WO2008035090A1 - Procédé d'inhibition de la formation d'hydrates - Google Patents

Procédé d'inhibition de la formation d'hydrates Download PDF

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Publication number
WO2008035090A1
WO2008035090A1 PCT/GB2007/003589 GB2007003589W WO2008035090A1 WO 2008035090 A1 WO2008035090 A1 WO 2008035090A1 GB 2007003589 W GB2007003589 W GB 2007003589W WO 2008035090 A1 WO2008035090 A1 WO 2008035090A1
Authority
WO
WIPO (PCT)
Prior art keywords
gas
pipeline
trunkline
downstream
hydrocarbon
Prior art date
Application number
PCT/GB2007/003589
Other languages
English (en)
Inventor
Keijo Kinnari
Catherine Labes-Carrier
Gunnar Flaten
Knud Lunde
Jan Hundseid
Original Assignee
Statoilhydro Asa
Cockbain, Julian
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Statoilhydro Asa, Cockbain, Julian filed Critical Statoilhydro Asa
Publication of WO2008035090A1 publication Critical patent/WO2008035090A1/fr

Links

Classifications

    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C7/00—Methods or apparatus for discharging liquefied, solidified, or compressed gases from pressure vessels, not covered by another subclass
    • F17C7/02—Discharging liquefied gases
    • C—CHEMISTRY; METALLURGY
    • C07—ORGANIC CHEMISTRY
    • C07C—ACYCLIC OR CARBOCYCLIC COMPOUNDS
    • C07C7/00—Purification; Separation; Use of additives
    • C07C7/20—Use of additives, e.g. for stabilisation
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10L—FUELS NOT OTHERWISE PROVIDED FOR; NATURAL GAS; SYNTHETIC NATURAL GAS OBTAINED BY PROCESSES NOT COVERED BY SUBCLASSES C10G, C10K; LIQUEFIED PETROLEUM GAS; ADDING MATERIALS TO FUELS OR FIRES TO REDUCE SMOKE OR UNDESIRABLE DEPOSITS OR TO FACILITATE SOOT REMOVAL; FIRELIGHTERS
    • C10L3/00—Gaseous fuels; Natural gas; Synthetic natural gas obtained by processes not covered by subclass C10G, C10K; Liquefied petroleum gas
    • C10L3/06—Natural gas; Synthetic natural gas obtained by processes not covered by C10G, C10K3/02 or C10K3/04
    • E—FIXED CONSTRUCTIONS
    • E21—EARTH OR ROCK DRILLING; MINING
    • E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
    • E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
    • E21B43/34—Arrangements for separating materials produced by the well
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2221/00—Handled fluid, in particular type of fluid
    • F17C2221/03—Mixtures
    • F17C2221/032—Hydrocarbons
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2221/00—Handled fluid, in particular type of fluid
    • F17C2221/03—Mixtures
    • F17C2221/032—Hydrocarbons
    • F17C2221/036—Hydrates
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2227/00—Transfer of fluids, i.e. method or means for transferring the fluid; Heat exchange with the fluid
    • F17C2227/03—Heat exchange with the fluid
    • F17C2227/0337—Heat exchange with the fluid by cooling
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2227/00—Transfer of fluids, i.e. method or means for transferring the fluid; Heat exchange with the fluid
    • F17C2227/03—Heat exchange with the fluid
    • F17C2227/0337—Heat exchange with the fluid by cooling
    • F17C2227/0358—Heat exchange with the fluid by cooling by expansion
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2227/00—Transfer of fluids, i.e. method or means for transferring the fluid; Heat exchange with the fluid
    • F17C2227/03—Heat exchange with the fluid
    • F17C2227/0367—Localisation of heat exchange
    • F17C2227/0397—Localisation of heat exchange characterised by fins
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2260/00—Purposes of gas storage and gas handling
    • F17C2260/03—Dealing with losses
    • F17C2260/031—Dealing with losses due to heat transfer
    • F17C2260/032—Avoiding freezing or defrosting
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2260/00—Purposes of gas storage and gas handling
    • F17C2260/05—Improving chemical properties
    • F17C2260/053—Reducing corrosion
    • F—MECHANICAL ENGINEERING; LIGHTING; HEATING; WEAPONS; BLASTING
    • F17—STORING OR DISTRIBUTING GASES OR LIQUIDS
    • F17C—VESSELS FOR CONTAINING OR STORING COMPRESSED, LIQUEFIED OR SOLIDIFIED GASES; FIXED-CAPACITY GAS-HOLDERS; FILLING VESSELS WITH, OR DISCHARGING FROM VESSELS, COMPRESSED, LIQUEFIED, OR SOLIDIFIED GASES
    • F17C2270/00—Applications
    • F17C2270/01—Applications for fluid transport or storage
    • F17C2270/0102—Applications for fluid transport or storage on or in the water
    • F17C2270/0118—Offshore

