A system and method for improved flow measurements for LCG, such as liquid petroleum gas (LPG), is disclosed. Embodiments of the present technology detect the presence of a vapor in a fluid flowing in a mass flow meter. A control valve is then adjusted to provide enough back pressure to prevent the measured liquid from flashing and to reduce the presence of vapor in the fluid flowing in the mass flow meter. By keeping the fluid in liquid form, the present technology reduces the vapor flowing in the mass flow meter, increasing the accuracy of mass flow and other measurements. Utilizing a similar principle of vapor detection, embodiments of the present technology provide for improved average parameter value calculation, such as average density calculations and equivalent liquid volume calculations.

This invention relates to a multiphase pumping block device comprising a pump and a bypass circuit. Said bypass circuit is suitable for enabling the flow of a fluid from an area upstream of the pump to an area downstream of the pump by bypassing the pump. The latter comprises at least out non-return valve suitable for blocking the flow of the fluid from the area downstream of the pump to the area upstream of the pump. In addition, the pumping block device is connected to a set of pumping circuits, comprising a main bypass circuit suitable for enabling the flow of a fluid from an area upstream of the connected pumping block to an area downstream of the connected pumping block. Finally, the pumping block device is arranged in order to be disconnected from said set of circuits for maintenance.

A multi-phase pump system and method that directs incoming two-phase flow into a fixed cylinder that contains a vortical flow. The system includes a momentum-driven, vortex phase separator, the phase separator accepting liquid-gas flows at any ratio from all liquid to all gas. The pump system also includes a liquid prime mover; a gas prime mover; and a control system. The vortical flow is driven by injecting the two-phase or another fluid stream tangent or approximately tangent to the curved surface of the cylindrical chamber. Inertial forces generated within the vortical flow drive a buoyancy-driven separation process within the cylindrical chamber. Single-phase prime movers are then used to pump the separated phases to a higher pressure.

A system (200) for pumping a multi-phase feed mixture includes a separation section (230) having a separation tank (206), a mixing section (240), and a pumping section (250). The separation tank (206) has a feed mixture entrance (204) and a liquid outlet (215) located at different axial positions along a wall of the separation tank (206). A gas line (212) extends through the separation tank (206) from a gas inlet (217) located in an interior of the separation tank to a gas outlet (218) located outside of the separation tank (206). The mixing section (240) includes a fluid suction chamber (220) surrounding the gas outlet (218), and a liquid line (216) fluidly connects the liquid outlet (215) to the fluid suction chamber (220). The pumping section (250) includes a pump (226), and a diffuser (222) fluidly connects the fluid suction chamber (220) to a pump inlet (224).

A method for operating a fluid flow system (300) is provided. The fluid flow system (300) includes a fluid flowing through a pipeline (301), a first pressure sensor (303) located within the pipeline (301), and a vibrating meter (5). The vibrating meter (5) includes a sensor assembly (10) in fluid communication with the first pressure sensor (303). The method includes steps of measuring a pressure of the fluid within the pipeline (301) using the first pressure sensor (303) and measuring one or more flow characteristics of the fluid using the vibrating meter (5). The method further includes a step of determining a static pressure of the fluid based on the pressure of the fluid within the pipeline (301) and the one or more flow characteristics. The method further includes a step of determining if the fluid contains at least some gas based on the static pressure of the fluid.

A natural gas liquid interconnected large pipe storage facility for natural gas liquid wholesale transfer with a proprietary modular manufacturing pipe interface for vapor recovery to aid in the transfer of liquified petroleum gas on an exceptionally small footprint. The natural gas liquid modular terminal may comprise a lower pipe, an upper pipe located above and running parallel to the lower pipe where the upper pipe is in fluid communication with the lower pipe, one or more bulkheads, one or more compressors, and one or more pumps, where the lower pipe, upper pipe, bulkheads, compressors, and pumps are modular and capable of being assembled onsite according to the needs of a user. The natural gas liquid modular terminal may comprise a vapor diffuser inside of the lower pipe.

A device for separating liquid from gas in a well flow when compressing the well flow comprises a liquid separator (1) having an inlet (13) for the well flow, an outlet (5) for gas and an outlet (4) for liquid. According to the invention separated liquid from the liquid separator (1) is fine-divided in connection with the liquid outlet (4), and the fine-divided liquid is supplied into the gas outlet (5) at a mixing point (8) downstream the liquid separator (1) and upstream a compressor (11).

A method of cleaning deposited solid material from a fouled portion of a gas compressor (6) whilst the gas compressor (6) is in situ in a natural gas processing system (1) is provided. The method comprises the steps of supplying a liquid cleaning agent to a gas inlet of the gas compressor (6), the liquid cleaning agent being capable of removing the deposited solid material; passing the liquid cleaning agent through the gas compressor (6) to a gas outlet of the gas compressor (6), wherein at least a portion of the cleaning agent remains in a liquid state as it passes through the fouled portion of the gas compressor (6); and recovering a fluid containing removed material that is output from the gas compressor (6) so as to prevent the removed material reaching one or more gas processing stages of the gas processing system (1) downstream of the gas compressor (6).

A method can include detecting instability of multiphase fluid flow in a multiphase fluid production system using sensor measurements from the multiphase fluid production system; and, responsive to the detection of instability, increasing gas injection into the multiphase fluid production system until a variation metric of the sensor measurements decreases to a level indicative of stable multiphase fluid flow in the multiphase fluid production system.

A natural gas liquid interconnected large pipe storage facility for natural gas liquid wholesale transfer with a proprietary modular manufacturing pipe interface for vapor recovery to aid in the transfer of liquified petroleum gas on an exceptionally small footprint. The natural gas liquid modular terminal may comprise a lower pipe, an upper pipe located above and running parallel to the lower pipe where the upper pipe is in fluid communication with the lower pipe, one or more bulkheads, one or more compressors, and one or more pumps, where the lower pipe, upper pipe, bulkheads, compressors, and pumps are modular and capable of being assembled onsite according to the needs of a user. The natural gas liquid modular terminal may comprise a vapor diffuser inside of the lower pipe.