WO1996008456A1 - Procede empechant la formation d'hydrates - Google Patents

Procede empechant la formation d'hydrates Download PDF

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Publication number
WO1996008456A1
WO1996008456A1 PCT/US1995/011356 US9511356W WO9608456A1 WO 1996008456 A1 WO1996008456 A1 WO 1996008456A1 US 9511356 W US9511356 W US 9511356W WO 9608456 A1 WO9608456 A1 WO 9608456A1
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WO
WIPO (PCT)
Prior art keywords
additive
fluid
formation
hydrate
additives
Prior art date
Application number
PCT/US1995/011356
Other languages
English (en)
Inventor
Karla Schall Colle
Christine Ann Costello
Russell Harlan Oelfke
Dennis George Peiffer
Manese Rabeony
Larry Dalton Talley
Pamela Jean Wright
Original Assignee
Exxon Production Reserch Company
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 Exxon Production Reserch Company filed Critical Exxon Production Reserch Company
Priority to AU36926/95A priority Critical patent/AU3692695A/en
Publication of WO1996008456A1 publication Critical patent/WO1996008456A1/fr

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Classifications

    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/52—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning
    • 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
    • C10L3/10—Working-up natural gas or synthetic natural gas
    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K2208/00—Aspects relating to compositions of drilling or well treatment fluids
    • C09K2208/22—Hydrates inhibition by using well treatment fluids containing inhibitors of hydrate formers

