Abstract: Disclosed is a system and method for monitoring a characteristic of an environment of an electronic device. The electronic device may include a printed circuit board and a component. A sensor is placed on the printed circuit board, and may be between the component and the board, and connects to a monitor, or detector. An end user device may be used to store, assess, display and understand the data received from the sensor through the monitor.

Abstract: A method for determining a total vertical depth (TVD) for a well plan involves measuring differences between a projected BHA position at a depth of a survey station and a calculated BHA position based upon a minimum curvature method at the depth of the survey station. The differences are accumulated at each survey station with respect to the BHA position. Real time TVD corrected gamma logs are generated responsive to the accumulated differences of the BHA position.

Abstract: Systems, methods, and computer-readable media are provided for a near-well unstructured grid model builder for generating a full-field unstructured grid for reservoir simulation. As described further below, the near-well unstructured grid model builder may include a workflow interface and a parallel unstructured grid model builder. The inputs to the near-well unstructured grid model builder may include existing well trajectory and completion data, future well data, a geological model, a structured grid simulation model, or any combination thereof. The near-well unstructured grid model builder may output a near-well unstructured grid having a specified grid resolution in regions of interest that include a well.

Abstract: According to some implementations, the present disclosure relates to a method and apparatus for evaluating exploitation value of a geological resource. In one implementation, a method includes: acquiring geological parameters of a geological structure in multiple designated dimensions, wherein the geological parameters are used for characterizing a state of the geological structure in the designated dimensions; matching the geological parameters with a threshold of each of the designated dimensions, respectively, to obtain a characterization value of each of the designated dimensions; forming a characterization vector from the characterization values of the designated dimensions; and performing an evaluation operation based on the characterization vector to obtain an evaluation value of the geological resource in the geological structure.

Abstract: The invention discloses a dolomite reservoir prediction method and system based on well and seismic combination, and storage medium. The method steps include: obtaining the dolomite index characteristic curve through well log sensitivity analysis, and distinguishing the dolomite and limestone according to the difference in their response range; after the artificial intelligence deep learning is performed on the dolomite index characteristic curve of the drilling area, the dolomite index characteristic curve of the virtual drilling area is obtained; according to the dolomite index characteristic curve of the drilling area and the virtual drilling area, the post-stack seismic data is used for inversion to obtain the distribution and development status of the dolomite reservoir in the test area.

Abstract: A pore analysis method is described which comprises the steps of generating a model of a medium, the model comprising a regular array of pores, the pores being connected to adjacent ones of the pores by throats, modifying the sizes of the pores and throats until the model of the medium is representative of the medium, simulating, using the model, the effect of percolation of the medium using a fluid at a first pressure, repeating the simulation step with progressively increasing intrusion pressures and noting, for each pore, the intrusion pressure at which intrusion of that pore occurs, and identifying, from the information relating to the intrusion pressure at which intrusion of each pore occurs and from the shape of the void size distribution, at least one pore that should be treated, during further analysis, as comprising a cluster of voids.

Abstract: A method for modeling a reservoir includes receiving vertical formation data describing geological formations in a vertical direction as a function of vertical depth, receiving near-wellbore horizontal formation data describing the geological formations in a horizontal or deviated direction near a wellbore up to a wellbore instrument range, and correlating the vertical formation data with the near-wellbore horizontal formation data to create horizontally adjusted formation data to describe the geological formations in the vertical direction beyond the wellbore instrument range, along the horizontal or deviated direction.

Abstract: An acoustic logging method that may comprise acquiring waveforms for multiple acoustic wave modes as a function of tool position in a borehole; deriving position-dependent mode dispersion curves from the waveforms; accessing a computed library of dispersion curves for a vertical shear slowness (s) and a Thomsen gamma (?) of a given acoustic wave mode as a function of frequency; interpolating dispersion curves in the computed library to an assumed known compressional wave slowness, a borehole radius, a formation density, a mud density, and a mud slowness; computing an adaptive weight; and inverting dispersion curve modes jointly for a shear wave anisotropy, a vertical shear wave slowness, an inverted mud slowness, and an inverted mud density as a function of depth. An acoustic logging system may comprise a logging tool, a conveyance attached to the logging tool, at least one sensor, and at least one processor.