Definitions

  • This invention relates to improvements in and relating to gaseous hydrocarbon transport through pipelines, and in particular to a method of inhibiting hydrate formation in such pipelines, especially at the upper inner surface.
  • Gaseous hydrocarbon e.g. natural gas
  • an offshore well head to an onshore receiving facility (for example a gas liquefaction plant) .
  • Such gaseous hydrocarbons generally have some moisture content and the pressure and temperature conditions within the pipeline can reach the zone in which formation of solid gas hydrates can occur. If build up of solid gas hydrates is severe, the hydrocarbon flow rate may drop or the pipeline may even become blocked. Since removal of gas hydrate is not a straightforward matter, it is normal to inject continuously into the hydrocarbon flow a chemical inhibitor of gas hydrate formation, e.g. methanol or monoethylene glycol.
  • a chemical inhibitor of gas hydrate formation e.g. methanol or monoethylene glycol.
  • the resulting risk of gas hydrate formation can however be reduced if the flowing hydrocarbon gas, downstream of chemical inhibitor injection, is exposed to cooling sufficient to cause the water vapour in the gas to condense before the gas enters the trunkline.
  • the invention provides a method of treatment of hydrocarbon fluid, particularly gas, flowing through a pipeline comprising an in-field flowline and downstream thereof a larger internal cross- sectional area trunkline, said method comprising introducing a gas hydrate formation inhibitor into hydrocarbon gas at a site in said pipeline and downstream thereof cooling the gas in said pipeline to a temperature close to or below the water dew point thereof whereby to condense water from the gas such that the water dew point of the gas entering said trunkline is close to or lower than the ambient temperature.
  • the inhibitor is conveniently introduced in substantially dry form and at or downstream of the well-head such that it flows along the pipeline in the same direction as the hydrocarbon, i.e. it is introduced in the manner conventional for inhibitors. No substantial countercurrent inhibitor flow will thus occur.
  • the temperature difference is no more than 15°C, more especially no more than 10 0 C, particularly no more than 5°C.
  • Particularly preferably cooling is to below the water dew point and condensation is such that the water dew point of the gas entering the trunkline is below the ambient temperature.
  • the invention provides a hydrocarbon gas pipeline comprising an in-field flowline and downstream thereof a larger internal cross-sectional area trunkline, said pipeline having a port for the introduction of a gas hydrate formation inhibitor and having downstream of said port and upstream of said trunkline a gas cooler.
  • the cooling of the gas to close to or below the dew point may be effected by heat transfer to the surroundings of the pipeline and/or to a coolant fluid and/or by expansion of the gas.
  • the cooler in the pipeline will generally comprise a section of pipeline in which the internal surface area to volume ratio is increased relative to upstream and downstream sections, e.g. by the provision of internal cooling fins or by the use of one or more smaller internal diameter sections of pipeline in parallel and/or in series.
  • the cooler in the pipeline takes the form of a section of pipeline of greater internal cross sectional area than the upstream section of the pipeline, optionally preceded by a section of pipeline of smaller internal cross-sectional area than the section upstream thereof, i.e.
  • the pipeline may be provided with a "choke" followed by an expansion zone.
  • the cooler is at or upstream of the trunkline, i.e. the section of the pipeline leading to the receiving facility (e.g. an onshore location or a remote storage or delivery site) . It may thus for example be at or upstream of a PLEM or it may take the form of a choke valve at the beginning of the trunkline.
  • the inlet temperature for the hydrocarbon entering the trunkline is T 1
  • the ambient temperature at position x along the trunkline is T x a
  • the temperature of the hydrocarbon in the trunkline at position x is T x t
  • the dew point for the hydrocarbon in the trunkline at position x is T x d
  • T x a ⁇ T x t for most of the trunkline.
  • some expansion of the gas phase in the trunkline may occur and accordingly there may thus be a temperature difference (drop) between T 1 and T x t such that T x c ⁇ T x d .
  • the gas hydrate formation inhibitor should thus desirably be present in the liquid phase entering the trunkline at sufficient concentration that its gas phase concentration at T x t is sufficient to prevent hydrate formation in any water condensing in the trunkline.
