Abstract: Methods for operating a decoupled long stroke pump to pump treatment fluid to a wellbore are provided. The decoupled long stroke pump has relatively long stroke plungers that can be powered by hydraulics, linear electric motors, mechanical long stroke mechanisms, linear actuators, or any other device that can provide a linear force to the plungers. Such long stroke pumps have the suction and discharge strokes decoupled such that an absolute linear flow rate without pressure pulses on the suction or discharge can be produced. Any desired flow profile of the treatment fluid can be produced via the decoupled long stroke pump.

Abstract: An active accumulator system which automatically adjusts or adapts the charge pressure or volume of an accumulator to maintain an optimal charge pressure or volume of the accumulator may provide optimal operation of a pump. An active accumulator system may comprise a flow line coupled to a pump, wherein a fluid flows through the flow line to the pump, an accumulator coupled to the flow line, a transducer coupled to the pump, wherein the transducer detects a parameter of the pump at an inlet of the pump, and a controller coupled to the transducer and the accumulator, wherein the controller receives the parameter, and wherein the controller regulates air flow to the accumulator such that the accumulator is adjusted to an optimal charge pressure based at least in part on the parameter.

Abstract: A method and system pulse for treating a plurality of wells simultaneously includes applying a high pressure of fracturing fluid to one or more switching valves and repeatedly opening and closing the one or more switching valves to divert the fracturing fluid near instantaneously from one well to the other well to creating a pulse wave into the plurality of wells for fracturing subterranean formations. The one or more switching valves may be a single 3-way valve incorporating the function of two or more switching valves. This technique reduces wear of surface equipment including high pressure pumps that need only provide a constant pressure.

Abstract: The present disclosure relates generally to well operations. The present disclosure relates more particularly to a systems and methods for independently and/or simultaneously treating multiple wells from a centralized location using a split flow pumping system configuration. The split flow pumping system configuration may comprise one or more blenders, one or more boost pumps, a pumping system comprising one or more pumps, a component storage system, and a fluid storage system for treatment of two or more wells using two or more treatment compositions. The split flow pumping system configuration may comprise one or more controllers for controlling the one or more blenders, the one or more boost pumps, the pumping system comprising one or more pumps, the component storage system, and the fluid storage system.

Abstract: A system for use in hydraulic fracturing of at least one reservoir. The system including at least one pump for injecting a friction modifier into a wellbore, at least one friction modifier controller for controlling an amount of friction modifier channeled through at least one well bore, and at least one injector. The friction modifier controller is configured to monitor at least one of a fluid flow rate and pressure associated with each wellbore, compare the at least one of the fluid flow rate and the pressure with at least one of a desired flow rate and desired pressure, and adjust a friction modifier level for at least one wellbore based on results of the comparison. The injector is configured to control the pump to deliver an amount of a friction modifier into the wellbore based on the friction modifier level.

Abstract: Disclosed herein are methods and system for redistributing bulk material across a geographical area. A method for providing bulk material for a wellbore operation, the method comprising: forming a logistical model database to determine bulk material required for an at least one wellsite located in a geographical area; acquiring bulk material from a distribution center; verifying the bulk material acquired; and transporting bulk material for the wellbore operation. A method for providing bulk material for a wellbore operation, the method comprising: determining demand for bulk material across a geographical area; collecting data throughout a life cycle of bulk material; transmitting collected data to an off-site network comprising an adaptive machine; analyzing collected data via the off-site network thereby producing an output; providing bulk material to a wellsite based on output.

Abstract: At a well site, equipment will need a power source, such as a gas turbine, to operate. As the gas turbine operates, wasted energy in the form of heat is produced as a result of the efficiency of the gas turbine. With regards to the present disclosure, the heat may be used for operations and treatments at the well site. An embodiment of the present disclosure is a heat recovery system, comprising a gas turbine; a first heat exchanger, wherein the first heat exchanger is a finned-tube heat exchanger; and a second heat exchanger, wherein the second heat exchanger is a tube and shell heat exchanger, wherein the first heat exchanger is disposed in the flow path of an exhaust stream of the gas turbine, wherein the first heat exchanger is fluidly coupled to the second heat exchanger.

Abstract: A system may include multiple strain gauges and multiple position sensors positioned on multiple pressure pumps. The strain gauges may measure strain in chambers of the pressure pumps. The position sensors may measure positions of rotating members of the pressure pumps. One or more computing devices may be communicatively couplable to the strain gauges and the position sensors to determine an adjustment to a flow rate of fluid through at least one pump using a strain measurement and a position measurement for the at least one pump such that a timing of changes in composition of the fluid delivered to into a first manifold at an input for the pressure pumps matches the timing of the changes in composition of the fluid delivered from a second manifold at an output for the pressure pumps.

Abstract: A pump system and method of operating the same may utilize two relatively smaller turbines that are attached to and used to power a single pump. The two turbines are releasably coupled to the pump via respective one-way clutches, thereby enabling the use of one or both turbines at a time to power the pump. At low loads (e.g., low pump outputs), only one turbine operates to power the pump, and at higher loads (e.g., high pump outputs), both turbines operate to power the pump. By using two smaller turbines instead of one large turbine, the range-ability of the turbine power at the most efficient operating ranges is increased. This improves the fuel efficiency of the pump system. In addition, the dual turbine driven pump system provides increased reliability by preventing the loss of all power to the pump in the event of a turbine malfunction.

