Abstract: A distributed control system can be used to implement failover capabilities for control units that control well equipment during a well operation. For example, a system can include first well equipment that performs a first physical task and second well equipment that performs a second physical task different from the first physical task. Additionally, the system can include a distributed control system with a first control unit coupled to the first well equipment and a second control unit coupled to the second well equipment. Both control units may include a first control module and a second control module for automatically controlling the first physical task and the second physical task, respectively. The distributed control system can detect a failure of the second control unit and initiate a failover process in which the first control unit takes over control of the second physical task by enabling the second control module.

Abstract: A method of controlling a pumping stage of a fracturing fleet at a wellsite with a set of electric frac pumps to deliver fracturing fluids into a target formation at a steady pressure value. An global control process on a computer system communicatively connected to the plurality of pumping units can communicate a unit setpoint to each pumping unit, monitor the sensor measurements, compare the periodic datasets to a target pressure, and modify the fluid output of the pump units to achieve the target pressure during the pumping operation. The global control process can direct at least one pumping unit to deliver a fracturing treatment at a pressure higher or lower than the target pressure in response to changing wellbore environment pressures.

Abstract: This disclosure presents processes for controlling a hydraulic fracturing operation at a wellbore. The processes can determine power available from each of one or more individual power sources. From the determined power available from the power sources, parasitic power losses, existing power consumed by one or more loads of the hydraulic fracturing operation, a threshold power level, or a combination thereof, the processes can determine an incremental power available to the one or more loads. The processes communicate the incremental power available to the one or more loads. The hydraulic fracturing operation is then controlled by processes based on the incremental power available to the one or more loads.

Abstract: A method of controlling a pumping stage of a fracturing fleet at a wellsite with a set of electric frac pumps to deliver fracturing fluids into a target formation at a steady pressure value. An global control process on a computer system communicatively connected to the plurality of pumping units can communicate a unit setpoint to each pumping unit, monitor the sensor measurements, compare the periodic datasets to a target pressure, and modify the fluid output of the pump units to achieve the target pressure during the pumping operation. The global control process can direct at least one pumping unit to deliver a fracturing treatment at a pressure higher or lower than the target pressure in response to changing wellbore environment pressures.

Abstract: To compensate for an event, equipment may require a power down sequence of a motor connected to a pump to prevent the pumping of servicing fluid at a high pressure, high pressure fluid may be required to be diverted to a reservoir or otherwise diverted from a wellhead, multiple pumping systems may require that pumping pressure be altered or adjusted or that flow rate be altered or adjust to manage or control the conditions to protect equipment or personnel at a site. Activating, adjusting or altering an operational characteristic of equipment by using a control system may automatically initiate the most efficient and effective mitigation steps for equipment at a site when condition is detected or predicted. Collecting and analyzing information from devices, components, sensors, control systems, other equipment or any combination thereof at a site by a master control system provides automated control of pressure sensitive conditions.

Abstract: A method of performing a wellbore operation may include providing a real-time treatment decision engine, equipment centric decision engine, and equipment controls. The equipment centric decision engine may be configured to interface with the real-time treatment decision engine and the equipment controls. The equipment centric decision may include an operational database comprising wellbore servicing equipment models. The method may further include providing wellbore servicing equipment. The wellbore servicing equipment may be operable to be controlled by the equipment controls. The method may further include sending a command from the real-time treatment decision engine to the equipment centric decision engine. The method may further include evaluating the command using the wellbore servicing equipment models. The method may further include selecting equipment to carry out the command based at least in part on the wellbore servicing equipment models.

Abstract: Systems, methods, and apparatuses of the present disclosure generally relate to on-site logistics using autonomous delivery vehicles in organized use sites. A system for on-site logistics includes a plurality of containers that are organized by type, each container including an identification tag. The system also includes at least three signal beacons configured to at least emit or receive signals, and at least one autonomous material handling device configured to locate the containers, move the containers, and store delivery points of the containers, wherein the at least one autonomous material handling device is in communication with the at least three signal beacons.

Abstract: A pumping system pumps material or fluid, for example, downhole to perform a stimulation operation. A pumping system may comprise multiple pumps that must be powered-up in a sequence that does not overload a power source. A variable frequency drive may be coupled to a pump via a motor and may adjust the speed of the motor to control the rate of pumping of fluid from the pump. A soft-starter may be coupled to a pump via a motor to provide a constant pumping rate of fluid from the pump. A power-up sequence may be determined that provides power to the variable frequency pump and the soft-starter to power-up the corresponding motors such that the power source is not strained or overloaded. Mixing variable frequency drive driven pumps with pumps driven by a soft-starter may provide an efficient use of available power, conserve space, allow for control over a pumping rate of fluid and reduce costs.

Abstract: A pumping system pumps material or fluid, for example, downhole to perform a stimulation operation. A pumping system may comprise multiple pumps that must be powered-up in a sequence that does not overload a power source. A variable frequency drive may be coupled to a pump via a motor and may adjust the speed of the motor to control the rate of pumping of fluid from the pump. A soft-starter may be coupled to a pump via a motor to provide a constant pumping rate of fluid from the pump. A power-up sequence may be determined that provides power to the variable frequency pump and the soft-starter to power-up the corresponding motors such that the power source is not strained or overloaded. Mixing variable frequency drive driven pumps with pumps driven by a soft-starter may provide an efficient use of available power, conserve space, allow for control over a pumping rate of fluid and reduce costs.

Abstract: To compensate for an event, equipment may require a power down sequence of a motor connected to a pump to prevent the pumping of servicing fluid at a high pressure, high pressure fluid may be required to be diverted to a reservoir or otherwise diverted from a wellhead, multiple pumping systems may require that pumping pressure be altered or adjusted or that flow rate be altered or adjust to manage or control the conditions to protect equipment or personnel at a site. Activating, adjusting or altering an operational characteristic of equipment by using a control system may automatically initiate the most efficient and effective mitigation steps for equipment at a site when condition is detected or predicted. Collecting and analyzing information from devices, components, sensors, control systems, other equipment or any combination thereof at a site by a master control system provides automated control of pressure sensitive conditions.

Abstract: A job plan may be developed far in advance of actual execution of any one or more specified well servicing operations. To account for all the factors, parameters or conditions that occur at an actual well site a revised job plan may be generated that accounts for the actual site equipment available, environmental factors, one or more costs, available power source, optimal operation of equipment and any other factors. Any one or more of the factors may be weighted according to a particular physical location or other factors of the job plan. Correlating the collected, known, and actual information about equipment and a physical location allows for the generation of an optimized revised job plan that provides better utilization of equipment, including power sources, and control of costs.