Abstract: A method of detecting wear of a downhole tool implemented in a subject wellbore includes receiving offset wellbore data for one or more offset wellbores and, based on the offset wellbore data, determining an expected downhole tool index for the downhole tool at one or more measurement depths including an active measurement depth of the subject wellbore. The method further includes receiving subject wellbore data and, based on the subject wellbore data, determining a subject downhole tool index in real time for the downhole tool at the active measurement depth. The method further includes determining the wear of the downhole tool based on comparing the subject downhole tool index to the expected downhole tool index at the active measurement depth in real time.

Abstract: The present disclosure provides a gate driving circuit, a display panel, a driving method and a display device. The gate driving circuit includes an input module, a pull-up node, an output module, a first pull-down node, a first pull-down node control module and a first suppression module. The first pull-down node control module controls to connect the first connection node and the first pull-down node under the control of the pull-up node, and inputs the signal provided by the second signal terminal to the first pull-down node under the control of the potential of the first pull-down node; the first suppression module inputs the signal provided by the first level signal terminal to the first connection node under the control of the pull-up node.

Abstract: Provided in embodiments of the disclosure are a driving method for a display panel, and a display apparatus. A display frame includes a data refresh phase and a blanking time phase. The driving method for the display panel includes: in the data refresh phase, loading a clock signal including an active level and an inactive level to a gate driving circuit in a display panel to cause a gate line to load a gate-on signal, loading display data to a source driving circuit in the display panel to cause a data line to load a data voltage, and determining a current operating state of the display panel; and in the blanking time phase, loading a clock signal including an inactive level to the gate driving circuit in the display panel to cause the gate line to load a gate-off signal, and sending the current operating state of the display panel.

Abstract: Provided in embodiments of the disclosure are a driving method for a display panel, and a display apparatus. A display frame includes a data refresh phase and a blanking time phase. The driving method for the display panel includes: in the data refresh phase, loading a clock signal including an active level and an inactive level to a gate driving circuit in a display panel to cause a gate line to load a gate-on signal, loading display data to a source driving circuit in the display panel to cause a data line to load a data voltage, and determining a current operating state of the display panel; and in the blanking time phase, loading a clock signal including an inactive level to the gate driving circuit in the display panel to cause the gate line to load a gate-off signal, and sending the current operating state of the display panel.

Abstract: A system and method that include receiving drilling dynamics data simulated by a processor and drilling dynamics data collected by a sensor positioned in a drilling tool and extracting a feature map based on a combination of the drilling dynamics data simulated by the processor and the drilling dynamics data collected by the sensor positioned in the drilling tool. The system and method additionally include determining a feature zone from the feature map. The system and method further include selecting a drilling parameter for a drill string based on the feature zone.

Abstract: A method may include generating an optimal operational window (OOW) that specifies operational parameter values for drilling operations using equipment at a rig site, based on data indicative of rig state and formation characteristics, and based on mutation-based optimization of the operational parameter values; and instructing a control system to perform the drilling operations according to the OOW using the equipment at the rig site.

Abstract: A method can include receiving real-time data during a drilling operation performed by a drillstring that includes a mud motor and a bit characterized by an expected performance profile; determining actual performance of the drillstring based at least in part on the real-time data; predicting degraded performance of the drillstring based at least in part on the real-time data and a mud motor degradation model; and updating the expected performance profile based on a comparison of the actual performance and the degraded performance.

Abstract: Methods, computing systems, and computer-readable media for interpreting drilling dynamics data are described herein. The method can include receiving drilling dynamics data simulated by a processor or collected by a sensor positioned in a drilling tool. The method can further include extracting a feature map from the drilling dynamics data, and determining that a feature zone from the feature map corresponds to a predetermined dynamic state. The feature zone can be determined using a neural network trained to associate feature zones with dynamic states. Additionally, the method can include selecting a drilling parameter for a drill string based on the feature zone.

Abstract: A method for determining tortuosity, e.g., in an oilfield well includes obtaining a planned trajectory for a hole, and obtaining a first survey of the hole using a sensor deployed into the hole. The first survey includes a first surveyed position at a first depth of the hole and a second surveyed position at a second depth of the hole, and no surveyed positions between the first and second depths. The method further includes simulating a second survey of the hole between the first and second depths using a model. The second survey includes a plurality of simulated positions of the hole between the first and second depths. The method includes determining that the simulated position at the second depth is proximal to the second surveyed position, and visualizing a trajectory of the hole based on the first and second surveys.

Abstract: A method for evaluating one or more bottom hole assemblies (BHAs) includes receiving a plurality of inputs. The inputs include one or more properties of the one or more BHAs, a planned trajectory of a wellbore, and one or more properties of a subterranean formation into which the wellbore will be drilled. The method also includes simulating drilling the wellbore in the subterranean formation based at least partially upon the inputs. Drilling of the wellbore is simulated with one or more artificial intelligence (AI) agents. Drilling of the wellbore is simulated a plurality of times using each of the one or more BHAs, thereby producing a plurality of simulations. Each simulation is generated using a different one of the AI agents. The method also includes generating one or more outputs in response to simulating drilling the wellbore.

