The system and method for processing flowback fluid include a plurality of wellheads producing flowback fluid flows, a plurality of first stage separators corresponding to at least one wellhead of an installation with multiple wellheads and multiple flowback fluid flows, a plurality of metering devices corresponding to each first stage separator, and a second stage separator in fluid connection with the metering devices and the first stage separators. The second stage separator includes a solids separator to further control the storage volumes of the first and second stage separators and retention time in the second stage separator by removing solids.

A packer, disposed in a deviated portion of a well, seals with an inner wall of the well. A first tubular, extending through the packer, receives a wellbore fluid via first inlet. A first outlet of the first tubular discharges the wellbore fluid into an annulus within the well, uphole of the packer. A second tubular, coupled to the first tubular, receives at least a liquid portion of the wellbore fluid via a second inlet. The second tubular directs the liquid portion of the wellbore fluid to a downhole artificial lift system. A sump, defined by a region of an annulus between the inner wall of the well and the first tubular, receives at least a portion of solid material carried by the wellbore fluid.

A method of blowing out debris or sand from a separation device comprises opening a second valve assembly such that the second valve assembly is not exposed to pressurized fluid from the separation device when opening. A first valve assembly is opened, wherein the first valve assembly is downstream of the separation device and upstream of the second valve assembly. Debris or sand from the separation device is blown through the first and second valve assemblies, and through a choke port of a third valve assembly. A method of closing fluid flow through a high integrity pressure protection system comprises closing a primary valve in response to detecting the over pressurization of fluid in the fluid line, and closing at least one secondary valve in response to detecting the closing of the primary valve.

An apparatus and a method for controlling sand production from an oil well. A sand rate comparison value determined at a given oil production rate is used to control the oil production rate by controlling the choke to set the oil production rate to a set production rate corresponding to the oil production rate. The sand rate comparison value is used to confirm that the measured reduced sand flow rate, at that given oil production rate, is below the allowable sand rate (ASR). Since the oil production rate is associated with the sand rate, the sand rate comparison value is used to control the sand rate, by being used to control the oil production rate, and so the sand rate comparison value functions as, and therefore typically comprises, or is, a sand rate control parameter.

A device and method for inhibiting particle (e.g., sand) accumulation on down hole equipment, such as an ESP, particularly when the equipment is not in use. The device and methods permit the equipment to start and stop with fewer break downs and at greater efficiency. The device includes a central tubular section connecting the equipment to the production tubing string. The tubular section is surrounded by an annulus and a number of ports in the tubular section angled to allow fluid communication between the tubular section and the annulus during operation, but prevent particles from flowing from the annulus into the tubular section when not in use. A check valve between the tube and ESP assists in isolating the ESP from sand.

A temporary hydrocarbon well production system receives flow from a hydrocarbon well through a production line connected to the well. The production line flows into a sand separator, which has a fluid outlet connected to a choke manifold and a solids outlet connected to a sand dump line. A transportable and vertical closed separator receives flow through two separate lines from the choke manifold and from the sand dump line, which respectively flow into independent diffusing structures in the closed separator. Gas, vapors, volatile organic compounds, etc. are captured within the closed vessel and are discharged through a vapor discharge line attached to a vapor recovery unit for either further processing or incineration through a flare. A liquid dump line discharges liquids from the closed separator to at least one closed tank.

A transportable separation apparatus for separating spent materials from oil and gas operations into a primarily solid component, a primarily liquid component and a primarily gas component. The transportable separation apparatus includes a first separation unit disposed on the transportable separation apparatus for receiving spent materials and beginning separation of the spent materials. The transportable separation apparatus connectable to a vehicle to be pulled on commercial roadways when the transportable separation apparatus is in a transportation configuration. The transportable separation apparatus further includes a second separation unit in fluid communication with the first separation unit for further separation of the spent materials. A method of using the transportable separation apparatus to separate spent materials.

A gas compression system and a method of flow conditioning by a gas compression system are provided. A gas compression system includes a compact flow conditioner in a form of a flow conditioner tank and a combined multi-phase pump and compressor unit comprising an impeller configured to compress a mixture of gas and liquid, wherein the gas compression system is configured such that the gas and the liquid are separated in the flow conditioner tank, the separated gas and liquid are sucked up through the separate gas and liquid pipes and re-mixed again upstream of the impeller, and the liquid is distributed in a gas flow by Venturi effect, and wherein the Venturi effect is obtained by a constriction in the outlet pipe to the impeller, just upstream of the impeller.

A new method separating sand, solids, and produced particulates down-hole in a well producing hydrocarbons. The separation assembly can include ether one, two, or more segments or stages of varying lengths depending upon the individual application. The assembly is installed into the tubing string or delivery conduit of a well producing hydrocarbons. One stage can consist of a velocity chamber whereby separation of particulates occurs by increasing the downward velocity of particulates and reducing the upward velocity of hydrocarbons thereby allowing the particulates to “fall-out” into a lower chamber where the particulates are captured. Another stage can consist of a filter whereby particulates are captured in a chamber that can consist of filtering materials such as gravel, rock, sand, wood, or manmade materials. Each of the stages can be employed individually or in combination.

An automated sand separator discharge system includes a sand separator disposed downstream of a wellhead, an inlet conduit for transporting a process stream to the sand separator, a fluid outlet conduit for transporting a liquid and gas stream from the sand separator, a sand discharge conduit for removing sand from the sand separator, first, second, and third valves disposed along the sand discharge conduit, a first transducer connected between the first and second valves and operative to measure pressure in a portion of the sand discharge conduit and to produce a pressure reading, and a control panel operatively connected to the first, second, and third valves and the first transducer, the control panel being programmed to initiate and terminate discharge of sand from the sand separator, and to determine if the first and second valves are sealing completely when closed.