  • the required inhibitor concentration may be calculated using conventional means and if required further inhibitor may be added, e.g. to the liquid phase, following the cooling to close to or below the dew point and the resultant water condensation, e.g. at or adjacent a PLEM or at a point along the trunkline.
  • coolers may typically be up to tens of kilometers from the well-head. If desired coolers may be located in early-stage flowlines, i.e. flowlines from which the flow is subsequently combined to flow through a greater cross-sectional area flowline which leads in turn to the still greater-cross-sectional area trunkline.
  • the PLEM at a distance from the well-heads, generally at least 20 km, particularly at least 35 km, such that heat transfer to the environment from the in-field flowlines ensures that sufficient water has condensed out from the gas that the dew point of the gas in the trunkline starts close to or below and remains close to or below the ambient- temperature at the trunkline.
  • the gas hydrate formation inhibitor should thus desirably be present in the liquid phase entering the trunkline at sufficient concentration that its gas phase concentration is sufficient to prevent hydrate formation in any water condensing in the trunkline.
  • the required inhibitor concentration may be calculated using conventional means and if required further inhibitor may be added.
  • the use of such long in-field flowlines is generally undesirable since gas flow needs a lower pressure differential for larger cross-sectional tubes.
  • a water separator may be placed downstream of the point at which cooling to close to or below the dew point and hence condensation occurs .
  • a separator would be installed at or adjacent a PLEM.
  • Water from the separator may be treated, e.g. following transportation to a surface facility, to retrieve the gas hydrate formation inhibitor which can then be reused. With the use of a water separator, liquid build-up and pressure drop in the trunkline downstream of the separator may be reduced.
  • the separator may take any convenient form, e.g. a water trap provided with a valved outlet through which the water may be expelled into a water transport line itself optionally provided with a pump.
  • the in-field flowlines will have internal diameters of less than 30", e.g. 16" to 28", while the trunkline will generally have an internal diameter of 30" or greater, e.g. up to 50", more preferably up to 44". These diameter values are typical but should not be considered essential for the performance of the invention.
  • ambient temperature for any position along the trunkline is meant the temperature of the surroundings of the trunkline at that position.
  • ambient temperature is generally >-2°C, more typically >4°C.
  • the hydrate inhibitor is preferably introduced at, before or shortly after the well head, e.g. within up to 5Om of the well head, more preferably up to 10m. As mentioned above, further inhibitor may be introduced at or adjacent a PLEM or within a trunkline.
  • the inhibitor may be any of the chemicals conventionally used as gas hydrate formation inhibitors, e.g. methanol or monoethylene glycol, and may be used in conventional quantities .
  • the method and apparatus of the invention are particularly suitable for underwater hydrocarbon wells, e.g. offshore wells, especially where the ambient temperature of the surrounding water reaches temperatures as low as about -2°C to +5°C.
  • the method and apparatus are also suited for onshore operation, in particular where trunklines are exposed to cold weather conditions, e.g. arctic and subarctic tundra such as >50°N in North America and >60°N in Northern Europe or Asia, or at high altitudes.
  • arctic and subarctic tundra such as >50°N in North America and >60°N in Northern Europe or Asia, or at high altitudes.
  • the pipeline treatment according to the invention has the added advantage that trunkline corrosion will be reduced as the same water condensation mechanism controls corrosion.
  • the use of the inhibitor can be omitted.
  • the invention provides a method of treatment of hydrocarbon fluid flowing through a pipeline comprising an in-field flowline and downstream thereof a larger internal cross- sectional area trunkline, said method comprising cooling the gas in said pipeline to a temperature close to or below the dew point thereof whereby to condense water from the gas such that the dew point of the gas entering said trunkline is close to or lower than the ambient temperature .
  • FIG. 1 there is shown a pipeline 1 leading from sub-sea well heads 2 to an onshore receiving facility 3.
  • the pipeline comprises in-field flowlines 4 leading from the well heads 2 to a PLEM 5 and a spool 6 leading from the PLEM to the trunkline 7.
  • Gas hydrate inhibitor is injected into the pipeline at injection ports 8 at the well heads.
  • Coolers 9 are located in the flowlines 4 and take the form of a choke 10 followed by an expansion zone 11. Liquid condensed in the coolers flows along the pipeline.

