The invention discloses a kind of thickening carbon dioxide displacement visual analog device, including pressure boost module, visual stirring vessel module and displacement analog module; the mentioned pressure boost module, visual stirring vessel module and displacement analog module are connected successively; the invention is used to develop the experimental study including evaluation of gas injection miscible-phase/non-miscible-phase displacement efficiency, percolation characteristics during gas displacement, mobility control technology during gas drive, and optimization of gas injection way.

In accordance with presently disclosed embodiments, systems and methods for efficiently handling dry additives to be mixed with bulk material in a blender are provided. The systems may include a support structure used to direct bulk material from one or more portable containers on the support structure to a first outlet location, and a combined metering/transferring system for directing dry additives from another portable container to a second outlet location. Specifically, the metering/transferring system may output a metered flow of dry additives to the blender mixer to be combined with bulk material that is released from the portable containers. The metering/transferring system may utilize a gravity feed outlet coupled to a metered screw or other conveying device to move the dry additive from the portable container to the second outlet location.

A method of conducting fracturing operations at multiple wellsites in a field. The method may include manufacturing a first fracturing fluid concentrate at a fluid manufacturing plant located at a sand mine of the field using sand produced from the sand mine. The method may also include pumping the first fracturing fluid concentrate from the fluid manufacturing plant to a first well and a second well of the multiple wellsites. The method may further include injecting the first fracturing fluid concentrate into a first well at the first wellsite.

In accordance with presently disclosed embodiments, systems and methods for efficiently handling dry additives to be mixed with bulk material in a blender are provided. The systems may include a support structure used to direct bulk material from one or more portable containers on the support structure to a first outlet location, and a combined metering/transferring system for directing dry additives from another portable container to a second outlet location. Specifically, the metering/transferring system may output a metered flow of dry additives to the blender mixer to be combined with bulk material that is released from the portable containers. The metering/transferring system may utilize a gravity feed outlet coupled to a metered screw or other conveying device to move the dry additive from the portable container to the second outlet location.

An integrated blender system includes a skid. The integrated blender system includes a blender assembly, including a blender tub including an outlet, a supply pipe coupled between a suction pump and the blender tub, and an outlet pipe coupled to the outlet of the blender tub. The integrated blender assembly includes a dry product additive system. The dry product additive system includes a skid, a hopper, a pickup funnel, a feeder system, a supply pump, and an eductor assembly. The feeder system may be configured to transport product from the hopper to the pickup funnel. The eductor assembly including a suction inlet, a motive inlet, and an outlet. The suction inlet may be coupled to the pickup funnel by a suction hose. The motive inlet may be coupled to the supply pump by a motive fluid hose. The outlet nozzle is positioned to eject fluid and product into the blender tub.

The present invention provides a method and system for providing on-site electrical power to a fracturing operation, and an electrically powered fracturing system. Natural gas can be used to drive a turbine generator in the production of electrical power. A scalable, electrically powered fracturing fleet is provided to pump fluids for the fracturing operation, obviating the need for a constant supply of diesel fuel to the site and reducing the site footprint and infrastructure required for the fracturing operation, when compared with conventional systems. The treatment fluid can comprise a water-based fracturing fluid or a waterless liquefied petroleum gas (LPG) fracturing fluid.

A flow management and separation system for a horizontal wellbore having a primary artificial lift device having an intake has (a) a sealed central flowpath from a fluidseeker weighted keel inlet, through a recovery flow tube, a seal bore extension and a dip tube having a pump intake sealing assembly in fluid communication with the lift device intake; and (b) a mixed fluid flow path from a fluidseeker internal bypass passage, through an annulus of at least one slug catcher comprising a perforated shell.

A method of determining a dry proppant concentration in a fracturing fluid includes combining a wet proppant with a carrier fluid in a mixer to form the fracturing fluid. The dry proppant concentration of the fracturing fluid leaving the mixer is determined using a moisture content of the wet proppant entering the mixer, wherein use of the moisture content prevents overestimation of the dry proppant concentration. The method can be preformed using a system for injecting fracturing fluid into a borehole, the fracturing fluid including a carrier fluid mixed with a wet proppant including a dry proppant dampened with a dampening liquid. The system includes a mixer operable to receive and mix the carrier fluid and the wet proppant to form the fracturing fluid, a frac pump operable to inject the fracturing fluid into the borehole, and a control system comprising a processor operable to receive a moisture content of the wet proppant before being mixed with the carrier fluid and programmed to determine a dry proppant concentration of the fracturing fluid formed in the mixer using a moisture content of the wet proppant, wherein use of the moisture content prevents overestimation of the dry proppant concentration.

A polymer dispersion system for use in a hydraulic fracturing operation is disclosed. The system comprises (a) a tank assembly comprising an ingress, an egress, and an interior volume for collecting mother solution; (b) a first transfer pump coupled with the egress of the tank assembly: and (c) a second transfer pump coupled with the egress of the tank assembly. The first transfer pump is configured for coupling to a missile unit and a blender unit downstream thereof, but in fluid communication with only one of such units at any given time when coupled. A method of operating said polymer dispersion system is also disclosed.

The present invention discloses electro-hydraulic hybrid drive sand-mixing equipment, including a skid base, an electric motor, a hydraulic pump, a discharge centrifugal pump, a suction centrifugal pump, a mixing tank, a dry additive system, a liquid additive system, and a sand auger system. The electric motor, the hydraulic pump, the discharge centrifugal pump, the suction centrifugal pump, the mixing tank, the dry additive system, the liquid additive system, and the sand auger system are integrally skid mounted on the skid base. There are two electric motors, including a first electric motor and a second electric motor. The first electric motor drives the discharge centrifugal pump, and the second electric motor actuates the hydraulic pump, to drive the suction centrifugal pump, the mixing tank, the dry additive system, the liquid additive system, and the sand auger system. The electric motor is an integrated variable-frequency drive electric motor. Beneficial effects: Two integrated variable-frequency drive electric motors are applied. First, the setup of an independent variable-frequency drive cabinet is effectively omitted, that is, the overall size of the sand-mixing equipment is effectively reduced, so that it is more flexible and convenient to transport the equipment and arrange a well site. Next, a control system is simpler, thus optimizing the power matching of the sand-mixing equipment.