Abstract: A demarcating system is discussed that includes a control system, a wire loop arrangeable by a user to indicate to an object path as part of a boundary of an area: a signal generator controlled by the control system, wherein voltage signals applied by the signal generator to the loop are controlled by the control system; and current sensing circuitry that senses current signals present within the loop wherein processors of the control system analyse such current signals and—operate in a calibration mode to: cause the signal generator to apply to the loop a series of test voltage waveforms that generate corresponding current waveforms within the loop; and analyse the corresponding current waveforms to determine an operating voltage waveform that, when applied to the loop, generates a corresponding operating current waveform with substantially the same shape as a predetermined current waveform.

Abstract: A tilt detecting unit has a tilt sensor and is rotatably supported by an inner frame through a second shaft orthogonal to a first shaft, a first encoder is provided on the first shaft, a second encoder is provided on the second shaft, motors are provided on the respective shafts, an arithmetic processing module drives the respective motors so that the tilt sensor detects the horizontality based on a signal issued by the tilt sensor, calculates a tilt of the outer frame based on the outputs from the first and second encoders when the tilt sensor detects the horizontality, reverses the tilt detecting unit 180° at least once based on the outputs from the respective encoders in a stationary state of the tilt detecting device, and performs the calibration of the tilt sensor based on the detection signals output from the tilt sensor before and after the reversal.

Abstract: Noise in drilling operation measurements can be eliminated or reduced using machine learning. For example, a system described herein can receive one or more measured signals in a logging-while-drilling process for drilling a wellbore. The system can determine a coupling factor for noise in the one or more measured signals. The system can generate a corrected signal by removing the noise multiplied by the coupling factor from the one or more measured signals. The system can output the corrected signal for use in drilling operations in the wellbore.

Abstract: A microelectromechanical gyroscope which comprises one or more Coriolis masses driven by a drive transducer and a force-feedback system. The force-feedback circuit comprises first and second sideband modulators and the self-test circuit comprises first and second sideband demodulators.

Abstract: A method for offset well analysis includes receiving offset well data collected from an offset well, the offset well data including data representing a trajectory of an offset well, receiving subject well data comprising a trajectory of at least a portion of a subject well, partitioning the trajectory of the offset well into a plurality of offset well segments, partitioning the trajectory of the subject well into a plurality of subject well segments, determining a distance between at least some of the plurality of offset well segments and at least some of the plurality of subject well segments, selecting the offset well based in part on the distance, and performing an offset well analysis using the offset well and the subject well.

Abstract: A method may include obtaining power production and fuel consumption data of a first piece of rig equipment through a flow meter, where the rig equipment includes a plurality of pieces of equipment. The method further includes feeding the power production and fuel consumption data of the first piece of rig equipment into a real-time monitoring system of the rig via the flow meter. The method further includes determining an energy efficiency, based on real-time performance, of the first piece of rig equipment using a consumption efficiency model. The method further includes comparing the energy efficiency of the first piece of rig equipment against continuously updated historical data of the first piece of rig equipment by a real-time database monitoring system. The method further includes identifying deficiencies of the first piece of rig equipment in real-time and determining maintenance or replacement of the first piece of rig equipment.

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: A fault diagnosis unit (42) of a fault diagnosis apparatus (4) performs a fault diagnosis of a communication network (2) with a probabilistic inference algorithm using information on the communication network (2) having been gathered by an NW monitoring unit (41). A diagnosis result determining unit (43) determines test items for confirming and determining a diagnosis result of the fault diagnosis. A test performing unit (44) performs a confirmation test of the determined test items. The diagnosis result determining unit (43) determines a likelihood of the diagnosis result of the fault diagnosis based on a result of the confirmation test.

Abstract: A method may include obtaining a real-time petrophysical data derived from a plurality of well logs during drilling and utilizing the real-time petrophysical data to quantify a formation damage profile using a resistivity tornado chart and a wellbore modeling. The method further includes utilizing the resistivity tornado chart to determine a depth of invasion inside a formation at each depth in a wellbore by using ratios between different resistivity logs obtained while drilling and creating a synthetic wellbore model by using a fluid flow equation for the wellbore modeling and calculating a time-specific invasion profile to determine a condition at a flowback time. The method further includes performing a computational fluid dynamics investigation in order to identify invaded fluid flow characteristics from the formation to the wellbore and calculating a duration needed to flowback an obtained invaded volume for removal of the formation damage based on a fluid flow behavior.

Abstract: Systems and methods for evaluating simulation models are disclosed. In one embodiment, a method of evaluating a simulation model of a hydrocarbon field includes merging simulated reservoir data and actual reservoir data to generate merged reservoir data, and cross-linking the merged reservoir data with three-dimensional model data. The method further includes calculating one or more surface metrics from at least one of the merged reservoir data and the three-dimensional model data, calculating one or more subsurface metrics from at least one of the merged reservoir data and the three-dimensional model data, and calculating one or more overall history match indicators, one or more surface history match indicators, and one or more subsurface history match indicators from the one or more surface metrics, the one or more subsurface metrics, and the three-dimensional model data.

Abstract: Methods for determining an in-situ pore pressure in a formation rock may include acquiring well log data, calculating a cation-exchange capacity, calculating a mole fraction of fixed charges using the cation-exchange capacity, determining a formation temperature, calculating the in-situ pore pressure, outputting the in-situ pore pressure of the formation rock, and using the in-situ pore pressure in a wellbore stability model to monitor and maintain stability of the formation rock. Corresponding electronic devices may include a computer processor coupled to at least one logging tool, wherein the logging tool is configured to acquire well log data in a formation rock. Non-transitory computer storage mediums may include program instructions, that when executed, may be configured to perform the methods for determining an in-situ pore pressure in a formation rock.