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  • Chemical & Material Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Organic Chemistry (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • Mining & Mineral Resources (AREA)
  • Geology (AREA)
  • Mechanical Engineering (AREA)
  • General Engineering & Computer Science (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • General Chemical & Material Sciences (AREA)
  • Analytical Chemistry (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • Physics & Mathematics (AREA)
  • Water Supply & Treatment (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Pipeline Systems (AREA)

Abstract

L'invention concerne un procédé de traitement de fluide d'hydrocarbure circulant dans un pipeline comprenant une conduite d'écoulement sur site en aval de laquelle se trouve une conduite principale de coupe transversale interne plus grande. Ledit procédé comprend l'introduction d'un inhibiteur de la formation d'hydrate de gaz dans le gaz d'hydrocarbures à un emplacement donné dudit pipeline et, en aval de cet emplacement, le refroidissement du gaz dans ledit pipeline à une température proche du point de rosée de l'eau ou inférieure audit point de rosée afin de condenser l'eau du gaz. Ainsi, le point de rosée de l'eau du gaz pénétrant dans la conduite principale est proche de la température ambiante ou inférieur à cette dernière.
PCT/GB2007/003589 2006-09-21 2007-09-21 Procédé d'inhibition de la formation d'hydrates WO2008035090A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
GB0618656.3 2006-09-21
GB0618656A GB2447027A (en) 2006-09-21 2006-09-21 Prevention of solid gas hydrate build-up

Publications (1)

Publication Number Publication Date
WO2008035090A1 true WO2008035090A1 (fr) 2008-03-27

Family

ID=37421417

Family Applications (1)

Application Number Title Priority Date Filing Date
PCT/GB2007/003589 WO2008035090A1 (fr) 2006-09-21 2007-09-21 Procédé d'inhibition de la formation d'hydrates

Country Status (2)

Country Link
GB (1) GB2447027A (fr)
WO (1) WO2008035090A1 (fr)

Cited By (3)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2013004275A1 (fr) * 2011-07-01 2013-01-10 Statoil Petroleum As Procédé et système pour abaisser le point de rosée d'eau d'un flux de fluide d'hydrocarbure sous-marin
US10184090B2 (en) 2012-11-26 2019-01-22 Statoil Petroleum As Combined dehydration of gas and inhibition of liquid from a well stream
US10563496B2 (en) 2014-05-29 2020-02-18 Equinor Energy As Compact hydrocarbon wellstream processing

Citations (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3159473A (en) * 1960-08-19 1964-12-01 Shell Oil Co Low-temperature dehydration of well fluids
US3495380A (en) * 1967-02-24 1970-02-17 Shell Oil Co Prevention of gas hydrate formation in gas transport pipelines
FR2618876A1 (fr) * 1987-07-30 1989-02-03 Inst Francais Du Petrole Procede de traitement et de transport d'un gaz contenant du methane et de l'eau
US5127231A (en) * 1990-01-23 1992-07-07 Institut Francais Du Petrole Process and apparatus for transporting and treating a natural gas
US5351756A (en) * 1992-05-20 1994-10-04 Institut Francais Du Petrole Process for the treatment and transportation of a natural gas from a gas well
WO1996034177A1 (fr) * 1995-04-25 1996-10-31 Shell Internationale Research Maatschappij B.V. Procede destine a empecher le bouchage de conduits par des hydrates de gaz
GB2301839A (en) * 1995-06-06 1996-12-18 Inst Francais Du Petrole Method of transporting a fluid susceptible for the formation of hydrates
GB2326423A (en) * 1997-06-17 1998-12-23 Inst Francais Du Petrole Process for degasolining a gas containing condensable hydrocarbons

