Abstract: A method for determining the shape and position of an underwater riser extending from a floating platform includes calculating a deformed shape of the riser by means of a numerical model of the deformed shape of the riser as a function of a plurality of acceleration values and of a plurality of position values in predetermined points of the riser, detecting acceleration values of the riser in a plurality of detection points along a longitudinal extension of the riser, detecting the water pressure values in at least some of the detection points, and calculating the position values as a function of the measured water pressure values.

Abstract: Provided is a pile integrity detection system based on cross-hole sonic logging method. The operator sets the ultrasonic detector into the measuring tubes of the to-be-detected pile, subsequently inputs the project data and activate the ultrasonic detector, by an acoustic wave transmission among a transmitter and a receiver, a wave energy data of the to-be-detected pile can be obtained, and the wave energy data and a project data will be automatically transmitted to the cloud computing module, thereby the integrity level of the to-be-detected pile can be determined without any manual analysis to the wave energy data, preventing from any error or deflection due to manual operation, whereby it greatly improves the accuracy and efficiency of detection and reduces the error rate.

Abstract: In order to accurately probe a structure of concrete, a series of probe signals with defined carrier frequencies are generated by a probe signal generator and coupled into the structure by an antenna. The returning echo signals are processed by an echo signal receiver. Processing includes phase and amplitude detection in a multiplier, frequency-specific scaling in a scaling unit, replacement of the measured phases and amplitudes in an interpolation unit, and the generation of time-domain data in a Fourier transformation module. The device is robust against RF noise, accurate and low-power.

Abstract: A method of fluid substitution, wherein an initial data set is provided, wherein a substituted data set is provided, wherein a rock physics model is provided, wherein the initial data set includes initial data of a geophysical parameter and initial fluid data, and wherein the substituted data set includes substituted fluid data. The method includes using the model and the initial data set to calculate first calculated data of the geophysical parameter, using the model and the substituted data set to calculate second calculated data of the geophysical parameter, calculating the difference between the first calculated data of the geophysical parameter and the second calculated data of the geophysical parameter, and applying the difference to the initial data of the geophysical parameter to produce substituted data of the geophysical parameter.

Abstract: The present invention a method for determining the gas saturation of a tight reservoir. The method comprises the steps of: determining the pore size distribution of the tight reservoir rock sample, and calculating the free water saturation; calculating the water-membrane water saturation; calculating the corner water saturation; calculating the gas saturation of the tight reservoir rock sample according to the following equation: Sg=100?Sw wherein Sw is the water saturation in %; Sw is the sum of the free water saturation, the water saturation and the corner water saturation; Sg is the gas saturation in %. The method for determining the gas saturation of a tight reservoir uses model calculations, which avoids errors in the determination results of the gas saturation caused by water volatilization, surface adsorption, and observation of water flow during experiments.

Abstract: Methods and systems are described for detecting a wide variety of fault conditions in a HVAC system based on analysis of current and historical energy consumption patterns, and on comparison with energy consumption patterns of other similarly situated RTUs. Energy consumption comparisons are preferably made in regard to a normalized load ratio or NLR or more preferably to a daily maximum normalized load ratio or MDNLR, which provide more robust and reliable bases for comparison of faulty and fault-free RTUs, and hence for generalized fault detection, than other previously known metrics or criteria.

Abstract: The invention relates to a method for monitoring at least two redundant sensors, which are in particular arranged in a chemical plant or an aircraft, comprising providing a first sensor signal of a first sensor, the first sensor signal comprising at least one measured value, providing at least one further sensor signal from a further sensor, the further sensor signal comprising at least one further measured value, generating a first analysis signal from the first sensor signal, generating at least one further analysis signal from the further sensor signal, determining at least one relationship between the first sensor signal and the further sensor signal at least in dependence on the first analysis signal and the further analysis signal over a time horizon, comparing the relationship with at least one admissible range, and, depending on the result of the comparison, determining whether at least one sensor of the two redundant sensors is faulty.

Abstract: A remote sensor calibration system remotely calibrates sensors of various types in an automated fashion. The remote sensor calibration system receives sensor output, associated with one or more locations and one or more times, from a sensor and its peer sensor population. The sensor output from the sensor and its peer sensor population is compared to generate a correction factor. The correction factor is transmitted to the sensor and used to calibrate the sensor. Communication will typically occur via one or more wireless links allowing the sensors to be remotely calibrate while maintaining their mobility.

Abstract: A method of seismic acquisition using a dispersed-source array (DSA) comprising two or more sources. The method comprises determining, for each of the two or more sources of the DSA, an individual spectrally-banded waveform. For each of the two or more sources, a primary waveform is formed by repeating the individual spectrally-banded waveform. For each of the two or more sources, a secondary waveform is formed based on the primary waveform. The secondary waveform is spectrally shifted relative to the primary waveform such that secondary waveforms of any two of the two or more sources are spectrally non-overlapping. The blending operator based on the secondary waveform of each of the two or more sources is provided to the DSA. The method also includes performing deblended-data reconstruction of acquired seismic data using one or more properties of the blending operators of the two or more sources.