Definitions

  • the present invention relates to a method for inhibiting the formation of clathrate hydrates in a fluid. More specifically, the invention relates to a method for inhibiting the formation of gas hydrates in a pipe used to convey oil or gas.
  • water is typically found mixed in varying amounts with such petroleum fluid constituents.
  • clathrate hydrates can form when such petroleum fluid constituents or other hydrate formers are mixed with water.
  • Clathrate hydrates are water crystals which form a cage-like structure around guest molecules such as hydrate forming hydrocarbons or gases.
  • Some hydrate forming hydrocarbons include, but are not limited to, methane, ethane, propane, isobutane, butane, neopentane, ethylene, propylene, isobutylene, cyclopropane, cyclobutane, cyclopentane, cyclohexane, and benzene.
  • Some hydrate forming gases include, but are not limited to, oxygen, nitrogen, hydrogen sulfide, carbon dioxide, sulfur dioxide, and chlorine.
  • Gas hydrate crystals or gas hydrates are a class of clathrate hydrates of particular interest to the petroleum industry because of the pipeline blockages that they can produce during the production and/or transport of the natural gas and other petroleum fluids. For example, at a pressure of about IMPa ethane can form gas hydrates at temperatures below 4 °C, and at a pressure of 3MPa ethane can form gas hydrates at temperatures below 14 °C. Such temperatures and pressures are not uncommon for many operating environments where natural gas and other petroleum fluids are produced and transported.
  • a variety of measures have been used by the oil and gas industry to prevent the formation of hydrate blockages in oil or gas streams.
  • Such measures include maintaining the temperature and/or pressure outside hydrate formation conditions and introducing an antifreeze such as methanol, ethanol, propanol, or ethylene glycol. From an engineering standpoint, maintaining temperature and/or pressure outside hydrate formation conditions requires design and equipment modifications, such as insulated or jacketed piping. Such modifications are costly to implement and maintain.
  • the amount of antifreeze required to prevent hydrate blockages is typically between 10% to 20% by weight of the water present in the oil or gas stream. Consequently, several thousand gallons per day of such solvents can be required. Such quantities present handling, storage, recovery, and potential toxicity issues to deal with.
  • One method of practicing the present invention uses a first gas hydrate additive in combination with a second gas hydrate additive in the concentration ranges of about 0.01 % to about 5% and about 0.05% to about 6%, respectively, by weight of the water present in the oil or gas stream.
  • the additives of this invention can effectively treat a petroleum fluid having a water phase.
  • a method for inhibiting the formation of clathrate hydrates in a fluid having water and other hydrate forming constituents comprises treating the fluid with a first additive and a second additive, the first additive comprising a substantially water soluble polymer and having a first independent effect on the formation of clathrate hydrates in the fluid, the second additive comprising a substantially polar part and a substantially nonpolar part, wherein the nonpolar part is an alkyl, alkenyl, or alkynyl group with 12 or fewer carbon atoms and having a second independent effect on the formation of clathrate hydrates in the fluid, thereby producing a total inhibition effect for the fluid which is greater than the combination of the first and second independent effects for the fluid.
  • the invention can be practiced using any one of various treatment methods including, but not limited to, (1) treating the fluid with the first and second additive substantially simultaneously, (2) treating the fluid first with the first additive and treating it second with the second additive, or (3) treating the fluid first with the second additive and treating it second with the first additive.
  • the first additive comprises a water soluble polymer including, but not limited to, those selected from the group consisting of polyvinyllactams, polyalkylacrylamides, and polyalkyloxazolines, polyvinylcarboxylates, and copolymers thereof.
  • the second additive comprises those organic compounds selected from the group consisting of anionic, cationic, non-ionic, zwitterionic organic compounds and mixtures thereof. Such second additives include, but are not limited to, those selected from the group consisting of alcohols, ethers, and organic salts.
  • the claimed method inhibits the formation of clathrate hydrates in a fluid having hydrate forming constituents.
  • Formation of clathrate hydrates means the nucleation, growth, and/or agglomeration of clathrate hydrates.
  • Such clathrate hydrates may be formed in a fluid whether it is flowing or substantially stationary, but are often most problematic in flowing fluid streams conveyed in a pipe. For example, flow restrictions arising from partial or complete blockages in a fluid stream can arise as clathrate hydrates adhere to and accumulate along the inside wall of the pipe used to convey the fluid. Nonetheless, the invention can be used for inhibiting formation of clathrate hydrates in substantially stationary fluids.
  • a concentrated solution or mixture of a first additive comprising one or more substantially water soluble polymeric additives, and a second additive comprising one or more anionic, cationic, non-ionic, or zwitterionic organic compounds is introduced into a petroleum fluid stream having an aqueous phase.
  • a solution or mixture of additives described in this invention is substantially dissolved in the aqueous phase or dispersed in the fluid stream it reduces the rate that clathrate hydrates are formed and reduces their tendency to agglomerate into large masses, thereby reducing the tendency for a flow restriction to occur.
  • the first and second additive are first dissolved into an appropriate carrier solvent or liquid to make a concentrated solution or mixture.
  • an appropriate carrier solvent or liquid to make a concentrated solution or mixture.
