Abstract: A hydrocarbon control system includes a base device, a field device, and a mobile device. The base device includes a key generator configured to generate a temporary key. The field device is configured to restrict or allow access based on verification of a received key. The mobile device is configured to communicate with the base device to receive the temporary key when in proximity of the base device, communicate with the field device to provide the temporary key to the field device when in proximity of the field device, and exchange data with the field device in response to the field device verifying the temporary key.

Abstract: A system for oil and gas production includes a drilling, pipeline, or power quality device, a sensor, and a storage device. The storage device has instructions stored thereon that, when executed by one or more processors, cause the one or more processors to perform operations. The operations include receiving first data from the sensor. The operations include determining whether the device is experiencing an event condition based on the first data The operations include generating one or more potential corrective actions responsive to a determination that the device is experiencing the event condition. The operations include calculating a reward value for each of the one or more potential corrective actions. The operations include identifying a first corrective action of the one or more potential corrective actions with a largest or most positive reward value The operations include controlling the device according to the first corrective action.

Abstract: A system and method to detect and quantify integration errors in a transit time ultrasonic flow meter uses dissimilar integration methods or schemes employed simultaneously. In a preferred embodiment, a number of chordal paths are arranged in a single meter body such that at least two dissimilar chordal integration schemes can be used to determine the flow rate. At least one of the chordal paths is common to both integration schemes. The total number of chordal paths needed in any chordal measurement plane is less than the sum of the chordal paths used in each of the integration schemes (as is the sum of the planes), thereby reducing hardware requirements.

Abstract: A method for evaluating operation of an electric submersible pumping (ESP) system is shown. The method includes receiving first sensor data from sensors monitoring operation of the ESP system. The method further includes using a physical model of the electric submersible pumping system to determine second sensor data. The method further includes processing the first sensor data and the second sensor data to determine an first system state as a function of operating time. The method further includes generating a degradation model and applying the degradation model to the first sensor data and the second sensor data to generate a time prediction. The method further includes adjusting operation of the electric submersible pumping system in response to the predictor of the time to failure of the components.

Abstract: A method for controlling an ESP-lifted well in an optimal fashion using the ESP speed and choke opening as actuators subject to operational constraints.

Abstract: A mobile clamp attaches to a steam pipe and converts thermal energy to electric energy. One side of the clamp is generally open to allow for insertion of the steam pipe. During insertion, opposing blocks on either side of the clamp are deflected apart. Each block includes a curved channel extending along the length of the block to receive the steam pipe. Fitting the steam pipe within the channel aligns the clamp on the steam pipe. A biasing force applied to the blocks to return each block to an initial position provides a clamping force on the steam pipe to positively retain the clamp on the pipe. Thermoelectric devices are mounted on the blocks to convert the thermal energy into electrical energy. Thermal energy is transmitted from the steam, through the steam pipe, through the block pressed against the steam pipe, and to the thermoelectric device.

Abstract: A method for determining conflicts in updates of a hydrocarbon control system includes obtaining a first configuration and a second configuration from different locations in the hydrocarbon control system. The method also includes comparing the first configuration and the second configuration to determine if differences are detected. If differences are detected, the method includes operating a display to notify a user that differences are detected, using conflict resolution techniques to automatically determine a resolved configuration, and updating a configuration of the hydrocarbon control system with the resolved configuration. If no differences are detected, the method includes operating the display to notify the user that no differences are detected and updating the configuration of the hydrocarbon control system with the first configuration or the second configuration.

Abstract: Systems and methods provided herein relate to a pump system. The pump system includes a pump disposed within a well, an actuator operable to move a rod including a surface end coupled to the actuator and a downhole end coupled to the pump, and a controller. The controller is configured to identify a first impulse response and a second impulse response associated with the pump system based on a first model of the pump system. The controller is further configured to generate a second model of the pump system based on the first impulse response and the second impulse response. The controller is further configured to operate the pump system based on the second model.

Abstract: A method for operating a pipeline system includes obtaining sensor data of a gas in the pipeline system from sensors of a sensing unit. The method also includes performing a real-time and closed loop control scheme using the sensor data and a material model of the gas to determine one or more control decisions. The method also includes operating one or more controllable pipeline elements to adjust a temperature, a pressure, a flow rate, or a composition of the gas according to the one or more control decisions.

