnetic anomaly by a first magnetometer is indicated when the difference value deviates. The second magnetometer is then maneuvered until the magnetic field measurements generated thereby are indicative of detection of the magnetic anomaly by the second magnetometer. When this occurs, an adjusted baseline is defined between the magnetometers. At least one of the magnetometers is maneuvered to position the adjusted baseline in each of three orthogonal dimensions.

Abstract: Embodiments of the present disclosure provide a method and an apparatus for enhancing measurement in a wireless communication system. The method includes: obtaining, according to a measurement period or triggered by an event, a measurement amount, where the measurement amount includes a ratio of a valid signal based on a reference signal to a non-valid signal based on the reference signal measured based on the reference signal; reporting the measurement amount to a base station; or performing cell selection or cell reselection according to the measurement amount.

Abstract: Various driver assistance systems mountable in a host vehicle and computerized methods for detecting a vertical deviation of a road surface. The driver assistance system includes a camera operatively connectible to a processor. Multiple consecutive image frames are captured from the camera including a first image of the road and a second image of the road. Based on the host vehicle motion, the second image is warped toward the first image to produce thereby a warped second image. Image points of the road in the first image and corresponding image points of the road in the warped second image are tracked. Optical flow is computed between the warped second image to the first image. The optical flow is compared with an optical flow based on a road surface model to produce a residual optical flow. The vertical deviation is computed from the residual optical flow.

Abstract: A method for determining orientation of an electrical resistivity boundary in a wellbore includes using measurements of an electromagnetic property of formations traversed by the wellbore at at least one axial spacing between a multiaxial electromagnetic transmitter and a multiaxial electromagnetic receiver, and determining a symmetrized angle using measurements of the electromagnetic property made using receiver components transverse to a well logging instrument axis and a transmitter component along the axis. At least a relative orientation of the electrical boundary with respect to an orientation of the well logging instrument is determined using the symmetrized angle.

Abstract: The present disclosure describes measuring bending moments within a drillstring or tool string to identify deflections (or “dog-legs”) within the string. In some systems, the bending moments a plurality of strain gauges. In some such systems the strain gauges will be arranged in a selected spacing around the circumference of the tool string, in many examples, at a common plane extending generally perpendicular to the longitudinal axis of the string proximate the strain gauges. The bending moments may be further evaluated to provide a measure of wellbore tortuosity. For example, the bending moments may be utilized to define a radius of curvature associated with the determined bending moments, which may be further correlated with a directional measurement to apply a direction to the bending moment, and therefore to the tortuosity an any given location.

Abstract: A leveling system for identifying high and low areas of a surface relative to a reference plane to within a desired tolerance. A light source emits light in a level plane at a height above the reference plane. Several depth-indicator targets rest on the surface to be measured in an upright manner and are struck by the light in the level plane. Each of the depth-indicator targets indicates, based on color, whether the surface at that surface location is high, low, or level based on the location at which the light strikes the depth-indicator target. The color emitted by the target can be from a fluorescing layer of the target or light signals on the target controlled by a light-detecting receiver. A user can then quickly identify problem areas of the surface that need to be adjusted (e.g., raised or lowered).

Abstract: A method for determining the direction and/or range from a drilling well to a target well may include positioning a magnetic source in the target well and a magnetic sensor in the drilling well. The method may include activating the magnetic source in the target well and moving one or both of the magnetic source and magnetic sensors until a location in which the magnetic sensor is not saturated is identified. The method may include determining the direction and/or range to the target well at that location.

Abstract: A system and method for monitoring underground drilling in which vibration is monitored by creating a model of the drill string using finite element techniques or finite difference techniques and (i) predicting vibration by inputting real time values of operating parameters into the model, and then adjusting the model to agree with measured vibration data, (ii) predicting the weight on bit and drill string and mud motor speeds at which resonance will occur, as well as when stick-slip will occur, so that the operator can avoid operating regimes that will result in high vibration, (iii) determining vibration and torque levels along the length of the drill string based on the measured vibration and torque at one or more locations, (iv) determining the remaining life of critical components of the drill string based on the history of the vibration to which the components have been subjected, and (v) determining the optimum drilling parameters that will avoid excessive vibration of the drill string.