Abstract: A cognitive computing system for enhancing drilling operations, in some embodiments, comprises: neurosynaptic processing logic; and one or more information repositories accessible to the neurosynaptic processing logic, wherein the neurosynaptic processing logic performs a probabilistic analysis of one or more real-time drilling operations measurements, one or more resources obtained from said one or more information repositories, and one or more drilling operations simulations that account for said one or more real-time drilling operations measurements, wherein the neurosynaptic processing logic controls a drilling operation based at least in part on said probabilistic analysis.

Abstract: Disclosed are methods and apparatus pertaining to processing in-situ, real-time data associated with fluid obtained by a downhole sampling tool. The processing includes generating a population of values for ?, where each value of ? is an estimated value of a fluid property for native formation fluid within the obtained fluid. The obtained data is iteratively fit to a predetermined model in linear space. The model relates the fluid property to pumpout volume or time. Each iterative fitting utilizes a different one of the values for ?. A value ?* is identified as the one of the values ? that minimizes model fit error in linear space based on the iterative fitting. Selected values ? that are near ?* are then assessed to determine which one has a minimum integral error of nonlinearity in logarithmic space.

Abstract: A technique for calculating the motion and stress at any location along a riser or mooring line that is connected to an oil platform using data from multiple motion sensors that are installed above the water level on the platform is disclosed. A relationship between motion at the locations of the motion sensors and motion at the point at which the riser or mooring line is attached to the platform is determined from a model of the platform. From this relationship, the motion at the location at which the riser or mooring line is attached to the platform is computed from motion that is measured by the motion sensors. The motion and stress at any location along the riser or the mooring line is calculated based on the acceleration at the location at which the riser or mooring line is attached to the platform.

Abstract: A heating, ventilation, and air conditioning (HVAC) system includes a control unit, a central controller coupled to the control unit via a first two-conductor wireline structure, and a plurality of HVAC system components coupled to the central controller via a second two-conductor wireline structure. The central controller is configured to receive, via the first two-conductor wireline structure, control information corresponding to an enclosed space, generate control data, and transmit, via the first two-conductor wireline structure, the control data to at least one of the plurality of HVAC system components to regulate operations thereof.

Abstract: A monitoring system includes a processor configured to receive sensor data from one or more sensors positioned about a mineral extraction system, input the sensor data into a model to generate a health index predictive of a future condition of a component of a blowout preventer (BOP) stack assembly of the mineral extraction system, and to provide an output indicative of the future condition of the component of the BOP stack assembly.

Abstract: Systems and methods for initiating an emergency disconnect sequence (EDS) are provided. In an aspect, a disconnection system is provided and configured to initiate the EDS, and includes a controller including a processor and a memory operably coupled to the processor. The controller receives, from a set of motion reference units (MRU(s)) operably coupled to a flexible joint, position data generated by the set of motion references units and associated with the joint when the joint is operably coupled to and disposed between a drilling riser and a lower marine riser package (LMRP). The controller determines, based on the position data, an angular offset of the joint. The controller sends, to a subsea control pod disposed at or adjacent to the LMRP, a trigger signal in response to determining that the angular offset exceeds a predetermined threshold, such that the subsea control pod initiates the EDS.

Abstract: A layered water injection system and a layered water injection method. The system comprises: a ground water injection valve group configured with an intelligent control valve, for receiving a water injection control instruction sent by a remote control center, and for converting the water injection control instruction into a switching action of the intelligent control valve to control water flow pressure fluctuation in a water injection string, so as to form a first pressure wave code in the water injection string; a water distributor for collecting the first pressure wave code, interpreting the first pressure wave code as a corresponding water outlet switch instruction, and performing layered water injection control according to the water outlet switch instruction. The embodiments of the application can improve the automation level of layered water injection and the reliability of layered water injection control.

Abstract: A method may comprise penetrating a subterranean formation with a bottom hole assembly, determining a revolutions-per-minute (RPM) measurement based on a zero crossing of sinusoidal magnetometer data, determining a gyroscope bias from gyroscope data using the determined RPM measurement, determining bias compensated gyroscope data by subtracting the determined gyroscope bias from the gyroscope data, determining an angular displacement measurement using the bias compensated gyroscope data, determining a selected tool-face measurement, computing a weighted sum of the selected tool-face measurement with the determined bias compensated gyroscope data, and determining a gravitational tool-face measurement from the computed weighted sum. A system may comprise a drilling rig, a pipe string attached to the drilling rig, a bottom hole assembly attached to the pipe string, wherein the bottom hole assembly comprises at least one sensor, a drill bit, and a computing subsystem connected to the at least one sensor.

