Abstract: A bubble detection sensor includes an emitter having an emitting surface and a receiver positioned on a side of a fluid conduit opposite the emitter. The receiver has a receiving surface adapted to receive a signal emitted by the emitter through a fluid of the fluid conduit. A sensor axis extending normal to the emitting surface and the receiving surface is disposed at a rotation offset angle with respect to a plane extending normal to a longitudinal conduit axis of the fluid conduit. The rotation offset angle is set to optimize a ratio of a sensitivity of the signal received by the receiver to an efficiency of the signal received by the receiver.

Abstract: In a particular embodiment, a method includes receiving a first set of location data and a second set of location data at a mobile device. The method includes locating a first reference point identifier that is included in the first set of location data and a second reference point identifier that is included in the second set of location data. The first reference point identifier field and the second reference point identifier field identify a common reference point. The method includes identifying first information in the first set of location data that is associated with the common reference point. The method also includes identifying second information in the second set of location data that is associated with the common reference point and spatially aligning the first set of location data with the second set of location data based on the common reference point to associate the first information with the second information.

Abstract: A testing system for a wellbore operation and method of testing a fluid sample from a wellbore. A fluid sample is obtained from the wellbore operation. The fluid sample is received at a first test station having a first robot arm for performing a test on the fluid sample. A controller receives data on the wellbore operation, selects the test based on the data and controls the first robot arm to perform the test. A result of the test is used to adjust a parameter of the wellbore operation.

Abstract: Systems and methods include a method for downhole leak detection and prediction in water injection wells. Bulk well operation information for one or more wells is accessed from a database. Real-time pressure and water rate information is received from surface and downhole gauges during operation of a water injection well. Engineered prediction-ready data is generated using the real-time pressure and water rate information by translating the bulk well operation information. Early signs of leakage at sub-surfaces of the water injection well are determined using the engineered prediction-ready data and wellbore dynamics of the water injection well. Information associated the early signs of leakage is provided based on the determining and for presentation to one or more users.

Abstract: A system is provided for detecting the mass of oil in an inorganic mineral of shale. The system operates by performing an extraction test on a first shale sample by using chloroform to obtain a total content of shale oil in the shale; enriching kerogen from the second shale sample to obtain dry kerogen; and performing an extraction test on oven-dried kerogen by using chloroform to determine the mass of extracted kerogen. The system also operates by determining the mass of the oil in the organic matter of the shale sample and the mass of the oil in an inorganic mineral of the shale; establishing a model for predicting a ratio of the mass of the oil in the inorganic mineral of the shale to the mass of the oil in the organic matter; and using the prediction model to determine the mass of oil in an inorganic mineral.

Abstract: A method and a system for measuring downhole fluid properties. The downhole fluid sampling tool may comprise at least one probe and at least one passageway that passes through the at least one probe and into the downhole sampling tool. The method may comprise drawing a wellbore fluid through the at least one probe and through the at least one passageway, obtaining a first channel measurement of the wellbore fluid, obtaining at least a second channel measurement, clustering channel data from a plurality of channel measurements comprising the first channel measurement and the at least second channel measurement, and measuring a phase through a plurality of channels. The method may further comprise separating a plurality of phase signals based on the phase measured through the plurality of channels, labeling the wellbore fluid, assigning the plurality of phase signals to specific phases of a multi-phase fluid, and estimating a fluid property.

Abstract: A method includes receiving a histogram output from a detector sensor, and calculating a median point of a pulse waveform within the histogram. The pulse waveform has an even probability distribution over at least one quantization step of the histogram around the median point. A corresponding apparatus can include a detector sensor and a co-processor coupled to the detector sensor.

Abstract: One aspect of the invention provides a computer-implemented method of identifying a species from mass spectra. The computer-implemented method includes: loading a data set including a species and associated mass spectra into memory on a computer; for each of the associated mass spectra, pre-processing to identify ranks of intensities of an in-bin peak across bins defining ranges of mass-to-charge ratio; and training a species binary classifier for each of a plurality of species using at least the ranks of intensities. Another aspect of the invention provides a system for identifying a species from mass spectra. The system includes: a processor; and computer-readable memory containing instructions to: implement an interface programmed to receive mass spectra; store the mass spectra in the computer-readable memory; and invoke execution of any of the methods described herein on the processor.

Abstract: The disclosure provides a method for measuring energy of natural gas, including determining first energy per unit volume of the target natural gas based on the carbon content; obtaining combustible component information in the target natural gas, and determining second energy per unit volume of the target natural gas based on the combustible component information; determining a difference between the first energy per unit volume and the second energy per unit volume; based on the difference, determining whether the first energy per unit volume and the second energy per unit volume are accurate by a deviation determination model; and if the first energy per unit volume and the second energy per unit volume are accurate, determining the energy of the target natural gas based on the first energy per unit volume, the second energy per unit volume, and the volume of the target natural gas.

Abstract: The present invention relates to a technique for identifying geological and drilling patterns by analyzing data from drilling parameters, using periodic orthogonal functions applied to such data. The use of averages to convert time data to depth data acts as a low-pass filter, attenuating the textural information from the torque data. Therefore, with the use of simple statistical filters combined with the use of multidimensional data visualization methods, it is possible to discretize drilling and geological patterns in the depth data acquired, aiding in the characterization of the top of the pre-salt carbonate reservoir, minimizing the geological and engineering risk in these operations.

