Abstract: A method for calculating a velocity model for a subsurface of the earth. The method includes receiving (200) measured seismic data d; calculating (204) predicted seismic data p; selecting (206) a matching filter w that when applied to one of the measured seismic data d or the predicted seismic data p reproduces the other one of the measured seismic data d or the predicted seismic data p; selecting (208) a misfit function J that calculates (1) a distance between the matching filter w and a Dirac Delta function or (2) a travel time shift associated with the measured seismic data; and calculating (218) a new velocity model using the misfit function J, the measured seismic data d, and the predicted seismic data p. The measured seismic data d includes wavefields generated by a seismic source and the wavefields propagate through the subsurface where they are attenuated and reflected, and the attenuated and reflected wavefields are recorded by plural seismic receivers.

Abstract: A diagnosis device includes a first acquisition unit, a second acquisition unit, and an associating unit. The first acquisition unit is configured to acquire, from a machine tool, context information including at least a monitoring specifying number identifying a machining process. The second acquisition unit is configured to acquire detection information output from a detection unit installed for the machine tool. The associating unit is configured to associate the monitoring specifying number included in the context information acquired by the first acquisition unit and the detection information acquired by the second acquisition unit.

Abstract: The present invention discloses a three-dimensional in-situ characterization method for heterogeneity in generating and reserving performances of shale. The method includes the following steps: establishing a logging in-situ interpretation model of generating and reserving parameters based on lithofacies-lithofacies-well coupling, and completing single-well interpretation; establishing a 3D seismic in-situ interpretation model of generating and reserving parameters by using well-seismic coupling; establishing a spatial in-situ framework of a layer group based on lithofacies-well-seismic coupling, and establishing a spatial distribution trend framework of small layers of a shale formation by using 3D visualized comparison of a vertical well; and implementing 3D in-situ accurate characterization of shale generating and reserving performance parameters by using lithofacies-well-seismic coupling based on the establishment of the seismic-lithofacies dual-control parameter field.

Abstract: Methods for inversion of seismic data to infer subsurface physical property parameters, comprising constructing an inhomogeneous anisotropy model and/or inhomogeneous VS/VP or VP/VS model; and inverting the seismic data in a sequential or simultaneous approach to obtain at least one subsurface physical property parameter using an elastic inversion algorithm and the inhomogeneous anisotropy model and/or inhomogeneous VS/VP or VP/VS model. Constructing an inhomogeneous anisotropy model may comprise deriving geobodies from at least one of seismic facies analysis, regional geologic information, or seismically derived earth models; and adjusting at least one of ?, ?, ?, or parameters of the elastic stiffness tensor matrix in a homogeneous anisotropy model in areas corresponding to the geobodies. Constructing an inhomogeneous VS/VP or VP/VS model may comprise deriving geobodies and adjusting values in a homogeneous VS/VP or VP/VS model in areas corresponding to the geobodies.

Abstract: A fluid dispensing device and method for controlling the device are provided. The device includes a housing defining a fluid outlet. A valve controls the flow of fluid to the outlet. A sensor is configured to detect an object outside of and proximate to the housing. A solenoid is configured to move the valve between an open position and a closed position. A controller is configured to receive the output signal of the sensor, determine a characteristic of noise in the output signal such as a level of noise, adjust at least one of a sampling rate of the output signal and an amount of filtering of the output signal responsive to the characteristic of noise in the output signal, and transmit a control signal to the solenoid responsive to the output signal.

Abstract: A position-measuring device includes a measuring transducer configured to carry out a position measurement. The position-measuring device has at least one memory having stored parameter data defining an active configuration under which the position-measuring device is operable. The at least one memory further has data and instructions useable to activate at least one further configuration under which the position-measuring device is operable.

Abstract: In accordance with one or more implementations of the apparatus, system and methods described, a sample measurement device is provided that is configured to measure the color of a sample. The sample measurement device includes at least one light source configured to illuminate the sample; at least one light sensor configured to output a signal in response to light emitted by light source and reflected off the sample being received by at least a portion of the light sensor; and a processor configured to receive the signal and calculate a color value for the sample, the processor configured to calculate the color value by at least adjusting the signal using a calibration factor.

Abstract: Embodiments of the present disclosure include methods, apparatuses, systems, and computer program product for enabling multi-point shunt calibration of a sensor device. Multi-point shunt calibration provides at least a first, second, and third simulated calibration output, each simulated calibration output corresponding to an actual reading value and an expected reading value. The simulated calibration outputs are associated with a predefined output sequence, where each simulated calibration output is separated from an adjacent simulated calibration output by an output step size. Some embodiments are configured for automatically outputting each simulated calibration output for a particular period of time before outputting an adjacent simulated calibration output in the predefined output sequence. The various simulated calibration outputs, actual reading values, and/or expected values may be used in determining calibrated reading values for the sensor device.

Abstract: Aircraft air data is estimated using a neural network trained to be independent of any signals from air data sensors whose values are based on air flow pressure measurements.

Abstract: Systems and methods for determining mechanical properties of anisotropic media are disclosed. A method for determining mechanical properties of an anisotropic media includes obtaining log data of the anisotropic media, the log data corresponding to measurements of the anisotropic media collected with a logging tool; determining values for a plurality of first stiffness components of a stiffness matrix based on horizontal and vertical velocities derived from the log data; determining an upper bound for a second stiffness component of the stiffness matrix based on the values for the plurality of first stiffness components; estimating a value for the second stiffness component based on the determined upper bound; determining a mechanical property of the anisotropic media based on the estimated value of the second stiffness component; and providing the determined mechanical property.