Abstract: A method for controlling a downhole steerable tool, such as a rotary steerable system (RSS), in a drilling system that also includes a rotating drillstring and a measurement-while-drilling (MWD) system comprises encoding an original command for the tool into an encoded signal consisting of modulations of the drillstring rotation rate, transmitting the encoded command by modulating the drillstring rotation rate, measuring the drillstring rotation rate at the tool and decoding the encoded command so as to generate a tool-decoded command, separately measuring the drillstring rotation rate and decoding the encoded command from the separate downhole-measurements so as to generate a separately downhole-decoded command, transmitting the separately downhole-decoded command to the uphole location, comparing the separately downhole-decoded command to the original command, and taking corrective action if the two commands are different.

Abstract: A method of performing aspects of an energy industry operation includes receiving input data at a processing system, the input data describing an assembly for performing the energy industry operation and properties of the formation, the assembly including a downhole component, the processing system configured to estimate production properties based on mathematical models including at least a model of the downhole component and one or more models for simulating fluid flow in the formation. The method also includes, based on the input data, generating a workflow that includes steps for estimating production properties using the models, receiving a selection from a user specifying a type of analysis to be performed and/or a level of complexity of analysis to be performed, customizing the workflow based on the user selection, estimating the production properties based on the models, where estimating is performed according to a procedure specified by the workflow.

Abstract: Method for mapping a 3D grid or mesh from a faulted subsurface domain to a continuous design domain, wherein the grid may be used to represent a discrete model of a subsurface material property (such as permeability) to use, for example, in a reservoir simulator. The mapping is geometry-based, not physics-based. The mapping is determined by an iterative optimization procedure designed to penalize deformation of tessellated mesh cells (703) in the design domain compared to their geometric quality in the faulted domain (701), but subject to stitching constraints (702) appearing as a penalty term or Lagrange multiplier term in the optimization objective function to influence the final mesh to co-locate pairs of points identified on opposite sides of a fault as having been located together before the fault occurred.

Abstract: Well log data may be used in well log operations by facilitating the identification of hydrogen carbon deposits. More specifically, the well log data may be used to generate visual representations. Aspects of the present disclosure relate to generating a color composite image based on multiple types of well log data and transforming the well log data into a color space. In further embodiments, the color composite image may be modified and/or objects within the color composite image may be identified.

Abstract: Systems and methods for calculating a standardized Health Index for a plurality of different components are shown and described. There is a vast number of different components used on an oil rig and each one may have a different definition of new, worn, damaged, or depleted. The system includes a measurement component that takes a measurement of the different components, and a health modeling component which calculates the standardized Health Index. Monitoring the Health Indices provides a rig operator information from which decisions on equipment use can be made.

Abstract: Managing oilfield operations include obtaining a subsurface model including a fracture design model having an fracture property with an uncertain value. A set of representative values that represent uncertainty in the fracture property is obtained and used to solve an oilfield optimization problem with a control variable to obtain a solution. The solution includes an optimal value for the control variable. Based on the solution, an oilfield design is generated and stored.

Abstract: Seismic systems and processes for making and using same. In some examples, the seismic system can include an acoustic tool configured for placement in a wellbore penetrating a subterranean formation. The acoustic tool can include an acoustic transmitter unit for producing acoustic energy waveforms in the subterranean formation such that the interaction of the acoustic energy waveforms with structures in the formation can be an event that generates event signals. A receiver unit can include acoustic receivers distributed azimuthally around a central axis of the acoustic tool for sensing the event signals. The acoustic tool can determine event signal amplitudes of the event signals at each of the acoustic receivers, can determine which of the acoustic receivers has a maximum amplitude of the event signal amplitudes, and can interpolate between the maximum amplitude acoustic receiver and one or more adjacent acoustic receivers to find an azimuthal direction of the event.

Abstract: Methods and systems are described that can be used for locating conductive bodies such as wellbore casing or piping disposed below the earth's surface. An electrical current can be excited in a conductive body in each wellbore in a given area to produce a magnetic field, and the magnetic field can be detected by a ranging tool. Location and current parameters can be determined for an estimated number of wellbores producing non-negligible contributions to the magnetic field, and the estimated number of wellbores can be adjusted until the number of contributing wellbores is determined. Location solutions can be returned for each of the contributing wellbores, and the location solutions can be employed to facilitate exploration of drilling applications such as well avoidance, well intersection and/or steam assisted gravity drainage (SAGD) steering operations.