Abstract: A camera testing system for determining performance of a camera comprising an imaging sensor and a lens, the system comprising a processing system comprising at least one processor and memory. The processing system may be configured to: control the camera to capture, using the imaging sensor, a first image through the lens of a target disposed at a first distance from the camera; determine a first modulation transfer function (MTF) value from the first image; control the camera to capture, using the imaging sensor, a second image through the lens of the target disposed at a second distance from the camera that is different from the first distance; determine a second MTF value from the second image; and determine performance of the camera based on the first MTF value, the second MTF value and a difference between the first MTF value and the second MTF value.

Abstract: A power calculation apparatus includes a microprocessor and a memory. The microprocessor is configured to perform: acquiring a power amount information regarding amounts of power input to and output from a plurality of vehicles, the amounts of power being detected by a plurality of measuring instruments provided in the plurality of vehicles or interposed between a power grid and the plurality of vehicles; classifying the plurality of measuring instruments based on errors possessed by the plurality of measuring instruments to set a plurality of groups; and calculating a total power input and output in each of the groups, based on the power amount information. The setting the plurality of groups includes setting the plurality of groups such that a mean value of errors of amounts of power in the groups is a predetermined value or less.

Abstract: The disclosed embodiments relate to a system that automatically adapts a prognostic-surveillance system to account for aging phenomena in a monitored system. During operation, the prognostic-surveillance system is operated in a surveillance mode, wherein a trained inferential model is used to analyze time-series signals from the monitored system to detect incipient anomalies. During the surveillance mode, the system periodically calculates a reward/cost metric associated with updating the trained inferential model. When the reward/cost metric exceeds a threshold, the system swaps the trained inferential model with an updated inferential model, which is trained to account for aging phenomena in the monitored system.

Abstract: A method for detecting actual slip in a coupling of a rotary shaft, for example, in a wind turbine power system, includes monitoring, via a controller, a plurality of sensor signals relating to the coupling for faults. In response to detecting a fault in the plurality of sensor signals relating to the coupling, the method includes determining, via the controller, whether the fault is indicative of an actual slip or a no-slip event of the coupling using one or more classification parameters. When the fault is indicative of the actual slip, the method includes estimating, via the controller, a magnitude of the actual slip using the plurality of sensor signals and a time duration of the actual slip. Further, the method includes implementing, via the controller, a control action based on the magnitude of the actual slip in the coupling.

Abstract: A method is described for measuring workpieces, each having structural features that form test features for measurement. The method determines an unstable one and a stable one of the test features, based on expected violation or satisfaction, respectively, of a statistical control rule. The method measures workpieces such that the unstable test feature is measured more frequently than the stable test feature. The method ascertains whether the unstable test feature remains unstable and whether the stable test feature remains stable. The method measures additional workpieces if the unstable test feature remained unstable and the stable test feature remaining stable. The determining is repeated if the unstable test feature is no longer unstable, the stable test feature is no longer stable, or any other measurement feature changes, such as if a new batch of workpieces is to be measured, environmental conditions change, or measurement has proceeded longer than a predefined threshold.

Abstract: A method for discovering an unexploded ordnance in a target area includes: acquiring first feedback signals respectively corresponding to detection regions, the first feedback signals being first induced electromotive force signals; judging whether there is any abnormal signal in the first feedback signals, if there is the abnormal signal, determining the detection region corresponding to the abnormal signal is an abnormal region; acquiring second feedback signals respectively corresponding to detection sites in the abnormal region, the second feedback signals being magnetic field gradient signals; acquiring third feedback signals respectively corresponding to the detection sites, the third feedback signals being second induced electromotive force signals; acquiring location information of the detection sites; obtaining a feature spatial distribution map of the abnormal region; and judging whether there is any unexploded ordnance in the abnormal region according to the feature spatial distribution map.

Abstract: A method for detecting positions of wafers includes: rotating a rotation table with a wafer thereon in a first direction at a first speed; detecting a contour of the wafer rotating in the first direction at the first speed to provide contour data; rotating the rotation table in a second direction at a second speed when an aiming feature of the wafer passes the detector in the first direction at the first speed; detecting the contour of the wafer rotating in the second direction at the second speed to provide new contour data; and stopping the rotation of the rotation table and the detection of the wafer according to an accumulation of contour data and corresponding rotation angles, to estimate an eccentric position of the wafer and a position of the aiming feature when the aiming feature passes the detector in the second direction at the second speed.

Abstract: Actions, such as effects and adverse-events, of a test substance in humans are predicted by using an artificial intelligence model trained by a method for training an artificial intelligence model, the method including inputting into the artificial intelligence model a set of first training data and second training data or a set of the second training data to train the artificial intelligence model.

Abstract: Apparatus and methods can be implemented to monitor the condition of the production and intermediate casing strings in oil and gas field operations. A series of measurements can be made in a multi-pipe structure and received responses can be operated on by employing a mapping optimization procedure in which a surrogate model is updated. Estimates of one or more properties of the pipes of the multi-pipe structure can be generated using coefficients of the updated surrogate model. Additional apparatus, systems, and methods are disclosed.