Abstract: A method includes receiving, via a processor, a first seismic dataset generated using a first type of survey system. The method further includes receiving, via the processor, a second seismic dataset generated using a second type of survey system. The method additionally includes determining a frequency band in which to combine the first seismic dataset with the second seismic dataset to generate a combined dataset and generating a seismic image based upon the combined dataset, wherein the seismic image represents hydrocarbons in a subsurface region of the Earth or subsurface drilling hazards.

Abstract: Strain and time-strain measurement in a well enables derivation of a constant that links the two. Knowledge of the constant along with time-strain measurement at another well enables estimation of strain at the other well.

Abstract: Systems and methods for generating pressure data from at least two pressure sensors, storing one or more parameters indicative of water cut in a neural network model, receiving pressure data from at least the two pressure sensors respectively indicative of the pressure at two points of a well bore, determining a pressure drop between the two points, generating an input water cut estimate, estimating a dynamic pressure loss to initiate an iterative process, estimating a potential energy loss, inverse modeling a water cut estimate, comparing the water cut estimate to the input water cut estimate to generate a water cut ?, utilizing the water cut estimate as the input water cut estimate for the iterative process when the water cut ? exceeds a threshold, and continuing the iterative process until the water cut ? is below the threshold.

Abstract: In a method to transform logs, an acoustic logging tool inserted into a borehole includes a source and an array of receiver stations. Each station includes a receiver spaced along the tool from the source by successively greater distances. In the method, the source emits energy (I) to cause the propagation towards the stations of plural signals exhibiting paths characteristic of first and second respective modes and (II) to stimulate a receiver of each station to generate an output signal per station that indicates the signal packets and represents the modes in combination with one another. In the method, the output signals are transformed into transformed signals containing phase/amplitude information of each mode. The phase/amplitude are linked by an operator to the slowness and attenuation of the mode and the transmitter-receiver distance of the station. The phase/amplitude are used to extract slowness and attenuation information for each mode.

Abstract: A method or system is configured for determining a seismic attenuation quality factor Q for intervals of subsurface formations by performing actions including receiving vertical seismic profile traces. The actions include filtering the vertical seismic profile traces with an inverse impulse response of a downhole receiver. The actions include transforming the vertical seismic profile data from the particle motion measured by the downhole receiver to the far-field particle motions represented by the source wavelet. The actions include determining a ratio of the spectral amplitudes of the direct arrival event of the transformed vertical seismic profile data and the source Klauder wavelet. A quality factor Q is generated representing an attenuation of the seismic signal between the source at ground level surface and the downhole receiver.

Abstract: A non-transitory computer-readable storage medium stores instructions, which when executed by a processing device of a diagnostic server, cause the processing device to perform certain operations. The operations include receiving, from a processing chamber, (i) measurement values of a combined signal that is based on an injection of an alternating signal wave onto a first output signal of a controller of the processing chamber, and (ii) measurement values of a second output signal of the controller that incorporates feedback from the processing chamber. The operations further include generating, based on the measurement values of the combined signal and the measurement values of the second output signal of the controller, a baseline bode fingerprint pertaining to a state associated with the processing chamber. The operations further include storing, in computer storage, the baseline bode fingerprint to be used in performing diagnostics of the processing chamber.

Abstract: Disclosed are methods, systems, and computer-readable medium to perform operations including: receiving seismic data acquired by at least one receiver of a geologic survey system configured to perform a geologic survey of a subterranean formation, wherein the seismic data is associated with reflected acoustic signals generated by at least one source of the geologic survey system; calculating a ground force signal by stacking the acoustic signals generated by the least one source; calculating, using the ground force signal, a time and depth variant quality factor (Q) of the subterranean formation; and compensating, based on the time and depth variant Q, attenuation in the seismic data.

Abstract: A residual thermal strain distribution measurement method of measuring a residual thermal strain distribution as residual thermal deformation in a sample generated under application of a thermal load, comprises recording images of a periodic pattern present on the surface of the sample by an image recording unit at a first temperature and a sample formation temperature at which the sample is formed, generating moire fringes based on each recorded image of the periodic pattern, calculating a phase of the moire fringes for the sample at the first temperature, calculating a phase of the moire fringes for the sample at the sample formation temperature, acquiring a phase difference of the moire fringes at the sample formation temperature with respect to the first temperature, and calculating a residual thermal strain of the sample at the first temperature with respect to the sample formation temperature based on the acquired phase difference.

Abstract: Power management techniques in distributed communication systems are disclosed herein. Related components, systems, and methods are also disclosed. In embodiments disclosed herein, services within a remote unit of the distributed communication system are selectively activated and power consumption is measured. From at least two measurements, a maximum power available may be calculated and compared to power requirements of the remote unit.

Abstract: Disclosed herein is a quantifying method of uncertainty of measured value by close match span calibration of measuring sensor comprising a step of: a quantifying using below equation I. u c ( x bag ) ? [ 1 f cyl ? u ? ( R bag ) ] 2 + [ 1 f cyl ? u ? ( R cyl ) ] 2 + u 2 ( x cyl ) ( I ) wherein, uc is a combined standard uncertainty, Xbag is a measured value of a test, xcyl is standard value, fcyl is standard response factor (sensitivity coefficient), Rbag is a signal value of a test, represents xbag·fbag, Rcyl represents xcyl·fcyl, and u is standard uncertainty.