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US3837399A (en) * 1973-05-04 1974-09-24 Texaco Inc Combined multiple solvent miscible flooding water injection technique for use in petroleum formations
US4132535A (en) * 1976-11-17 1979-01-02 Western Chemical Company Process for injecting liquid in moving natural gas streams
US4407367A (en) * 1978-12-28 1983-10-04 Hri, Inc. Method for in situ recovery of heavy crude oils and tars by hydrocarbon vapor injection
US5109928A (en) * 1990-08-17 1992-05-05 Mccants Malcolm T Method for production of hydrocarbon diluent from heavy crude oil
US6197095B1 (en) * 1999-02-16 2001-03-06 John C. Ditria Subsea multiphase fluid separating system and method
NO311103B1 (no) * 2000-02-08 2001-10-08 Jon Grepstad Fremgangsmåte for å lette separasjonen av en råoljeströms oljefase og vannfase
GB2377711A (en) * 2001-07-20 2003-01-22 Ingen Process Ltd Thinning of crude oil in a bore well

Patent Citations (8)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
US3159473A (en) * 1960-08-19 1964-12-01 Shell Oil Co Low-temperature dehydration of well fluids
US3495380A (en) * 1967-02-24 1970-02-17 Shell Oil Co Prevention of gas hydrate formation in gas transport pipelines
FR2618876A1 (fr) * 1987-07-30 1989-02-03 Inst Francais Du Petrole Procede de traitement et de transport d'un gaz contenant du methane et de l'eau
US5127231A (en) * 1990-01-23 1992-07-07 Institut Francais Du Petrole Process and apparatus for transporting and treating a natural gas
US5351756A (en) * 1992-05-20 1994-10-04 Institut Francais Du Petrole Process for the treatment and transportation of a natural gas from a gas well
WO1996034177A1 (fr) * 1995-04-25 1996-10-31 Shell Internationale Research Maatschappij B.V. Procede destine a empecher le bouchage de conduits par des hydrates de gaz
GB2301839A (en) * 1995-06-06 1996-12-18 Inst Francais Du Petrole Method of transporting a fluid susceptible for the formation of hydrates
GB2326423A (en) * 1997-06-17 1998-12-23 Inst Francais Du Petrole Process for degasolining a gas containing condensable hydrocarbons

Cited By (11)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
WO2013004275A1 (fr) * 2011-07-01 2013-01-10 Statoil Petroleum As Procédé et système pour abaisser le point de rosée d'eau d'un flux de fluide d'hydrocarbure sous-marin
GB2507429A (en) * 2011-07-01 2014-04-30 Statoil Petroleum As A method and system for lowering the water dew point of a hydrocarbon fluid stream subsea
US20140157658A1 (en) * 2011-07-01 2014-06-12 Statoil Petroleum As Method and system for lowering the water dew point of a hydrocarbon fluid stream subsea
AU2011372732B2 (en) * 2011-07-01 2016-08-04 Statoil Petroleum As A method and system for lowering the water dew point of a hydrocarbon fluid stream subsea
US9950293B2 (en) 2011-07-01 2018-04-24 Statoil Petroleum As Method and system for lowering the water dew point of a hydrocarbon fluid stream subsea
GB2507429B (en) * 2011-07-01 2020-09-09 Equinor Energy As A method and system for lowering the water dew point of a hydrocarbon fluid stream subsea
US10786780B2 (en) 2011-07-01 2020-09-29 Equinor Energy As Method and system for lowering the water dew point of a hydrocarbon fluid stream subsea
US10184090B2 (en) 2012-11-26 2019-01-22 Statoil Petroleum As Combined dehydration of gas and inhibition of liquid from a well stream
US10576415B2 (en) 2012-11-26 2020-03-03 Equinor Energy As Combined dehydration of gas and inhibition of liquid from a well stream
US10821398B2 (en) 2012-11-26 2020-11-03 Equinor Energy As Combined dehydration of gas and inhibition of liquid from a well stream
US10563496B2 (en) 2014-05-29 2020-02-18 Equinor Energy As Compact hydrocarbon wellstream processing

Also Published As

Publication number Publication date
GB0618656D0 (en) 2006-11-01
GB2447027A (en) 2008-09-03

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