Abstract: A system 10 for controlling a drilling operation by a drill rig 12 includes a receiver 16 for receiving sensed data related to the drilling operation. A processor 18 is in communication with the receiver 16, the processor 18 processing the sensed data to estimate at least one geological property of interest of a zone 20 in which the drill rig 12 is active. The processor 18 is configured to operate as a decision engine 22 to optimize the drilling operation automatically by changing at least one drilling related parameter during the drilling operation based on the at least one geological property of interest.

Abstract: Image block transmission includes reading an image block from a downhole sensor. Based on the image block, a set of formation features attributes for the image block are detected. The set of formation features attributes describe a structural property of a subsurface formation. Based on the set of formation feature attributes, a wavelet transform function is modified to obtain a modified wavelet transform function. The modified wavelet transform function is applied to the image block to obtain a set of wavelet transform coefficients for the image block. The image block transmission further includes generating an encoded bit stream comprising the set of formation features attributes and the set of wavelet transform coefficients for the image block, and transmitting the encoded bit stream.

Abstract: An active heat-dissipation system for a base station of a communication system includes a measuring module, configured to detect a temperature sensing signal of the base station; a controller, configured to receive the temperature sensing signal detected by the measuring module to set a preset temperature signal, to generate a difference between the temperature sensing signal and the preset temperature signal and a time derivative of the difference, and to output a control signal according to the difference and the time derivative of the difference based on a control program; and a power module, configured to receive the control signal and output an electrical signal to a heat-dissipation module according to the control signal, such that the heat-dissipation module performs a heat-dissipation process for the base station according to the electrical signal.

Abstract: A system and method for installing casing in a blind horizontal well for blind horizontal directional borings. The system and method may include an example of an offset transmitter sonde assembly that contains an open central passage through which well casing can be inserted, and an example of a drill bit assembly that may be remotely uncoupled from a drill string, leaving the bit in the bore created. Remote uncoupling of the drill bit assembly tends to allow a casing to be installed in the bore while the drill string and bit remain in the bore for support during casing installation. After installation of the casing the drill bit assembly may be uncoupled from the drill string, allowing the drill string to be withdrawn from the bore, with the drill bit assembly remaining in the bore.

Abstract: In the field of power distribution networks, a digital output circuit, for controlling an item of equipment within a power distribution network, comprises a switch element openable and closeable to selectively permit the flow of current to an item of equipment being controlled in use by the digital output circuit. The digital output circuit also includes a current acquisition circuit to measure the current flowing through the switch element. In addition, the digital output circuit includes a condition monitoring circuit that is arranged in communication with the current acquisition circuit. The condition monitoring circuit is configured to record the measured current flowing through the switch element as the switch element closes and thereby establish a switch element closing signature.

Abstract: A method of probing the layers above, at, and below the surface of a conducting region includes exciting nuclear or electronic spins within the conducting region using a first frequency, receiving a second frequency from the conducting region, determining the length scales by the conductivity of the conducting region, the first frequency, and the second frequency, obtaining a depth profile of the conducting region, and indirectly measuring the presence of the surface by characterizing signal distortions above the surface.

Abstract: A method including receiving a waveform, identifying the presence of a pulse in the waveform, and subtracting a reflection template from the received waveform when a pulse is present in the waveform to obtain a corrected waveform, is presented. The method may further include reading the corrected waveform using a digital processing protocol and adjusting a drilling parameter according to the reading. A device configured to perform a method as above is also provided. A method as above, further including modifying a drilling parameter in a wellbore based on the reading of a pulse sequence including the waveform is also provided.

Abstract: Methods of geophysical prospecting are described herein. In the described methods, a data set of electromagnetic readings from a marine geophysical survey is obtained and loaded into a computer processing system. Using the computer processing system, a high-frequency subset of the data is selected based on a frequency threshold, and a seawater resistivity map is resolved from the subset for a seawater portion of the survey by inversion. The seawater resistivity map can subsequently be used to resolve a resistivity map of the seabed from the data set by inversion.

Abstract: A method includes acquiring signals generated from operating a multi-component induction tool in a wellbore. The multi-component induction tool has a plurality of receiver arrays. The method includes generating, for each receiver array at a fixed frequency, a combination of components from the acquired signals, wherein the components corresponds to components of an apparent conductivity tensor. The generating of the combination of components includes generating vertical magnetic dipole (VMD) data and horizontal magnetic dipole (HMD) data. The method includes mixing together the combination of VMD data and HMD data measured from the plurality of receiver arrays and generating data, with respect to evaluation of a formation around the wellbore, from the mixing together of combinations.

