Systems and methods for increasing hydrocarbon production using an electrical submersible pump are described. The methods typically include, for example, configuring an electrical submersible pump comprising a gas separator to induce a gas lift effect in a well comprising a tubing within a casing. Hydrocarbon production from the well is therefore increased using the electrical submersible pump.

The object of this invention is to create the elements necessary to supply lifting energy in flowlines or recipients containing motionless fluids. The invention provides a motive force through hollow shafts or hollow stators inside a streamlined housing having a rotor comprised of two concentric and coplanar arrays of external and internal blades working together as pump and turbine on the same plane. To operate, the artifact requires a source of fluid supply acting as motive fluid to boost a static or relative slow-motion fluid. The motive fluid travels from an internal hollow shaft toward an external hollow shaft, or from a scroll case throughout hollow stators to an internal array of blades to induce movement on the rotor. The present invention is designed to be used in different locations for different applications in different positions, to support the transportation of fluids. It operates with any fluid supply such as gas or liquid or a mix of both. The artifact does not require direct sources of electrical power.

There is provided an apparatus 30 and method for conditioning the flow of a mixed phase flow from a supply pipe 101 from a hydrocarbon well. The apparatus 30 comprises an elongate reservoir 11 having a first end for receiving a multi-phase fluid flow from the supply pipe and a second closed end, there being provided a gas outlet 02 from the upper part of the first end, a liquid separation region downstream of the first end, and a liquid outlet 12 from the lower part of the liquid separation region; and a gas-liquid mixer to which the gas and liquid outlets are connected such that the separated gas and liquid may be recombined. The reservoir 11 may accommodate surges of liquid such that the flow rate from the liquid outlet is relatively invariant over time compared to that of the flow received by the apparatus.

There is provided an apparatus 30 and method for conditioning the flow of a mixed phase flow from a supply pipe 101 from a hydrocarbon well. The apparatus 30 comprises an elongate reservoir 11 having a first end for receiving a multi-phase fluid flow from the supply pipe and a second closed end, there being provided a gas outlet 02 from the upper part of the first end, a liquid separation region downstream of the first end, and a liquid outlet 12 from the lower part of the liquid separation region; and a gas-liquid mixer to which the gas and liquid outlets are connected such that the separated gas and liquid may be recombined. The reservoir 11 may accommodate surges of liquid such that the flow rate from the liquid outlet is relatively invariant over time compared to that of the flow received by the apparatus.

A gas compressor comprising a rotating drum and a return assembly. The drum includes a compression channel assembly with compression channels between a common zone and a distal area. The compression channels may be formed by a plurality of V-shaped blocks. The return assembly draws liquid from an annular lake formed in the drum to a fluid outlet. A gas inlet in the return assembly mixes incoming gas with the liquid. An optional eductor connected to the gas inlet draws gas into the gas inlet. Fluid entering the common pressure zone is forced into the compression channels that compress the gas. Pressurized gas is separated from liquid in the fluid prior to leaving the compression channel. An inducer may be positioned between the fluid outlet of the return assembly and the opening of the centralized common pressure zone.

A gas compressor comprising a rotating drum and a return assembly. The drum includes a compression channel assembly with compression channels between a common zone and a distal area. The compression channels may be formed by a plurality of V-shaped blocks. The return assembly draws liquid from an annular lake formed in the drum to a fluid outlet. A gas inlet in the return assembly mixes incoming gas with the liquid. An optional eductor connected to the gas inlet draws gas into the gas inlet. Fluid entering the common pressure zone is forced into the compression channels that compress the gas. Pressurized gas is separated from liquid in the fluid prior to leaving the compression channel. An inducer may be positioned between the fluid outlet of the return assembly and the opening of the centralized common pressure zone.

A system for dewatering a subsea gas pipeline includes a pig launcher at the pipeline's upper end, which may be at or near the sea surface, and a pig receiver at the pipeline's lower end, which may be at or near the sea floor. A multiphase pump unit is deployed at the pipeline lower end and is configured to provide sea water suction to aid in a pig train being forced downwards through pipeline. The multiphase pump is configured to handle some amount of gas leaking around the pig train. A choke system may allow sea water to enter the flowline, thereby lowering the gas volume fraction (GVF) and preventing the GVF from exceeding the ability of the multiphase pump. For deeper water applications, a second pump may be provided in series that may be a single pump if positioned downstream of the multiphase pump.

A system for dewatering a subsea gas pipeline includes a pig launcher at the pipeline's upper end, which may be at or near the sea surface, and a pig receiver at the pipeline's lower end, which may be at or near the sea floor. A multiphase pump unit is deployed at the pipeline lower end and is configured to provide sea water suction to aid in a pig train being forced downwards through pipeline. The multiphase pump is configured to handle some amount of gas leaking around the pig train. A choke system may allow sea water to enter the flowline, thereby lowering the gas volume fraction (GVF) and preventing the GVF from exceeding the ability of the multiphase pump. For deeper water applications, a second pump may be provided in series that may be a single pump if positioned downstream of the multiphase pump.

A top side-less pump system for managing multiphase fluid includes a pump subsystem having a suction and a discharge. A first gas liquid extraction unit has a multiphase fluid inlet and a liquid outlet. The liquid outlet is coupled to the suction for providing a liquid rich fluid to the bearing lubrications. An ejector is coupled to a gas outlet of the main gas liquid extraction unit to receive a gas rich fluid. A second gas liquid extraction unit is coupled to an outlet of the ejector. A water based lubrication liquid unit is coupled to the inlets of the pump and, after being energized at higher pressure, injected into the bearings through built in lubrication and cooling passages.

A top side-less pump system for managing multiphase fluid includes a pump subsystem having a suction and a discharge. A first gas liquid extraction unit has a multiphase fluid inlet and a liquid outlet. The liquid outlet is coupled to the suction for providing a liquid rich fluid to the bearing lubrications. An ejector is coupled to a gas outlet of the main gas liquid extraction unit to receive a gas rich fluid. A second gas liquid extraction unit is coupled to an outlet of the ejector. A water based lubrication liquid unit is coupled to the inlets of the pump and, after being energized at higher pressure, injected into the bearings through built in lubrication and cooling passages.