Abstract: A system, method, and computer-readable medium for determining the flow rate and fluid density in an electrical submersible pump (ESP) and controlling the ESP based on the flow rate and density. In one implementation, an ESP system includes an ESP, drive circuitry, a current sensor, a voltage sensor, and a processor. The ESP includes an electric motor. The drive circuitry is electrically coupled to the ESP and is configured to provide an electrical signal to power the ESP. The current sensor is configured to measure a current of the electrical signal. The voltage sensor is configured to measure a voltage of the electrical signal. The processor is configured to calculate speed of a shaft of the electric motor based on a frequency induced by rotation of the motor detected in the current. The processor is also configured to calculate a density of fluid in the ESP based on the speed.

Abstract: A hydrocarbon control system includes a base device, a field device, and a mobile device. The base device includes a key generator configured to generate a temporary key. The field device is configured to restrict or allow access based on verification of a received key. The mobile device is configured to communicate with the base device to receive the temporary key when in proximity of the base device, communicate with the field device to provide the temporary key to the field device when in proximity of the field device, and exchange data with the field device in response to the field device verifying the temporary key.

Abstract: A system, method, and computer-readable medium for determining the flow rate and fluid density in an electrical submersible pump (ESP) and controlling the ESP based on the flow rate and density. In one implementation, an ESP system includes an ESP, drive circuitry, a current sensor, a voltage sensor, and a processor. The ESP includes an electric motor. The drive circuitry is electrically coupled to the ESP and is configured to provide an electrical signal to power the ESP. The current sensor is configured to measure a current of the electrical signal. The voltage sensor is configured to measure a voltage of the electrical signal. The processor is configured to calculate speed of a shaft of the electric motor based on a frequency induced by rotation of the motor detected in the current. The processor is also configured to calculate a density of fluid in the ESP based on the speed.

Abstract: A technique facilitates fluid flow measurement by providing a meter able to accurately monitor fluid flow of a liquid even if gas is present in the liquid. The meter may comprise a tubing with an internal flow passage and a wedge or other restriction extending into the internal flow passage. A first port is located upstream of the restriction and a second port is located downstream of the restriction to enable monitoring of a differential pressure across the restriction. The differential pressure can be used to determine the desired flow parameter, e.g. volumetric flow. The system facilitates separation of gas from the liquid and utilizes a gas bypass. The gas bypass routes the separated gas past the restriction, e.g. wedge, before directing the gas back into the fluid flow path.

Abstract: An edge device management system comprising a plurality of edge devices is shown. Each device includes a processing circuit configured to provide, via a first edge device of the plurality of edge devices, remote upgrades for an application of a second edge device of the plurality of edge devices. The processing circuit is configured to control hardware security features of the second edge device. The processing circuit is configured to configure a software update package for the second edge device, the software update package comprising a plurality of different software updates. The processing circuit is configured to deploy one or more deployment management tools to manage the application on the second edge device.

Abstract: A flow meter is shown. The flow meter includes a housing extending along an axis and defining an interior volume, the interior volume extending between an inlet port and an outlet port. The flow meter further includes an insert positioned within the interior volume and spaced apart from the housing, the insert extending along the axis. A first region between at least part of the insert and the housing along the axis defines a first flow pathway, and a second region within the insert and along the axis defines a second flow pathway.

Abstract: A hydrocarbon control system includes a base device, a field device, and a mobile device. The base device includes a key generator configured to generate a temporary key. The field device is configured to restrict or allow access based on verification of a received key. The mobile device is configured to communicate with the base device to receive the temporary key when in proximity of the base device, communicate with the field device to provide the temporary key to the field device when in proximity of the field device, and exchange data with the field device in response to the field device verifying the temporary key.

Abstract: A method can include operating a pump system; determining a condition associated with the pump system; and controlling the pump system based at least in part on the condition.

Abstract: A method can include operating a pump system; determining a condition associated with the pump system; and controlling the pump system based at least in part on the condition.

Abstract: A technique facilitates smart alarming, event detection, and/or event mitigation. The smart alarming may be achieved by, for example, automating detection processes and using advanced signal processing techniques. In some applications, event detection is enhanced by combining different alarms to facilitate diagnosis of a condition, e.g. a pump condition. The occurrence of certain unwanted events can be mitigated by automatically adjusting operation of a well system according to suitable protocols for a given event.

Abstract: A system and method to detect and quantify integration errors in a transit time ultrasonic flow meter uses dissimilar integration methods or schemes employed simultaneously. In a preferred embodiment, a number of chordal paths are arranged in a single meter body such that at least two dissimilar chordal integration schemes can be used to determine the flow rate. At least one of the chordal paths is common to both integration schemes. The total number of chordal paths needed in any chordal measurement plane is less than the sum of the chordal paths used in each of the integration schemes (as is the sum of the planes), thereby reducing hardware requirements.