  • many liquids may effectively facilitate treatment of the fluid stream without dissolving the additives. Because many of such liquids will preferably dissolve the additives, for convenience, they are referred to hereafter as solvents whether they produce an additive solution, emulsion, or other type of mixture.
  • the solvent's principal purpose is to act as a carrier for the first and second additive and to facilitate their absorption into the aqueous phase of the petroleum fluid. Any solvent suitable for delivering the additives to the fluid's aqueous phase may be used.
  • Such solvents include, but are not limited to, water, brine, sea water, produced water, methanol, ethanol, propanol, isopropanol, glycol or mixtures of such solvents.
  • Other solvents familiar to those skilled in the art may also be used.
  • a carrier solvent is not required in the practice of the invention, but it is a convenient method of introducing the additive into the fluid. In many applications the use of a carrier solvent will facilitate treatment of the fluid stream. It should also be understood that the two additives do not need to be mixed in the same carrier solvent. They can be mixed individually, in separate solvents, and introduced separately into the petroleum fluid. Alternatively, some of the second additives listed below do not need carrier solvents because they are liquids at normal ambient temperatures and pressures.
  • any convenient concentration of the additive in the carrier solvent can be used, so long as it results in the desired final concentration in the aqueous phase of the petroleum fluid. Higher concentrations are preferred, since they result in a reduced volume of concentrated mixture to handle and inject into the petroleum stream.
  • concentration of the organic compound additive is about four times that of the polymeric additive.
  • the additive mixture is introduced into the aqueous phase of the petroleum fluid using mechanical equipment, such as, chemical injection pumps, piping tees, injection fittings, and other devices which will be apparent to those skilled in the art. However, such equipment is not essential to practicing the invention. To ensure an efficient and effective treatment of the petroleum fluid with the additive mixture three points should be carefully considered.
  • an aqueous phase is preferably present at the location the additive mixture is introduced into the fluid.
  • an aqueous phase does not appear until the gas has cooled sufficiently for water to condense. If this is the case, the additive mixture is preferably introduced after the water has condensed.
  • the additive mixture concentration should be selected to ensure that the additive mixture's viscosity is sufficiently low to facilitate its dispersion through the fluid and permit it to reach the aqueous phase.
  • the additives primarily serve to inhibit the formation of clathrate hydrates, rather than reverse such formation, it is important to treat the fluid prior to substantial formation of clathrate hydrates.
  • Teq hydrate equilibrium dissociation temperature
  • a petroleum fluid's T e q will shift as the pressure applied to the fluid and its composition change.
  • the fluid should be treated with the first and second additives when the fluid is at a temperature greater than T e q. It is possible, but not preferable, to introduce the additives while the temperature is at or slightly below T e q, preferably before clathrate hydrates have begun to form.
  • hydrate nucleation and growth is inhibited but nonetheless hydrates can form, while the tendency for them to agglomerate is substantially reduced. Therefore, dispersed hydrates may be present in a petroleum fluid stream.
  • the fluid stream is gradually warmed to a temperature above its T e q to ensure any solid hydrates are melted and do not interfere with other processes.
  • the quantity of the first additive introduced into a petroleum fluid with an aqueous phase solvent will typically vary between about 0.01 wt% to about 5 wt% by weight of the water present in the fluid.
  • the quantity of the second additive introduced into a petroleum fluid with an aqueous phase solvent will typically vary between about 0.05% to about 6% by weight of the water present in the fluid.
  • the first additive concentration will be about 0.5 wt% and the second additive will be about 2 wt%.
  • PDMAM Poly(N,N-dimethylacrylamide)
  • PDEAM Poly(N,N-diethylacrylamide)
  • PEOx Poly(2-ethyl-2-oxazoline)
  • PVP Poly(vinylpyrrolidone)
  • PVCap Poly(vinylcaprolactam)
  • VP/VPro Copolymer of N-vinyl pyrrolidone and vinyl propionate
  • VP/SPP Copolymer of N-vinyl pyrrolidone and N-(3-sulfopropyl)-N-methacryloylamidopropyl-N,N- dimethylammonium betaine
  • PEFAm Poly(ethenylformamide)
  • x and y are average integers sufficient to produce an average molecular weight between about 1,000 and about 1,000,000.
  • a polymer's average molecular weight it is well understood by those skilled in the art that a given polymer composition is comprised of polymers having variable chain lengths and molecular weights, with some above and some below the polymer's average molecular weight. Therefore, some polymer chains contain less than x repeating units and some polymer chains contain more than x repeating units. Accordingly, x represents an average number of repeating units over the distribution of polymer chains comprising a given polymer composition.
  • Na C4 Sulfate Sodium salt of n-butyl sulfate - 2 . 2 -.
  • Na C4 Sulfonate Sodium salt of n-butyl sulfonic acid 3 2 2 2 3
  • Butyl Zwitterion C4 Zwitterion CH 3 --(CH 2 ) 3 -- + N-(CH 3 ) 2 --(CH 2 ) 4 --SO 3
  • VP/VPro is prepared by copolymerizing vinyllpyrrolidone and vinyl propionate, both commercially available monomers, using known procedures (Hayashi and Smets, J. Polym. Sci., 27, 275 (1958) or EP 0 104 042 A2).
  • VP/SPP is prepared as described by Schulz, et al. in "Polymers In Aqueous Media - Performance Through Association,” Advances in Chemistry Series, 222, Amercian Chemical Society, Washington, D.C., 1989, Chapter 9.
  • the ionic and non- ionic organic additives are all commercially available materials or can be produced by neutralization of commercially available precursors.
  • THF test typically uses 3mL of tetrahydroftiran (THF) and 9 mL of ASTM synthetic seawater (SSW) containing the desired amount of additive.
