A system comprises an electric submersible pump (ESP) motor electrically coupled to a variable speed drive (VSD) that outputs voltage to the ESP motor. The system comprises a magnet on a shaft of the ESP motor and a downhole sensor coupled to the magnet, wherein the downhole sensor is to measure a magnetic flux of the magnet. The system comprises a VSD controller to control the VSD, wherein the VSD controller comprises a processor and a non-transitory memory storage having instructions stored thereon that are executable by the processor to perform operations comprising: obtaining a measurement of at least one pump performance variable and a motor current for a first period of time to establish a first data set and making a first adjustment to a voltage output from the VSD to the ESP motor, the first adjustment having a first adjustment type.

One or more sensors are mounted on a collar proximate to a motor shaft of a motor. The motor is associated with an electric submersible pump (ESP) located in a wellbore of a geological formation. The one or more sensors sense one or more identifiers located on the motor shaft of the motor. One or more of a rotation direction and rotation speed of the motor shaft is determined based on the sensing of the one or more identifiers. The motor is powered to pump fluid from a reservoir in the geological formation to a surface of the geological formation based on the one or more of the rotation direction and rotation speed of the motor shaft.

One or more sensors are mounted on a collar proximate to a motor shaft of a motor. The motor is associated with an electric submersible pump (ESP) located in a wellbore of a geological formation. The one or more sensors sense one or more identifiers located on the motor shaft of the motor. One or more of a rotation direction and rotation speed of the motor shaft is determined based on the sensing of the one or more identifiers. The motor is powered to pump fluid from a reservoir in the geological formation to a surface of the geological formation based on the one or more of the rotation direction and rotation speed of the motor shaft.

Raw signal measurements can be received by sensors in a wellbore. Borehole effects can affect the raw signal measurements. The raw signal measurements can be converted into ratio signals having attenuation and phase shift. An apparent resistivity can be determined from the ratio signals. Mud resistivity can be determined based on apparent resistivity, at least part of the raw signal measurements, and the borehole size. A true resistivity can be determined based on the mud resistivity and at least part of the ratio signals. The raw signal measurements and the ratio signals can be updated based on the true resistivity. Steps can be repeated to determine a corrected true resistivity. Based on the true resistivity value and updated raw signal measurements and ratio signals, an operating characteristic of a well tool can be caused to be adjusted.

Raw signal measurements can be received by sensors in a wellbore. Borehole effects can affect the raw signal measurements. The raw signal measurements can be converted into ratio signals having attenuation and phase shift. An apparent resistivity can be determined from the ratio signals. Mud resistivity can be determined based on apparent resistivity, at least part of the raw signal measurements, and the borehole size. A true resistivity can be determined based on the mud resistivity and at least part of the ratio signals. The raw signal measurements and the ratio signals can be updated based on the true resistivity. Steps can be repeated to determine a corrected true resistivity. Based on the true resistivity value and updated raw signal measurements and ratio signals, an operating characteristic of a well tool can be caused to be adjusted.

A method to estimate the likely downhole conditions in the wellbore and reservoir by Inverse modeling well flow simulation history matched with field sensor data. The invention presents a method for automating sensor data processing through cleaning, transformation, and identification of stable states. This process is crucial for the selection of data to be simulated and matched without human review. The matched simulations are subjected to a state-space model in order to assign a probability to a given unknown state. This probability is updated at each time step. As the well undergoes transition over time including decline, the drift of the likely state of operation is orchestrated to allow physically constrained movement to a proximate space. Based on the extent of repetition and overlap between similar states as they transition over several time steps, the confidence of the inverse model increases, thus narrowing down the likely domain and trajectory of operation and boosting the probability of this narrowed zone. The knowledge of downhole and near wellbore reservoir zone is essential for better modeling, understanding of the wells and decision making in the oilfield. This knowledge may be obtained through well testing but involves physical intervention that can involve expense and production loss. It is also less common to have such well tests being performed at a daily, weekly or even monthly basis so timely information is generally not available. This invention provides a mechanism to have a live update of such information without any physical intervention.

A method to estimate the likely downhole conditions in the wellbore and reservoir by Inverse modeling well flow simulation history matched with field sensor data. The invention presents a method for automating sensor data processing through cleaning, transformation, and identification of stable states. This process is crucial for the selection of data to be simulated and matched without human review. The matched simulations are subjected to a state-space model in order to assign a probability to a given unknown state. This probability is updated at each time step. As the well undergoes transition over time including decline, the drift of the likely state of operation is orchestrated to allow physically constrained movement to a proximate space. Based on the extent of repetition and overlap between similar states as they transition over several time steps, the confidence of the inverse model increases, thus narrowing down the likely domain and trajectory of operation and boosting the probability of this narrowed zone. The knowledge of downhole and near wellbore reservoir zone is essential for better modeling, understanding of the wells and decision making in the oilfield. This knowledge may be obtained through well testing but involves physical intervention that can involve expense and production loss. It is also less common to have such well tests being performed at a daily, weekly or even monthly basis so timely information is generally not available. This invention provides a mechanism to have a live update of such information without any physical intervention.

Systems and methods of restarting a downhole pump for pumping downhole fluid and located in a wellbore that include determining a pump reverse rotational frequency of a downhole pump caused by downhole fluid flowing in a downhole direction using a phase locked loop. A pump motor is driven at a motor reverse rotational frequency matching the pump reverse rotational frequency. The pump motor is then driven to accelerate the pump reverse rotational frequency and thereby pump the downhole fluid in an uphole direction. The pump motor is then driven to decrease the pump reverse rotational frequency while continuing to pump the downhole fluid in the uphole direction. The pump motor is then driven to change the rotation of the downhole pump to a forward rotation at a pump forward rotational frequency to pump the downhole fluid in the uphole direction.

Systems and methods for exchanging fracturing components of a hydraulic fracturing unit and may include an exchangeable fracturing component section to facilitate quickly exchanging a fracturing component of a hydraulic fracturing unit. The fracturing component section may include a section frame including a base, and a fracturing component connected to the base. The fracturing component section also may include a component electrical assembly and a component fluid assembly connected to the section frame. The fracturing component section further may include a coupling plate connected to the section frame. The fracturing component section also may include one or more of a plurality of quick-connect electrical couplers or a plurality of quick-connect fluid couplers connected to a coupling plate. The quick-connect electrical and fluid couplers may be positioned to receive respective electrical and fluid connections of the component electrical and fluid assemblies and connect to other portions of the hydraulic fracturing unit.

Systems and methods for exchanging fracturing components of a hydraulic fracturing unit and may include an exchangeable fracturing component section to facilitate quickly exchanging a fracturing component of a hydraulic fracturing unit. The fracturing component section may include a section frame including a base, and a fracturing component connected to the base. The fracturing component section also may include a component electrical assembly and a component fluid assembly connected to the section frame. The fracturing component section further may include a coupling plate connected to the section frame. The fracturing component section also may include one or more of a plurality of quick-connect electrical couplers or a plurality of quick-connect fluid couplers connected to a coupling plate. The quick-connect electrical and fluid couplers may be positioned to receive respective electrical and fluid connections of the component electrical and fluid assemblies and connect to other portions of the hydraulic fracturing unit.