Systems/methods for real-time monitoring and control of a well site provide an event monitor and detector for progressing cavity pump (PCP) operations at the well site. The event monitor and detector uses machine learning (ML) based anomaly detection to detect operations that fall outside normal PCP operating space. The event monitor and detector then computes novelty scores for the anomalies and checks whether the novelty scores exceed a threshold novelty score. If the number of novelties detected within a given detection window exceeds a minimum threshold count, then the event monitor and detector flags an “event” and automatically responds accordingly. The event monitor and detector also provides an explanation with the alerts that quantifies the extent to which various PCP parameters contributed to the event. The event monitor and detector further performs drift detection to determine whether an event may be due to operator-initiated adjustments to PCP parameters.

Systems and methods to pump fracturing fluid into a wellhead may include a gas turbine engine including a compressor turbine shaft connected to a compressor, and a power turbine output shaft connected to a power turbine. The compressor turbine shaft and the power turbine output shaft may be rotatable at different rotational speeds. The systems may also include a transmission including a transmission input shaft connected to the power turbine output shaft and a transmission output shaft connected to a hydraulic fracturing pump. The systems may also include a fracturing unit controller configured to control one or more of the rotational speeds of the compressor turbine shaft, the power turbine output shaft, or the transmission output shaft based at least in part on target signals and fluid flow signals indicative of one or more of pressure or flow rate associated with fracturing fluid pumped into the wellhead.

A variable displacement pump for supplying fluid to a system is described. Controlling the variable displacement pump is determined based upon inputs from a fluidic pressure sensor and an accelerometer, and includes determining a desired fluidic pressure and monitoring, via the fluidic pressure sensor, an actual fluidic pressure. A pressure error term is determined based upon a difference between the actual fluidic pressure and the desired fluidic pressure. A time-integrated pressure error term is determined based upon the pressure error term, and a g-force is determined based upon an input signal from the accelerometer. The variable displacement pump is controlled in response to the time-integrated pressure error term when the g-force is greater than a threshold g-force.

There is provided a technique that includes: a controller configured to execute a process recipe including a plurality of steps to perform a predetermined process on a substrate. The controller acquires device data, which includes at least one of a current value, a rotational speed, and a back pressure of a pump, in a specific step among the plurality of steps and compares an acquired value of the device data with a previously acquired value of the device data. The controller generates a notification if at least one of the following conditions is met: the acquired value for the current value is larger than the previously acquired value for the current value, the acquired value for the back pressure is larger than the previously acquired value for the back pressure, and the acquired value for the rotational speed is smaller than the previously acquired value for the rotational speed.

A lockout system for a metering pump is provided. The lockout system can include a user interface that is used to switch the pump between a locked configuration and an unlocked configuration. In the locked configuration, the operation of the pump cannot be adjusted through the user interface. In the unlocked configuration, the operation of the pump can be adjusted through the user interface. The lockout system can include a passkey notice that provides information regarding how to use the user interface to switch the pump between the locked and unlocked configurations.

The present disclosure provides a device for monitoring oil pressure in an oil cylinder of a diaphragm compressor, including a piston rod and a strain gauge circuit. The strain gauge circuit includes a strain gauge component and a bridge circuit connected, and the strain gauge component is arranged on the surface of the piston rod. A strain gauge component is noninvasively arranged on the piston rod of the diaphragm compressor to measure the load of the piston rod, such that the oil pressure can be measured indirectly, and thus the oil pressure of the diaphragm compressor can be measured nondestructively. Nondestructive and noninvasive monitoring of the diaphragm compressor is safe and reliable, and can achieve accurate monitoring of the oil pressure especially in high-pressure working conditions.

An example system includes a fluid end having a block, a fluid inlet formed in the block, and a fluid outlet formed in the block. The system also includes an intake manifold fluidly coupled to the fluid inlet, and a fluid conduit fluidly coupled to the fluid outlet and the intake manifold. The system further includes a valve fluidly coupled to the fluid conduit, the valve configured to control fluid flow through the fluid conduit, an actuator coupled to the valve and configured to position the valve in an open position or a closed position, and a controller communicatively coupled to the actuator and configured to send one or more signals to the actuator, causing the actuator to position the valve in the open position or the closed position.

A system for controlling a pump can include a fluid level sensor, a fuel level sensor, one or more oil pressure sensors, a pump fluid sensor, and a pump controller. The pump controller can provide speed instructions to a pump having an engine control unit, an engine, and a volute. The pump controller can include a user interface that includes a display and may also include a transceiver that is operatively engaged to a remote user device through a computer network. A method of controlling a pump can include characterizing the operation of the pump, performing a safety check of the pump, determining a level of a fluid in a tank, and providing the speed instructions to the pump.

Systems and methods to pump fracturing fluid into a wellhead may include a gas turbine engine including a compressor turbine shaft connected to a compressor, and a power turbine output shaft connected to a power turbine. The compressor turbine shaft and the power turbine output shaft may be rotatable at different rotational speeds. The systems may also include a transmission including a transmission input shaft connected to the power turbine output shaft and a transmission output shaft connected to a hydraulic fracturing pump. The systems may also include a fracturing unit controller configured to control one or more of the rotational speeds of the compressor turbine shaft, the power turbine output shaft, or the transmission output shaft based at least in part on target signals and fluid flow signals indicative of one or more of pressure or flow rate associated with fracturing fluid pumped into the wellhead.

Systems and methods to pump fracturing fluid into a wellhead may include a gas turbine engine including a compressor turbine shaft connected to a compressor, and a power turbine output shaft connected to a power turbine. The compressor turbine shaft and the power turbine output shaft may be rotatable at different rotational speeds. The systems may also include a transmission including a transmission input shaft connected to the power turbine output shaft and a transmission output shaft connected to a hydraulic fracturing pump. The systems may also include a fracturing unit controller configured to control one or more of the rotational speeds of the compressor turbine shaft, the power turbine output shaft, or the transmission output shaft based at least in part on target signals and fluid flow signals indicative of one or more of pressure or flow rate associated with fracturing fluid pumped into the wellhead.