Abstract: Systems and methods provided herein relate to a well site or other plant. Systems and methods are employed to determine fouling and/or reduce maintenance and down time associated with equipment that is subject to fouling conditions due to their operating environments in some embodiments. Fouling can include but is not limited to scale formation due to mechanical, thermal, chemical or combinations of such phenomenon. These phenomenon are initiated and progressively exacerbated as the equipment interacts with gaseous, solids and/or liquids from the operating environment. The equipment includes stationary and rotary equipment including but not limited to pump systems, valves, piping, heat exchangers, and plumbing utilized to move fluid in a well in a subterranean environment.

Abstract: Systems and methods provided herein relate to optimization of the motor of a pump system. Voltage-frequency ratios are adjusted while maintaining pumps speed in a systematic manner to lower power usage. Oscillations of the motor speed are detected, and voltage-frequency ratios adjusted to maintain low levels of oscillations while lowering power usage. Savings resulting in the optimization of the pump system are estimated.

Abstract: A system includes a capacitive sensor and a processor. The capacitive sensor is configured to measure a first capacitance along a first path through a fluid and a second capacitance along a second path through the fluid. The processor is configured to receive sensor data from the capacitive sensor corresponding to the first capacitance and the second capacitance. The processor is also configured to determine a first value of a fluid property of the fluid based on the first capacitance. The processor is also configured to determine a second value of the fluid property of the fluid based on the second capacitance. The processor is also configured to operate a display device to provide the variation to a user in response to determining that a variation between the first value of the fluid property and the second value of the fluid property is above a predetermined threshold.

Abstract: Systems and methods provided herein relate to a power system, such as a system for a motor. A digital acquisition unit is configured to receive current sense signals associated with a motor and phase voltage power signals associate the motor. The data acquisition unit includes a module coupled to a first ground and an attenuator circuit coupled to a second ground. The first ground is isolated from the second ground. The phase voltage power signals are provided to the attenuator, and the attenuator provides phase voltage sense signals to the module.

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 system for oil and gas production includes a drilling, pipeline, or power quality equipment, a sensor, and a storage device having 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, determining whether the drilling, pipeline, or power quality equipment is experiencing an event condition based on the first data, generating one or more potential corrective actions, identifying a first corrective action of the one or more potential corrective actions, and controlling a fluid transfer device to implement the first corrective action. The first corrective action includes at least one of increasing a drive frequency of the fluid transfer device, adjusting a choke position of the fluid transfer device, or reversing a rotational direction of an impeller of the fluid transfer device.

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 method executable by one or more processors includes obtaining a measured value of a first variable at a current time step, estimating, with a first model, an estimated value of a second variable at the current time step based on the measured value of the first variable, generating, by a reinforcement learning model, a control decision for a subsequent time step based on the measured value of the first variable and the estimated value of the second variable, predicting, with a second model, a predicted value of the first variable for the subsequent time step based on the measured value of the first variable at the current time step, adjusting the control decision for the subsequent time step based on a constraint and the future value of the first variable, and controlling an actuator based on the control decision.

Abstract: Systems and methods provided herein relate to a well site or other plant. Systems and methods are employed to determine fouling and/or reduce maintenance and down time associated with equipment that is subject to fouling conditions due to their operating environments in some embodiments. Fouling can include but is not limited to scale formation due to mechanical, thermal, chemical or combinations of such phenomenon. These phenomenon are initiated and progressively exacerbated as the equipment interacts with gaseous, solids and/or liquids from the operating environment. The equipment includes stationary and rotary equipment including but not limited to pump systems, valves, piping, heat exchangers, and plumbing utilized to move fluid in a well in a subterranean environment.

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 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 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 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: Systems and methods generate and use a digital twin in a hydrocarbon system. The systems and methods can perform the following operations: (1) performing a plurality of simulations in a hyperdimensional space to generate outputs; (2) using the outputs of the plurality of simulations to generate one or more reduced order models (ROMs) using a regression technique or a machine learning technique; (3) generating a digital twin of the hydrocarbon system by instantiating the one or more ROMs at an operational point of the hydrocarbon system, and configuring the digital twin to use real-time data obtained from the hydrocarbon system; and (4) estimating values of one or more variables of the hydrocarbon system in real-time using the digital twin.

Abstract: An electric submersible pump system can include a multiphase electric motor operatively coupled to a fluid pump; a multiphase power cable operatively coupled to the multiphase electric motor; and a controller that includes an input that receives measurements as to power supplied to the multiphase electric motor via the multiphase power cable and that processes the measurements to determine information germane to the operation of the electric submersible pump system.

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

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 method can include receiving sensor information from at least one sensor disposed in a downhole environment that includes an electric submersible pump operatively coupled to a power drive via a cable; receiving electrical information associated with transmission of power via the cable; and identifying a state of the electric submersible pump via an adaptive model of at least the cable and the electric submersible pump based at least in part on a portion of the sensor information and a portion of the electrical information.

Abstract: An electric submersible pump system can include a multiphase electric motor operatively coupled to a fluid pump; a multiphase power cable operatively coupled to the multiphase electric motor; and a controller that includes an input that receives measurements as to power supplied to the multiphase electric motor via the multiphase power cable and that processes the measurements to determine information germane to the operation of the electric submersible pump system.