A system for recovering natural gas liquid from a gas source, comprising compression means (206) for increasing the temperature and pressure of the fluid from the gas source, cooling means (230) for cooling the fluid from the compression means, a gas/gas heat exchanger (204), fluid from the gas source flowing from a first inlet to a first outlet; at least one separator (208) for receiving the fluid from the first outlet of the gas/gas heat exchanger (204) and separating liquid from the gas, the gas from the separator being directed to expansion means (206) for reducing the temperature and pressure of the gas, the aqueous part of the liquid from the separator and/or the gas from the expansion means being directed to the gas/gas heat exchanger (204) where it flows therethrough from a second inlet to a second outlet for cooling the fluid flowing between the first inlet and first outlet, wherein injection means are provided between the cooling means and the gas/gas heat exchanger for saturating the gas with a liquid agent, wherein the liquid agent comprises an evaporant and an antifreeze agent; and a recovery vessel (240) is provided downstream of the second outlet, the antifreeze agent being recovered therein for injection into the fluid from the gas source upstream of the first inlet.
A system for recovering natural gas liquid from a gas source, comprising compression means (206) for increasing the temperature and pressure of the fluid from the gas source, cooling means (230) for cooling the fluid from the compression means, a gas/gas heat exchanger (204), fluid from the gas source flowing from a first inlet to a first outlet; at least one separator (208) for receiving the fluid from the first outlet of the gas/gas heat exchanger (204) and separating liquid from the gas, the gas from the separator being directed to expansion means (206) for reducing the temperature and pressure of the gas, the aqueous part of the liquid from the separator and/or the gas from the expansion means being directed to the gas/gas heat exchanger (204) where it flows therethrough from a second inlet to a second outlet for cooling the fluid flowing between the first inlet and first outlet, wherein injection means are provided between the cooling means and the gas/gas heat exchanger for saturating the gas with a liquid agent, wherein the liquid agent comprises an evaporant and an antifreeze agent; and a recovery vessel (240) is provided downstream of the second outlet, the antifreeze agent being recovered therein for injection into the fluid from the gas source upstream of the first inlet.
A system for transferring energy by converting gas from an offshore facility to electrical power using a fuel gas power generator located on a stationary modified tanker, storing the electrical power as charged electrolyte in storage tanks therein, transferring the electrolyte to storage tanks within a shuttle modified tanker, which can then transfer the electrolyte to an onshore facility for use thereof.
A system (102; 302) for recovering natural gas liquid from a low pressure gas source (110; 310), comprising a gas/gas heat exchanger (104; 304), fluid from the gas source flowing therethrough; at least one separator (108; 308) for receiving the fluid from the gas/gas heat exchanger (104; 304) and separating liquid from the gas, the gas being directed via a connecting pipe (116; 316) to the gas/gas heat exchanger (104; 304) where it cools the fluid from the gas source; characterised in that the connecting pipe (116; 316) includes expansion means (106; 322) for cooling the gas therein and liquid injection means (120; 320) for saturating the gas with liquid.
F25J 3/06 - Processes or apparatus for separating the constituents of gaseous mixtures involving the use of liquefaction or solidification by partial condensation
A low pressure separation system comprising a separator for receiving fluid from a well, and a surge vessel for receiving liquid from the separator, characterised in that when the liquid reaches a predetermined high level in the surge vessel, a valve on the equalisation pipe connecting the surge vessel to the separator is closed and high pressure gas is directed into the surge vessel by opening a valve or a gas pipe, forcing: the liquid out of the surge vessel to a production header via a liquid outlet, a when the liquid drops to a predetermined low level in the surge vessel, the valve on the gas pipe is closed, and the valve on the equalisation pipe is opened to equalise the pressure between the surge vessel and the separator.
A multiphase sand separation system comprising an expanded pipe for flow stabilisation, with an inlet for receiving multiphase material, a first outlet for gas and a second outlet for liquid and/or solids; and a cyclonic desander including an inlet for receiving material from the second outlet of the expanded pipe, a first outlet for liquid and a second outlet for solids; characterised in that a pressure controller valve is provided to maintain a pressure difference between the first outlet of the expanded pipe and the first outlet of the cyclonic desander, thereby ensuring that the differential pressure across the cyclonic desander is maintained at a fixed preset pressure drop, irrespective of the flow regime, flow and pressure surges and the flow rates, ensuring that it continuously and consistently operates at its highest sand removal efficiency value.