Abstract: An injection pumping system is used to generate pressure pulses in a wellbore to create pressure spikes for stimulation treatment of the wellbore. An initial pressure pulse is generated with a known travel time from the surface to a termination point and back to a specified location within the wellbore. A subsequent pressure pulse with a known travel time from the surface to the specified location can be generated to collide with the initial pressure pulse at the specified location. Knowing the speed of sound throughout the wellbore allows for an accurate calculation of the required travel times for each of the pressure pulses. Multiple sections of the wellbore can be treated preferentially and independently without requiring multiple runs of a perforating tool as the pressure pulses can be manipulated to collide at different locations throughout the wellbore based on the known travel times.

Abstract: Certain conditions require powering down an engine driving a pump. During the down sequence the pump may continue pumping servicing fluid which may not be desirable. Activating one or more control valves may throttle or prevent the servicing fluid from being pumped from the pump during the power down sequence. Activation of an input control valve may introduce pressurized fluid into a cylinder of the pump extending a rod to force or maintain a suction valve in an open position. While the suction valve is in the open position, the stroke of the plunger may not create enough pressure to pump the servicing fluid causing the servicing fluid to flow between a fluid header and a chamber of the pump. Activation of an output control valve may divert servicing fluid pumped from the pump to a reservoir instead of to the desired location.

Abstract: Included are methods and systems for enhancing recovery of a hydrocarbon fluid. An example method includes selecting a liquefied natural gas capable of being processed into a modified liquefied natural gas having a desired composition and adjusting the composition of the liquefied natural gas to provide the modified liquefied natural gas with the desired composition. The method further includes preparing a treatment fluid from the modified liquefied natural gas, introducing the treatment fluid into a wellbore, and contacting the hydrocarbon fluid with the treatment fluid in the wellbore.

Abstract: A fluid injection system for injecting a particulate in a fluid, including a high-pressure pump operable to output the fluid from an outlet flow channel and a reservoir configured to hold the particulate. The system also includes a valve assembly in fluid communication with the reservoir and the outlet flow channel of the pump, the valve assembly operable to discharge the particulate into a fluid stream output by the pump while the reservoir is sealed from the outlet flow channel of the pump.

Abstract: One or more wellbore servicing operations may require the pulsed delivery of a wellbore servicing fluid. To optimize efficiency and effectives of a given wellbore servicing operation a concentrated proppant stimulation fluid may be pumped downhole at a predetermined time interval from dedicated pumping units or positive displacement pumps. The flow rate of proppant in the concentrated proppant stimulation fluid pumped from these dedicated pumps may simulate a square-wave. The desired or determined square-wave or output may be predetermined and any one or more dedicated pumps may be associated with a given time interval and pumping cycle or phasing such that the overall flow of proppant from all of the dedicated pumps simulates a square-wave. Clean fluid from one or more clean fluid pumps may be combined with the concentrated proppant stimulation fluid to maintain a target flow rate of fluid downhole.

Abstract: A method includes monitoring work done by a piece of equipment to generate backward-looking usage data. The method includes making a prediction of future work to be done by the piece of equipment, generating forward-looking usage data based on the prediction of future work, and making a prediction of when the piece of equipment is expected to fail based on the backward-looking usage data and on the forward-looking usage data. The method includes operating the piece of equipment after performing the prediction, and removing the piece of equipment from service prior to when the piece of equipment is expected to fail based on the prediction.

Abstract: Well production enhancement systems and methods to enhance well production are disclosed. The method includes deploying an outer conveyance into a wellbore, where a plurality of propellants are deployed along a section of the outer conveyance. The method also includes deploying one or more isolation devices to form one or more isolation zones along the outer conveyance. The method further includes deploying an inner conveyance within the outer conveyance, where the inner conveyance is initially deployed along the section of the outer conveyance. The method further includes detonating the plurality of propellants to generate one or more fractures in a formation proximate to the section of the outer conveyance. The method further includes injecting fracture enhancement fluids into the one or more fractures to enhance well production through the one or more fractures.

Abstract: An intensifier pump includes a piston including at least two selectable piston diameters. Additionally, the intensifier pump includes a plunger that in operation interacts with the piston. The plunger includes a plunger diameter that is smaller than each of the at least two selectable piston diameters.

Abstract: Certain conditions or triggering events require preventing or throttling the discharge of a servicing fluid from a pump to a wellhead or a borehole. Powering down may not be desirable or may require a duration that allows the condition or triggering event to persist. Selectively and automatically activating one or more pressure control valves may throttle or prevent the servicing fluid from being pumped from the pump during the power down sequence or without requiring a power down sequence. Selective activation of a pressure control valve may introduce pressurized fluid into a cylinder of the pump extending a rod to force or maintain a suction valve in an open position. While the suction valve is in the open position, the stroke of the plunger may not create enough pressure to pump the servicing fluid causing the servicing fluid to flow between a fluid header and a chamber of the pump.

Abstract: A pumping system pumps material downhole, for example, to perform a fracturing operation. The pumping system comprises one or more variable speed engines, one or more variable displacement hydraulic pumps and one or more intensifiers. According to the desired or required load, the speed of the engine is set at an optimal or most efficient operating speed. The volumetric displacement of the variable displacement hydraulic pump is set to provide the desired output volume and pressure of the material from the intensifier. Varying the speed of the engine and the volumetric displacement of the variable displacement pump allows for the pumping system and in particular the engine to operate at an optimal efficiency which reduces at least fuel costs and wear and tear on components.

Abstract: A method and system pulse for treating a plurality of wells simultaneously includes applying a high pressure of fracturing fluid to one or more switching valves and repeatedly opening and closing the one or more switching valves to divert the fracturing fluid near instantaneously from one well to the other well to creating a pulse wave into the plurality of wells for fracturing subterranean formations. The one or more switching valves may be a single 3-way valve incorporating the function of two or more switching valves. This technique reduces wear of surface equipment including high pressure pumps that need only provide a constant pressure.