  • THF and SSW are placed in a capped test tube (15 mm OD x 12.5 cm long) with a 0.95 centimeter stainless steel ball.
  • Each tube is placed in a ferriswheel-type holder and placed in a cooling bath held near 0 °C.
  • the tubes are rotated to facilitate mixing of the samples.
  • the tubes are monitored visually and recorded with a video camera.
  • BST ball stop time
  • the BST is an approximate indication of an additive's effectiveness. Because the THF/SSW solution has a T eq of about 2-5 °C and THF is miscible with water, hydrate formation is substantially accelerated for the THF/SSW solution as compared to petroleum fluids conveyed in a pipeline or flowline under typical field conditions. Therefore, BSTs are useful for indicating which additives may be effective under field applications.
  • a BST for a THF/SSW solution with an additive which is about three times the BST for a THF/SSW control solution with no additive present indicates that the additive demonstrates a threshold inhibition effect.
  • a threshold inhibition concentration means the additive concentration in a THF/SSW solution required to produce a BST which is about three times the BST for a THF/SSW control solution.
  • Some additives may have a BST indicating a nominal or no inhibition effect compared to the BST for the THF/SSW control solution ("control BST") or a BST indicating formation of hydrates is accelerated compared to the control BST. Consequently, an additive with a BST which is equal to the control BST is identified as having no inhibition effect or a null effect. An additive with a BST which is between the control BST and about three times the control BST is identified as having a nominal inhibition effect.
  • An additive with a BST which is less than the control BST is identified as having an a hydrate activation effect.
  • a hydrate activation effect indicates that an additive with such a BST accelerates or enhances the rate of hydrate formation compared to the THF/SSW control. Because the THF test results are sensitive to variations in the temperature at which the test is run, rotation frequency of the tube, clearances between the stainless steel ball and tube wall, etc., it is important to run a THF/SSW control solution with each additive evaluation to ensure that an additive's TIC is accurately measured and that a reliable threshold inhibition effect is observed. THE Test Results
  • various polymeric and organic additives were evaluated alone and in combination with each other including PVP, PEOx, PVCap, VP/VPro, VP/SPP, PEFAm, PDMAM, PDEAM, PMAM, Na C4 Sulfate, Na C4 Sulfonate, Na C8 Sulfonate, Na Valerate, C4 Zwitterion and MeOH.
  • a 2 wt% solution of Na C4 Sulfonate demonstrated an inhibition effect above the threshold inhibition effect with a BST that's 3.75 times the control sample's BST.
  • a 2 wt% solution of Na C4 Sulfate demonstrated an inhibition effect below the threshold inhibition effect with a BST that's only 2.1 times the control sample's BST. Consequently, a higher concentration of Na C4 Sulfate would be required to reach its TIC.
  • a synergistic inhibition effect occurs when a substantially water soluble polymer is combined with an organic compound having a substantially nonpolar part and substantially polar part and the nonpolar part is an akyl, alkenyl, or alkynyl group 12 or fewer carbon atoms.
  • the synergy for the combination of the first and second additive is evidenced by the combination having a BST or total inhibition effect which is greater than the sum of the respective BST or inhibition effects observed for each additive independent of the other.
  • the synergistic inhibition effect was not demonstrated with PEFAm at a concentration below its TIC in combination with Na C4 Sulfate.
  • polymeric additives, such as PEFAm or PDMAM which demonstrated an inhibition effect below the threshold inhibition effect when used alone, did demonstrate a synergistic inhibition effect in combination with an alcohol such as methanol.
  • the synergistic inhibition effect will be observed with other organic compounds including, but not limited to, nitrogen containing hydrocarbons such as alkyl pyrrolidone, other salts of carboxylic acids, other zwitterions, and other alcohols including ethoxylated alcohols such as 2-butoxy ethanol and diol alcohols such as ethylene glycol or propylene glycol.
  • the substantially nonpolar group may contain one or more double or triple bonded carbon atoms provided the group contains 12 or fewer carbon atoms. Accordingly, the substantially nonpolar group can comprise an alkenyl or alkynl group, as well as, an alkyl group.
  • the presence of a synergistic inhibition effect can be determined by conducting a THF test of a solution containg the first additive, a solution containing the second additive and a solution containing a combination of the first and second additive. A synergism is obtained where the inhibition effect for the combination exceeds the sum of the independent inhibition effects for the first and second additives.
  • a synergistic inhibition effect can also occur using a polymeric additive which demonstrate good inhibition effects when used alone, such as PDEAM.
  • a polymeric additive which demonstrate good inhibition effects when used alone, such as PDEAM.
  • the synergistic inhibition effect is observed with PDEAM used at a 0.05wt% concentration. Therefore, the synergistic inhibition effect may be observed at very low concentrations for the first additive by conducting a series THF tests with a range of different concentrations for the first additive. Such a series of tests will confirm the presence of the synergistic inhibition effect and demonstrate the extent to which additive concentrations influence such an effect.
  • the second additives are organic compounds comprising a substantially polar part and substantially nonpolar part with the nonpolar part having an alkyl, alkenyl, or alkynyl group with 12 or fewer carbon atoms.
  • the nonpolar part is directly bonded to the polar part.
  • directly bonded we mean that there are no intervening functional groups between the polar and nonpolar parts which would disrupt the continuity of the bond between the polar and nonpolar part.