Abstract: A method for transmitting a measurement taken by a sensor at a current measurement instant, a measurement instant and a measurement forming a measurement point. The method includes: determining a threshold on the basis of measurement points that temporally precede the current measurement point in a collection window; when a slope of a straight line that runs through the current measurement point and the measurement point that immediately precedes it is higher than the threshold, transmitting the measurement upon expiry of a waiting time that corresponds to the minimum time interval between two successive measurement instants in the collection window; when the slope is lower than the threshold, transmitting the measurement upon expiry of a waiting time that corresponds to the maximum time interval between two successive measurement instants in the collection window.

Abstract: A method for assessing the mass concentration of uranium in a sample of uranium-bearing material by gamma spectrometry, includes a) acquiring (200) an energy spectrum of gamma radiation from the sample using a scintillator detector, the energy spectrum (100) comprising at least a first energy band (110) between 87 keV and 110 keV, and a second energy band (120) between 560 keV and 660 keV, the second energy band comprising at least one energy line (130) at 609 keV from 214Bi, b) calculating (210) an initial mass concentration of uranium (CmU0) using the energy spectrum, c) measuring (220) a parameter representative of the height of the sample and a parameter representative of the density of the sample, d) calculating (230) a corrective coefficient (K), and e) calculating (240) a corrected mass concentration of uranium (CmU) using the initial mass concentration of uranium (CmU0) and the corrective coefficient (K).

Abstract: A method for determining oscillations occurring in a measuring signal. The method includes the steps of receiving a measuring signal, determining the extreme values of the received measuring signal, and ascertaining closed loops of the measuring signal, by a) identifying a closed loop in the measuring signal (a closed loop being formed by two half loops having identical oscillation width and opposite direction, b) storing the identified closed loop, c) removing the identified closed loop from the measuring signal, and d) repeating steps a) through c) until all closed loops have been ascertained.

Abstract: An apparatus comprises a subsurface sensor to be positioned in a wellbore formed in a subsurface formation, wherein the subsurface sensor is to detect subsurface measurements. The apparatus includes a processor and a machine-readable medium having program code executable by the processor to cause the processor to generate a combination of functions based on the subsurface measurements, wherein the combination of functions is a subset of functions from a library of functions. The program code is executable by the processor to cause the processor to determine at least one function parameter of at least one function of the combination of functions and determine at least one formation property of the subsurface formation based on the at least one function parameter.

Abstract: A method and system for a rotary steerable system (RSS). The method may comprise performing a tool position calculation from the one or more measurements and creating one or more event flags based at least in part on a location of the RSS in a formation, wherein the one or more event flags are created by an information handling system disposed on a bottom hole assembly. The method may also comprise selecting an algorithm for the tool position calculation based on the one or more event flags. The system may comprise one or more sensors configured to take one or more measurements and an information handling system disposed on a bottom hole assembly.

Abstract: Examples described herein provide a downhole sampling method that includes receiving fluid data from a fluid downhole in a wellbore operation. The method further includes defining a subset of the fluid data and a remaining subset of the fluid data. The method further includes iteratively generating, by a processing device, a plurality of curves fit to the subset of the fluid data. The method further includes performing, by the processing device, a validation on the plurality of curves as applied to the remaining subset of the fluid data to determine one or more best fit curves from the plurality of curves.

Abstract: A method for determining maximum recoverable hydrocarbon (EMR) in a tight reservoir is disclosed. The method includes determining, based on downhole logs, a total measure of hydrocarbon amount within the tight reservoir, determining, by at least attributing fluid loss during core surfacing of the core sample to hydrocarbons, a non-recoverable measure of hydrocarbon amount within a core sample of the tight reservoir, and determining an EMR measure based on the total measure of hydrocarbon amount and the non-recoverable measure of hydrocarbon amount, wherein during the core surfacing pore pressure reduces from a reservoir condition to a surface condition.

Abstract: Data receiving and logging are disclosed. A method includes receiving a linearly polarized signal, the linearly polarized signal including a set of direct and reflected components and obtaining power measurements of the linearly polarized signal. The power measurements are inserted into a navigation message and provided as precision power values characterizing the linearly polarized signal at a high precision. The power values for the linearly polarized signal are stored for further analysis.

Abstract: A method for associating environmental data with map features is described. The method includes receiving sensor data and receiving position data. The sensor data is associated with each of a plurality of time intervals and is from at least one sensor on at least one mobile sensor platform. The position data is associated with the plurality of time intervals and is from the at least one mobile sensor platform. Trajectories and corrected locations of the mobile sensor platform are generated for the plurality of time intervals using the position data. A position of the mobile sensor platform is assigned to a corresponding map feature for each of the plurality of time intervals based on the trajectories and corrected locations. The sensor data is also processed to generate sensor data values for each of the plurality of time intervals. The sensor data values are assigned to the corresponding map feature of the position of the mobile sensor platform for each of the plurality of time intervals.

Abstract: Electrochemical Impedance Spectroscopy (EIS) is used in conjunction with continuous glucose monitors and continuous glucose monitoring (CGM) to enable in-vivo sensor calibration, gross (sensor) failure analysis, and intelligent sensor diagnostics and fault detection. An equivalent circuit model is defined, and circuit elements are used to characterize sensor behavior.