Abstract: A motor bypass valve diverts drilling fluid away from a downhole motor when the motor is off bit. Bypassing the downhole motor reduces the shock and vibration on the BHA caused by the downhole motor, thereby reducing the damage to the BHA. The motor bypass valve may divert fluid out of a housing or into a bore through the rotor of the downhole motor.

Abstract: A method can include receiving data for a borehole trajectory in a formation, a length of pipe, and a bottom hole assembly that includes a mud motor and a bit; generating a sequence for operation of the mud motor using a model of at least the bit, where the sequence includes a sliding mode and a rotary mode for drilling the borehole in the formation a distance less than or equal to the length of pipe; and drilling the borehole according to the sequence.

Abstract: The present disclosure provides a display panel, a display device and manufacturing method of the display panel. The display panel includes a display area and a peripheral area located at a periphery of the display area, a light transmittance region is provided in the peripheral region; at least one first sub-pixels is provided at positions corresponding to the light transmittance regions, wherein at least one of the first sub-pixels is provided with a first thin film transistor, the first thin film transistor is connected with the first gate line, the first data line, and the first pixel electrode, wherein the first gate line is floating; a first pixel electrode is disposed in at least one of the first sub-pixels; and at least one first sensing electrode has an orthogonal projection on a base substrate partially overlapped with an orthogonal projection of the at least one first sub-pixel.

Abstract: A method for determining tortuosity, e.g., in an oilfield well includes obtaining a planned trajectory for a hole, and obtaining a first survey of the hole using a sensor deployed into the hole. The first survey includes a first surveyed position at a first depth of the hole and a second surveyed position at a second depth of the hole, and no surveyed positions between the first and second depths. The method further includes simulating a second survey of the hole between the first and second depths using a model. The second survey includes a plurality of simulated positions of the hole between the first and second depths. The method includes determining that the simulated position at the second depth is proximal to the second surveyed position, and visualizing a trajectory of the hole based on the first and second surveys.

Abstract: A method can include receiving data for a borehole trajectory in a formation, a length of pipe, and a bottom hole assembly that includes a mud motor and a bit; generating a sequence for operation of the mud motor using a model of at least the bit, where the sequence includes a sliding mode and a rotary mode for drilling the borehole in the formation a distance less than or equal to the length of pipe; and drilling the borehole according to the sequence.

Abstract: A motor bypass valve diverts drilling fluid away from a downhole motor when the motor is off bit. Bypassing the downhole motor reduces the shock and vibration on the BHA caused by the downhole motor, thereby reducing the damage to the BHA. The motor bypass valve may divert fluid out of a housing or into a bore through the rotor of the downhole motor.

Abstract: Methods, computing systems, and computer-readable media for interpreting drilling dynamics data are described herein. The method can include receiving drilling dynamics data simulated by a processor or collected by a sensor positioned in a drilling tool. The method can further include extracting a feature map from the drilling dynamics data, and determining that a feature zone from the feature map corresponds to a predetermined dynamic state. The feature zone can be determined using a neural network trained to associate feature zones with dynamic states. Additionally, the method can include selecting a drilling parameter for a drill string based on the feature zone.

Abstract: Embodiments of the present disclosure provide a reading apparatus for an X-ray detector, a method for using the reading apparatus, and the X-ray detector. The reading apparatus includes a control circuit, a compensation circuit, and a processing circuit. The control circuit is configured to provide, in a first phase, a first signal to an input terminal of the compensation circuit according to a reference signal and a dark current in a sense device of the X-ray detector, and provide, in a second phase, a second signal from the sense device to the input terminal of the compensation circuit. The compensation circuit is configured to generate, in the first phase, a compensation signal according to the first signal, and compensate, in the second phase, the second signal according to the compensation signal, to generate a third signal. The processing circuit is configured to process the third signal.

Abstract: A method can include receiving a maximum depth of cut value of a bit that accounts for bit body formation engagement; receiving a total revolution rate value for the bit that is based at least in part on a differential pressure value of a mud motor; generating a rate of penetration value for the bit as operatively coupled to the mud motor by multiplying the maximum depth of cut value and the total revolution rate value; and operating a rigsite system according to the rate of penetration value for drilling a portion of a borehole using the bit as operatively coupled to the mud motor.

Abstract: A method can include receiving a maximum depth of cut value of a bit that accounts for bit body formation engagement; receiving a total revolution rate value for the bit that is based at least in part on a differential pressure value of a mud motor; generating a rate of penetration value for the bit as operatively coupled to the mud motor by multiplying the maximum depth of cut value and the total revolution rate value; and operating a rigsite system according to the rate of penetration value for drilling a portion of a borehole using the bit as operatively coupled to the mud motor.