Abstract: Certain implementations of the disclosed technology may include systems and methods for extending a frequency response of a transducer. A method is provided that can include receiving a measurement signal from a transducer, wherein the measurement signal includes distortion due to a resonant frequency of the transducer. The method includes applying a complementary filter to the measurement signal to produce a compensated signal, wherein applying the complementary filter reduces the distortion to less than about +/?1 dB for frequencies ranging from about zero to about 60% or greater of the resonant frequency. The method further includes outputting the compensated signal.

Abstract: A unit that houses tracking electronics configured to be passed through a duct while the tracking electronics collect position information is provided. The information collected by the unit is used to map the duct. A method of mapping a duct is also provided.

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: An embodiment of a method of performing aspects of a downhole operation includes receiving a measurement value from a first sensor configured to measure a parameter related to the downhole operation, receiving measurement data from a different sensor, the measurement data related to the downhole operation, and performing, by a sensor evaluation module, an evaluation of the first sensor. The evaluation includes determining a condition of the first sensor based on the measurement data from the different sensor, selecting a rule that prescribes a set of one or more measurement values of the parameter that are plausible if the condition is met, and determining whether the measurement value from the first sensor is plausible based on comparing the measurement value to the prescribed set of one or more measurement values.

Abstract: Process for measuring emission for a flame in an open combustion environment. A captured image is received from each of a plurality of image capturing devices in at least one selected spectral band. Each of the plurality of image capturing devices is trained on the flame from the combustion process from a different perspective view angle. A spectral path length of the flame in the at least one spectral band is estimated from the captured images. Emitted radiance of the flame is estimated from the captured images, and a temperature of the flame is estimated from the estimated emitted radiance. A gas species concentration of the flame is estimated from the temperature of the flame and the spectral path length of the flame. Emission for the flame is measured from the gas species concentration.

Abstract: A method for characterizing a sand-pack or gravel-pack in a subsurface formation includes inducing a pressure change to induce tube waves in fluid in a well drilled through the subsurface formation. At a location proximate to a wellhead at least one of pressure and a time derivative of pressure in the well is measured for a selected length of time. At least one of a physical parameter and a change in the physical parameter with respect to time, of the sand-pack or gravel-pack, is determined using the measured pressure and/or the time derivative of pressure.

Abstract: A method and system for processing a slowness profile. A method may comprise disposing a geophone array into a borehole, positioning the geophone array at a first location within the borehole; discharging a seismic source; positioning the geophone array at a second location within the borehole; discharging the seismic source, wherein the seismic source produces an acoustic wave; recording a vertical seismic profiling dataset, wherein vertical seismic profiling comprises a dataset of recorded acoustic waves by the geophone array at the first location within the borehole and the second location within the borehole; picking a first gap travel time from the vertical seismic profiling dataset; and determining the slowness profile, wherein the slowness profile comprises determining a slowness of the acoustic wave through a formation by the geophone arrays. A well system may comprise a geophone array, comprising a plurality of geophones, and an information handling system.

Abstract: A system and method for online estimate of the filling level of balls and loading level in a rotary mills, comprising a set of vibration sensors unit, associated with a magnet to transmit data signals via an antenna to a receiver that receives data signals from the antenna, an antenna, wherein the receiver is connected via optical fiber to a signal processor, which in turn communicates to a control server via a UTP cable, wherein the control server also obtains data from the mill operation to determine the best filling of balls and load; and the operating method.

Abstract: A method of logging a wellbore casing and an adjacent formation comprises moving a measurement tool inside a borehole of the casing, wherein the casing is filled with air. Concurrently with moving the measurement tool inside the borehole, the method comprises emitting radioactive energy at an initial energy level from a radiation source of the measurement tool, wherein the radioactive energy is directed toward a wall of the casing and along a travel path from the radiation source to one or more detectors of the measurement tool, measuring energy loss of the radioactive energy at the one or more detectors relative to the initial energy level, and detecting a cement property outside of the casing based on the measured energy loss.

Abstract: To reduce the error in a rotational angle detected by a rotational angle detection apparatus, provided is a rotational angle detection apparatus that detects a rotational angle of a magnetic field generation source, including a magnetic field detection apparatus that detects magnetic field components in at least two directions, and outputs resulting detection data; a correction value calculating section that calculates correction values for correcting an angle error of the rotational angle, based on a steady-state error that does not depend on rotation of the magnetic field generation source; and an angle computing section that calculates the rotational angle of the magnetic field generation source based on the detection data and the correction values, and outputs an angle signal indicating the rotational angle.

Abstract: Described herein are methods and techniques for determining one or more characteristics of a hydrocarbon source. The method comprises obtaining a hydrocarbon fluid sample, determining at least one measured clumped isotope signature or measured position specific isotope signature for at least one hydrocarbon species of interest in the hydrocarbon fluid sample, determining at least one expected clumped isotope signature or expected position specific isotope signature for the hydrocarbon species of interest, comparing the measured clumped isotope signature or measured position specific isotope signature with the expected clumped isotope signature or expected position specific isotope signature, and determining at least one characteristic of the source of the hydrocarbon sample based on the comparison.