Abstract: A calibration system for an electromagnetic (EM) tool includes a processor. The processor employs the EM tool to measure responses at each of a plurality of channels. The processor records the measured responses at each of the channels in an EM data log for the channel. The processor determines a nominal value of each of the channels, as being equal to a histogram peak of the EM data log. The processor selects one or more calibration points from the EM data log for a particular channel, based on a difference between the nominal value of the particular channel and the measured response at the calibration point being greater than a particular threshold. The processor determines a plurality of parameters by reducing a misfit between synthetic data and both the nominal values of the channels and the measured responses of the channels at the selected one or more calibration points.

Abstract: Users of social networking computer systems provide location information that is transformed into geo-coded coordinates specifying user locations. Providers of content, such as messages or documents, also participate in the social networking system and use drawing tools or provide data files that define one or more geographical areas or regions of a map, which may define a larger geographical area that encompasses the users of the social networking system. Data specifying the areas is stored. The content providers create one or more messages and associate each of the one or more messages with one or more of the areas. The users communicate requests for messages to the social networking system; in response, the system associates the user location data with the stored areas and messages and returns only those messages that have been associated with the particular areas in which the users are located.

Abstract: An acoustic logging system identifies hydrocarbon formation types by a real-time model-constrained mud wave slowness determination method using borehole guided waves. The system also combines data processing from different acoustic waveform processing techniques using an information sharing procedure, for example, using monopole source data and dipole source data, to further improve the processing results and to achieve more stable and reliable real-time shear slowness answers.

Abstract: Apparatus and methods to visualize formation properties and distances associated with formations can be implemented in a variety of applications. In various embodiments, one or more visualization schemes and systems arranged to implement such schemes can use a combination of visual structures to provide information about measured formations. Additional apparatus, systems, and methods are disclosed.

Abstract: Methods and systems for enhancing workflow performance in the oil and gas industry may include modeling preferred sensor locations, sensor types, and sampling frequency for effective and efficient monitoring of a mud circulation system. For example, a method may include circulating a mud through a mud circulation system that includes a plurality of sensors that include at least one of: a pressure sensor, a stroke counter, a flow sensor, a viscosity sensor, or density sensor; and modeling the plurality of sensors using a state reduction approach to determine at least one selected from the group consisting of preferred locations, preferred sensory types, preferred sensor frequency resolution, and a combination thereof that effectively represent or substantially impact conditions of the mud circulation system, thereby providing a preferred sensor scheme.

Abstract: Systems and methods compute dysfunctions via mapping of tri-axial accelerations of drill pipe into drill-string motions. The methods remove gravitational and centripetal accelerations to yield corrected acceleration data due to the vibration only, transform the corrected acceleration data, and maps resulting transformed acceleration data into continuous drill-string positions. The maps provide 2D/3D visualization of drill-string motions to enable real-time optimization and control of well drilling operations and other scenarios where proactive detection of temporal events in automated systems may aid in avoiding failures.

Abstract: Methods and systems are described for estimating the level of contamination of downhole fluid and underlying composition using physical property measurements, and mathematical modeling of contamination functions and fluid property mixing laws. The proposed approaches enable computation of estimates of the pumping time needed to achieve a certain contamination threshold level and the determination of whether or not sampling is appropriate at the current point in time based on the predicted compositional properties of the formation fluid.

Abstract: A method includes constructing a digital model of a porous rock sample using input data and establishing for the digital model of a porous rock sample and for a fluid of interest figures-of-merit that are established for full-sample dimensions. For a selected fluid flow model, the method performs a calibration so as to match parameters of the selected fluid flow model to the established figures-of-merit and, based on the calibrated fluid flow model, performs at least one simulation of a flow of the fluid through the digital model of a porous rock sample with a fluid additive to provide a predicted enhanced fluid recovery efficiency. Also disclosed is a system as well as a computer program product configured to implement the method.

Abstract: An integrated wireless data system and method for controlling and measuring operational data of a pumpjack system, for safety, health monitoring, and pump control is provided. The integrated wireless data system and method may be configured to allow for bi-directional communication with a central station to enable human intervention with pumpjack and to store pump parameters in a database for use in development of predictive maintenance techniques.