Abstract: A method utilized in borehole logging, such as in surveying or exploration relating to a subsurface formation. The method includes deploying a logging instrument that includes a pressure sensor into a borehole drilled into the formation. The method includes the steps of obtaining a first pressure value at a first depth in the borehole, obtaining at least one further pressure value subsequent to the first pressure value during withdrawing or advancing the logging instrument in the borehole, and determining one or more characteristics of the subsurface formation, utilizing at least one of the further pressure values, or a change in pressure (??) between the first pressure value and a said further pressure value or values, or a change in pressure (??) between a said further pressure value and another said further pressure value, or a combination of two or more of such values.

Abstract: Angular position readings are obtained during rotation of an apparatus in a borehole, and angular rate readings are obtained over time of the rotation. The angular rate readings are adjusted based at least on the angular position readings. The angular position measurement does not require calibrated magnetometers or accelerometers to function. Additionally, a dynamic scale factor calculation for an angular rate gyroscope (ARG) allows the ARG to be used over a much wider operating range than without such a calculation. Finally, an integrated angular rate from the ARG calibrated for bias and scale factor fills in positional information between the magnetometers' zero crossings to deliver a high resolution hybrid angular position system capable of measuring precise angular position at high and irregular downhole rotation rates.

Abstract: A system includes a drillstring with an electromagnetic (EM) transmitter in a first borehole. The system also includes at least one fiber optic sensor deployed in a second borehole. The system also includes a processor configured to determine a distance or direction of the EM transmitter relative to the at least one fiber optic sensor based on EM field measurements collected by the at least one fiber optic sensor in response to an EM field emitted by the EM transmitter.

Abstract: A technique facilitates control over the actuation of a device by utilizing a rotor and a corresponding stator system. The technique employs a rotor and a corresponding stator component in a progressive cavity type system. The rotor and corresponding stator component are mounted such that rotational and/or axial motion may be imparted to at least one of the rotor or stator components relative to the other component. The controlled rotation may be utilized in providing controlled motion of an actuated device via the power of fluid moving through the progressive cavity type system.

Abstract: Locating while drilling systems and methods are disclosed. Some method embodiments include drilling a borehole with a bottom-hole assembly (BHA attached to a drill bit, pausing the drilling to determine a survey position of the bit, obtaining measurements with BHA sensors while drilling, processing the BHA sensor measurements with a model while drilling to track a current position of the bit relative to the survey position, the model accounting for deformation of the BHA, and steering the BHA based on the current position of the bit.

Abstract: A method for selecting a bottomhole assembly, including performing a first dynamic simulation of a first bottomhole assembly, performing at least a second dynamic simulation of the first bottomhole assembly, in which the at least a second dynamic simulation includes a different constraint than the first dynamic simulation, and outputting results for both the first dynamic simulation and the second dynamic simulation, in which the results include at least one output showing performance as a function of position along the bottomhole assembly.

Abstract: Methods of monitoring conditions within a wellbore comprise providing a plurality of signal transmitters and a plurality of signal receivers within the wellbore. Marker materials configured with a particular characteristic may interact with signals generated by the plurality of signal transmitters are introduced into the wellbore. The marker materials interact with the signals, forming modified signals. The modified signals are received by the plurality of signal receivers. The plurality of receivers are configured to measure at least one of acoustic activity and an electromagnetic field to determine a location of the marker materials. The electrical conductivity and the magnetism of produced fluids may also be measured to determine a producing zone of the produced fluid. Downhole systems including the marker materials and also disclosed.

