Implementations described herein relate to apparatus and methods for using a membrane pump to establish fracking pressure. Apparatus described herein includes, in place of mechanical pumps such as piston and impeller pumps, one or more membrane pumps are employed in a fluid circuit to increase the pressure of the fracking fluid. In operation of this system, a clean fluid circuit is used to pressurize clean fluid, transfer that pressure into the dirty fluid, and then return the clean fluid to a storage, and a dirty fluid circuit flows the dirty fluid from a storage, to the membrane pump to be pressurized, and then into a well bore to pressurize a formation penetrated by the well bore.

A system for hydraulically fracturing an underground formation in an oil or gas well, including a pump for pumping hydraulic fracturing fluid into the wellbore, the pump having a pump shaft, and an electric motor with a motor shaft mechanically attached to the pump to drive the pump. The system further includes a torsional coupling connecting the motor shaft to the pump shaft. The torsional coupling includes a motor component fixedly attached to the motor shaft and having motor coupling claws extending outwardly away from the motor shaft, and a pump component fixedly attached to the pump shaft of the pump and having pump coupling claws extending outwardly away from the pump shaft. The motor coupling claws engage with the pump coupling claws so that when the motor shaft and motor component rotate, such rotation causes the pump component and the pump shaft to rotate, thereby driving the pump.

A system for hydraulically fracturing an underground formation in an oil or gas well, including a pump for pumping hydraulic fracturing fluid into the wellbore, the pump having a pump shaft, and an electric motor with a motor shaft mechanically attached to the pump to drive the pump. The system further includes a torsional coupling connecting the motor shaft to the pump shaft. The torsional coupling includes a motor component fixedly attached to the motor shaft and having motor coupling claws extending outwardly away from the motor shaft, and a pump component fixedly attached to the pump shaft of the pump and having pump coupling claws extending outwardly away from the pump shaft. The motor coupling claws engage with the pump coupling claws so that when the motor shaft and motor component rotate, such rotation causes the pump component and the pump shaft to rotate, thereby driving the pump.

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.

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.

The embodiments herein relate generally to subterranean formation operations and, more particularly, systems and methods for achieving target downhole pressures having target downhole wave shapes for enhancement of subterranean formation stimulation and production. In particular, a treatment fluid is introduced into a subterranean formation and a downhole pressure wave in the subterranean formation having a downhole wave shape is determined, and a surface pressure wave having a surface wave shape is determined. The downhole wave shape and the surface wave shape are compared, followed by adjustment of the surface pressure to achieve a target downhole pressure wave in the subterranean formation having a target downhole wave shape. The target downhole pressure and target downhole wave shape may be selected to maximize production of the subterranean formation.

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/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.

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.

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.