Abstract: A system and method is provided for performing stimulation operations at a wellsite having a subterranean formation with a reservoir therein. The method involves acquiring integrated wellsite data (e.g., geomechanical, geological, and/or geophysical properties of the formation, and/or geometrical properties of the mechanical discontinuities in the formation). The method also involves generating a mechanical earth model using the integrated wellsite data, and identifying a crossing behavior between an induced hydraulic fracture and at least one discontinuity in the formation. The method also involves optimizing a stimulation plan to achieve an optimized crossing behavior. The stimulation plan includes at least one of fluid viscosity, rate of injection of the fracturing fluid, and concentration of a fluid loss additive. The optimization may further include adjusting the stimulation plan to achieve the optimized crossing behavior between the induced hydraulic fracture and the discontinuity in the formation.

Abstract: A system and method for minimizing the standoff effect on an imaging tool in a borehole are provided. The imaging tool may include a sensor assembly for transmitting current in the direction of the formation to obtain complex measurements having a real part and an imaginary part. The real-part measurement may be sensitive to, or affected by, the resistivity of the formation and the standoff of the imaging tool. The imaginary-part measurement may be affected by only to standoff. A computing device may determine a ratio using the imaginary-part measurement and corresponding to change in standoff at various imaging tool azimuths. The ratio may be applied to the real-part measurement to enhance the resolution of image data corresponding to formations adjacent to the wellbore.

Abstract: The present invention provides a methodology and system for formation boundary detection ahead and around of a drilling bit. By setting symmetrical design of receivers/transmitters around a transmitter/receiver and the direction of the receivers/transmitters, the system can measure the signals reflected by a formation boundary ahead of and around the drilling bit. The measured signals can be used to determine formation boundary positions.

Abstract: Embodiments of the disclosure include methods, machines, and non-transitory computer-readable medium having one or more computer programs stored therein to enhance core analysis planning for a plurality of core samples of subsurface material. Embodiments can include positioning electronic depictions of structure of encased core samples of subsurface material on a display and determining portions of each of the images as different planned sample types thereby to virtually mark each of the images. Planned sample types can include, for example, full diameter samples, special core analysis samples, conventional core analysis samples, and mechanical property samples. Embodiments further can include transforming physical properties of encased core samples of subsurface material into images responsive to one or more penetrative scans by use of one or more computerized tomography (CT) scanners.

Abstract: In an exemplary embodiment, a method is disclosed for developing an N-phasic finite element model for performing fully coupled analyses of multi-phase compositional fluid flow and heat flow in nonlinearly deforming porous solid media with time-dependent failure. The method can include formulating a finite element model of the behavior of a coupled solid-fluid formation, having complex geometry and behavior, and applying the model to derive the response of the formation in the form of one or more displacement fields for the solid phases and one or more pressure fields for the fluid phases in a zone of interest in a formation. In an exemplary embodiment, a system is disclosed for estimating the uncertainties in the derived displacement and pressure field solutions for the response of the fully coupled solid-fluid phases.

Abstract: Methods and apparatus for obtaining an indication of fluid inflow in a section of a gas well having multiple perforations through which fluids comprising gas and/or liquid enter the well are described. In an example, the temperature within the section of the gas well is monitored at a plurality of locations. The locations comprising (a) a first set of locations, at or near a perforation; and (b) a second set of locations at which the temperature is substantially independent of the effects of the inflow of gas at a perforation. An indication of temperature excursions at the locations is obtained and used to obtaining an indication of the inflow of fluids to the well by relating the indications of temperature excursions from the second set of locations to liquid inflow and relating the indications of temperature excursions from the first set of locations to liquid and gas inflow.

Abstract: An on-chip spectroscopic sensor includes a tunable diode laser. A laser driver for drives the tunable diode laser. An analyte test cavity receives a chemical sample and exposes the received chemical sample to light from the tunable diode laser. An optical detector detects light emerging from the analyte test cavity as a result of the laser exposure. A spectral analyzer determines a spectrum of the emerging light, matches and removes one or more known optical fringe patterns from the determined spectrum, and determines a composition or concentration of the chemical sample from the optical fringe pattern-removed spectrum.

Abstract: A technology is described for controlling an electric choke actuator included in a drilling rig. An example system can include a computing device configured to provide position data for an electric choke actuator configured to control a well choke valve in selective fluid communication with a blow-out preventer arranged to close a borehole. The system can receive a choke position command to move the electric choke actuator from a first position to a second position, whereupon a control signal can be sent to the electric choke actuator that causes the electric choke actuator to move from the first position to the second position. Position data for the electric choke actuator can be updated to indicate the second position.