Abstract: Fluid data collected while drilling a wellbore in a drilling operation that includes a first well trajectory is received. A first productivity metric for a next section of the wellbore on a continued trajectory of the first well section trajectory is determined, based at least in part on the fluid data. A second well section trajectory for the next section of the wellbore different from the continued trajectory of the first well section trajectory is determined. A second productivity metric for the second well trajectory is determined. The drilling operation is adjusted if the first productivity index differs from the second productivity index by more than a threshold amount.

Abstract: A mud sag monitoring system may be configured for real-time evaluation of sagging potential of a circulating mud. The monitoring system may include both physics-based sagging prediction models and data-driven sagging detection classifiers that allow for predicting the sagging potential. The sagging potential may also be quantified with a sagging severity index and associated with a specific location within the mud circulation system. The sagging severity and location predictions may provide a framework for mitigation of mud sagging using automatic control techniques.

Abstract: A method for determining a level of organic maturity of a shale gas formation includes inverting multifrequency complex conductivity data to estimate a volume fraction of graphite, turbostatic carbon nanostructures, and pyrite. The inversion is validated using estimates of the volume fraction of graphite, turbostatic carbon nanostructures, and pyrite. The volume fraction of graphite and turbostatic carbon nanostructures is correlated to a level of organic maturity log of the shale gas formation. The level of organic maturity log is validated using sulfur content obtained from pyrolysis or vitrinite reflectance. A variation of an electromagnetic response due to the volume fraction of graphite, turbostatic carbon nanostructures, and pyrite is quantified. The electromagnetic response is modified by removing the quantified variation to obtain resistivity and permittivity values.

Abstract: Systems and methods for determining manufacturing or operating parameters for a deviated downhole well component, including a method that includes representing a tubular string as nodes separated by segments, determining transfer matrices for determining an ith node's state vector from an ith?1 node's state vector, and defining initial state vector values for the reference node. The nodes are numerable from 1 to N with an initial, mechanically constrained reference node representable with i=0, and each is associated with a state vector describing a corresponding node position and one or more forces present at said node. The method further includes applying the transfer matrices to obtain each of the state vectors' values, deriving from at least one of the state vectors a parameter value for said component, and specifying a component having said parameter value. The parameter value can include a centralizer or stabilizer composition, manufacturing dimensions, or position.

Abstract: A downhole tool measurement device mounting system includes a chassis with a body and a chassis axis extending through the body. A monolithic assembly is mounted on the body of the chassis. The monolithic assembly includes a sensor mounted in a block. The monolithic assembly is mounted on the body of the chassis parallel to the chassis axis such that a sensing axis of the sensor is offset from a center of the body of the chassis.

Abstract: The present disclosure relates to a system, apparatus and method for guiding a drill bit based on forces applied to a drill bit, and drilling methods related to same.

Abstract: Techniques for controlling a bottom hole assembly (BHA) in a wellbore include determining a model of BHA dynamics; determining a predicted wellbore trajectory, based on the model of BHA dynamics; and determining an uncertainty of the predicted wellbore trajectory.

Abstract: A computer-based method of generating a survey of a wellbore section is provided. The method includes analyzing a plurality of surveys of the wellbore section to identify survey measurements that do not comprise gross errors, generating an initial weighted average survey, and calculating an initial set of measurement differences between the identified survey measurements and the initial weighted average survey. The method further includes calculating a plurality of error term estimates for the plurality of surveys and using the plurality of error term estimates to correct the identified survey measurements. The method further includes generating an updated weighted average survey and calculating an updated set of measurement differences between the identified survey measurements and the updated weighted average survey.

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

Abstract: The present invention is directed to tracking a borehole drilling direction and magnetic azimuth and orienting the tool face which controls the direction of drilling in a generally horizontal path between a specified borehole entry point and a predetermined exit location. The generally horizontal path may be disposed under a geographic obstacle such a river, a highway, a railroad, or an airport runway wherein the ground above the borehole is difficult or impossible to access.