Abstract

L'invention concerne un procédé empêchant la formation d'hydrates de clathrate dans un fluide contenant des constituants de formation d'hydrates. Plus particulièrement, le procédé peut s'appliquer au traitement d'un courant de fluide de pétrole tel que du gaz naturel transporté dans une conduite afin d'empêcher la formation d'un hdyrate qui pourrait constituer une restriction à l'intérieur de la conduite. Le procédé utilise un mélange comprenant un premier additif et un second additif. Le mélange produit un effet d'inhibiton d'hydrate synergique. Le premier additif est choisi dans la classe des polymères sensiblement hydrosolubles. Le second additif est choisi dans la classe des composés organiques ioniques ou non ioniques qui ont une partie polaire et une partie non polaire, la partie non polaire comprenant un groupe alkyle, alcényle, ou alcynyle ayant 12 atomes de carbone ou moins.
PCT/US1995/011356 1994-09-15 1995-09-05 Procede empechant la formation d'hydrates WO1996008456A1 (fr)

Priority Applications (1)

Application Number Priority Date Filing Date Title
AU36926/95A AU3692695A (en) 1994-09-15 1995-09-05 A method for inhibiting hydrate formation

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
US08/306,568 1994-09-15
US08/306,568 USH1749H (en) 1994-09-15 1994-09-15 Method for inhibiting hydrate formation

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WO1996008456A1 true WO1996008456A1 (fr) 1996-03-21