A separator system (5) comprising; a separation chamber (10) arranged to separate liquid from an inflow production fluid (45); at least one gas scrubber (15) for removing entrained liquid from a separated gas inflow from said separation chamber (10); wherein said at least one gas scrubber (15) is positioned above and proximate to said separation chamber (10), said gas scrubber (15) and separation chamber (10) connectable through a vertically oriented at least one liquid outflow conduit (20) arranged to direct the removed entrained liquid from the gas scrubber (15) to the separation chamber (10) wherein the conduit (20), is arranged such that an outflow end (22) of said conduit (20) extends into the separation chamber 10(10) such that it is lower than a minimum threshold liquid depth (65) in said separation chamber 10(10).
B01D 53/14 - Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols by absorption
B01D 45/02 - Separating dispersed particles from gases or vapours by gravity, inertia, or centrifugal forces by utilising gravity
B01D 45/08 - Separating dispersed particles from gases or vapours by gravity, inertia, or centrifugal forces by utilising inertia by impingement against baffle separators
A method for the production of stabilized crude oil, the method comprising the steps of: providing a stream of crude oil; injecting steam into said stream and so stripping C3- from said stream; providing a gas stream; extracting C4+ from the gas stream, and so; producing a stream from the extracted C4+; co-mingling the stripped stream with the C4+ stream, and so; producing a stream of stabilized crude oil.
C10G 53/00 - Treatment of hydrocarbon oils, in the absence of hydrogen, by two or more refining processes
F25J 3/02 - Processes or apparatus for separating the constituents of gaseous mixtures involving the use of liquefaction or solidification by rectification, i.e. by continuous interchange of heat and material between a vapour stream and a liquid stream
A separator vessel (5) comprising; a separation chamber (10) arranged to separate liquid from an inflow production fluid (45); at least one gas scrubber (15) for removing entrained liquid from a separated gas inflow from said separation chamber (10); wherein said at least one gas scrubber (15) is positioned above and proximate to said separation chamber (10), said gas scrubber (15) and separation chamber (10) connectable through a vertically oriented at least one liquid outflow conduit (20) arranged to direct the removed entrained liquid from the gas scrubber (15) to the separation chamber (10) wherein the conduit (20) is arranged such that an outflow end (22) of said conduit (20) extends into the separation chamber (10) such that it is lower than a minimum threshold liquid depth (65) in said separation chamber (10).
B01D 53/00 - Separation of gases or vapours; Recovering vapours of volatile solvents from gases; Chemical or biological purification of waste gases, e.g. engine exhaust gases, smoke, fumes, flue gases or aerosols
10.
SLUG SUPPRESSOR APPARATUS AND CRUDE OIL STABILIZATION ASSEMBLY AND PROCESS THEREFOR
A Slug Suppressor apparatus comprising an Inlet Separator (40) capable of gas-liquid separation of Full Well Stream (FWS) fluid and Expanded Inclined Liquid Pipe (42) for dampening slugs. The Inlet Separator (40) has an inlet for receiving the FWS fluid, a separated gas outlet in its upper section, and a separated liquid outlet in its lower section. The separated gas outlet and the separated liquid outlet are operationally connected to a Gas Bypass Line (41) and the Expanded Inclined Liquid Pipe (42) respectively. The Expanded Inclined Liquid Pipe (42) has means for dampening liquid slugs and is connectable to a 3 -Phase Separator (44). The Expanded Inclined Liquid Pipe (42) has a first Liquid Reservoir Pipe (42a) section of low inclination, a second substantially vertical Head Pipe (42b) section to provide sufficient liquid head to overcome pressure drop of the downstream system, and a third Restrictor Pipe (42c) section of low inclination with an internal segmented orifice (43) dimensioned to restrict maximum liquid flow at maximum upstream static head to no more than the maximum liquid handling capacity of the downstream system. A crude oil stabilization assembly is also provided separately and comprises a stabilizer column (60), a separator (61) for vapor-liquid disengagement provided upstream of the stabilizer column (60), an expanded down-comer pipe (62) at the base of the stabilizer column (60), a crude exchanger (63) in operational connection with the down-comer pipe (62), and a Surge/Reboiler Vessel (64) in operational connection with the crude exchanger (63) via a riser pipe (65).
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