Abstract: A technique facilitates control over the actuation of a device by utilizing a rotor and a corresponding stator system. The rotor is rotatably mounted in the stator system, and rotation of the rotor relative to the stator system is correlated with the volumetric displacement of the fluid passing between the rotor and the stator system. A control system is employed to control the angular displacement and/or torque of the rotor and/or the flow of fluid thereto.

Abstract: An apparatus and method for creating axial movement of a drill string using a variable valve and a controller. In some embodiments, the controller is a proportional-integral-derivative controller.

Abstract: The present invention is directed to a system that has a first sensor assembly coupled to a mobile platform that traverses a predetermined subsurface path and has an axis of motion. The first sensor assembly obtains a gravity vector of the Earth relative to the mobile platform. A second sensor assembly is disposed in substantial alignment with a predetermined position relative to the axis of motion and is characterized by a sensitivity axis. The second sensor assembly provides a sensor signal substantially corresponding to a single vector component of the Earth's rotation vector. A control system is configured to derive the path direction relative to a known direction and an inclination angle of the mobile platform relative to the surface based on the gravity vector and the single vector component of the Earth's rotation vector.

Abstract: A well advisor system and console for monitoring and managing drilling operations at a well site. The system may be accessed through one or more workstations, or other computing devices, which may be located at a well site or remotely. The system is in communication with and receives input from various sensors. It collects real-time sensor data sampled during operations at the well site. The system processes the data, and provides nearly instantaneous numerical and visual feedback through a variety of graphical user interfaces (“GUIs”), which are presented in the form of an operation-specific console. The input and data provides information related to drilling operations at a well site, including, but not limited to, hole cleaning status and wellbore stability.

Abstract: A magnetic ranging system utilizes the natural shape of magnetic fields for steering and/or landing of one wellbore in relation to another wellbore.

Abstract: A steering tool is movable by a drill string to form an underground bore along an intended path. A sensing arrangement of the steering tool detects its pitch and yaw orientations at a series of spaced apart positions along the bore, each position is characterized by a measured extension of the drill string. The steering tool further includes a receiver. At least one marker is positioned proximate to the intended path, for transmitting a rotating dipole field to expose a portion of the intended path to the field for reception by the receiver. The detected pitch orientation, the detected yaw orientation and the measured extension of the drill string are used in conjunction with magnetic information from the receiver to locate the steering tool. The steering tool may automatically use the magnetic information when it is available. A customized overall position determination accuracy can be provided along the intended path.

Abstract: A method for conducting survey measurements in a ranging operation between a first well and a second well include generating an electromagnetic field in a downhole location in the first well and scanning for the electromagnetic field in a downhole location in the second well. When at least one characteristic of the electromagnetic field is detected, the method includes automatically initiating survey measurements for a ranging operation without receiving a downlink command from surface.

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

Abstract: A downhole system has a plurality of telemetry systems and a control system configured to obtain information from one or more sensors and transmit that information on one or more of the plurality of telemetry systems. The configuration of a controller may be changed so as to change which information is transmitted on a given telemetry system and how the information is to be transmitted on the given telemetry system.

Abstract: Described is a system for position estimation. A set of raw sensor outputs are acquired from a sensor of a platform. The set of raw sensor outputs are stored in non-transitory memory. A set of optimized sensor measurements is generated by deducing errors in the raw sensor outputs using an unconstrained optimization algorithm. The system determines a position of the platform based on the set of optimized sensor measurements.

Abstract: Techniques for controlling downhole drilling equipment include determining a nominal model of downhole drilling dynamics based on sensor measurements from the downhole drilling equipment; determining an uncertainty for the nominal model of downhole drilling dynamics; determining, based on the uncertainty for the nominal model of downhole drilling dynamics, a set of models that deviate from the nominal model of downhole drilling dynamics; and generating a virtual controller for the downhole drilling equipment based on the nominal model and the set of models that deviate from the nominal model.