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EP0777837A1 (fr) * 1994-09-15 1997-06-11 Exxon Production Research Company Procede d'inhibition de la formation d'hydrates
DE19803384C1 (de) * 1998-01-29 1999-04-15 Clariant Gmbh Additive zur Inhibierung der Gashydratbildung und Verfahren zur Inhibierung der Bildung von Gashydraten
EP0946470A1 (fr) * 1996-11-06 1999-10-06 Isp Investments Inc. Procede visant a empecher ou a retarder la formation d'hydrates de gaz
WO1999064717A1 (fr) * 1998-06-05 1999-12-16 Basf Aktiengesellschaft Utilisation d'homopolymeres et de copolymeres de formamide de vinyle pour inhiber des hydrates de gaz
EP1048892A1 (fr) * 1999-04-29 2000-11-02 Institut Francais Du Petrole Formulation d'additifs pour améliorer le transport d'effluents pétroliers susceptibles de contenir des hydrates et procédé utilisant cette formulation
EP1243637A2 (fr) * 2001-03-24 2002-09-25 Clariant GmbH Additifs pour inhiber la formation d'hydrate de gaz
WO2002074722A1 (fr) 2001-03-20 2002-09-26 Isp Investments Inc. Inhibiteur d'hydrate de gaz
US6566309B1 (en) 1999-05-03 2003-05-20 Clariant Gmbh Additives for inhibiting gas hydrate formation
EP1824804A2 (fr) * 2004-11-04 2007-08-29 Nalco Company Amphiphiles de paire d'ions utilises comme inhibiteurs d'hydrates
RU2508308C2 (ru) * 2009-01-26 2014-02-27 Статойл Петролеум Ас Способ регенерации ингибитора образования гидратов

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Cited By (19)

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Publication number Priority date Publication date Assignee Title
EP0777837A4 (fr) * 1994-09-15 1999-09-22 Exxon Production Research Co Procede d'inhibition de la formation d'hydrates
EP0777837A1 (fr) * 1994-09-15 1997-06-11 Exxon Production Research Company Procede d'inhibition de la formation d'hydrates
WO1997007320A1 (fr) * 1995-08-16 1997-02-27 Exxon Production Research Company Procede de selection d'un polymere destine a inhiber la formation d'hydrates
EP0946470A4 (fr) * 1996-11-06 2000-12-27 Isp Investments Inc Procede visant a empecher ou a retarder la formation d'hydrates de gaz
EP0946470A1 (fr) * 1996-11-06 1999-10-06 Isp Investments Inc. Procede visant a empecher ou a retarder la formation d'hydrates de gaz
DE19803384C1 (de) * 1998-01-29 1999-04-15 Clariant Gmbh Additive zur Inhibierung der Gashydratbildung und Verfahren zur Inhibierung der Bildung von Gashydraten
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WO1999064717A1 (fr) * 1998-06-05 1999-12-16 Basf Aktiengesellschaft Utilisation d'homopolymeres et de copolymeres de formamide de vinyle pour inhiber des hydrates de gaz
US6417417B1 (en) 1999-04-29 2002-07-09 Institut Francais Du Petrole Additive formulation for improving transport of oilfield effluents which may contain hydrates, and a process using this formulation
FR2792997A1 (fr) * 1999-04-29 2000-11-03 Inst Francais Du Petrole Formulation d'additifs pour ameliorer le transport d'effluents petroliers susceptibles de contenir des hydrates et procede utilisant cette formulation
EP1048892A1 (fr) * 1999-04-29 2000-11-02 Institut Francais Du Petrole Formulation d'additifs pour améliorer le transport d'effluents pétroliers susceptibles de contenir des hydrates et procédé utilisant cette formulation
US6566309B1 (en) 1999-05-03 2003-05-20 Clariant Gmbh Additives for inhibiting gas hydrate formation
WO2002074722A1 (fr) 2001-03-20 2002-09-26 Isp Investments Inc. Inhibiteur d'hydrate de gaz
EP1243637A2 (fr) * 2001-03-24 2002-09-25 Clariant GmbH Additifs pour inhiber la formation d'hydrate de gaz
EP1243637A3 (fr) * 2001-03-24 2004-01-02 Clariant GmbH Additifs pour inhiber la formation d'hydrate de gaz
US6894007B2 (en) 2001-03-24 2005-05-17 Clariant Gmbh Additives for inhibiting gas hydrate formation
EP1824804A2 (fr) * 2004-11-04 2007-08-29 Nalco Company Amphiphiles de paire d'ions utilises comme inhibiteurs d'hydrates
EP1824804A4 (fr) * 2004-11-04 2009-03-04 Nalco Co Amphiphiles de paire d'ions utilises comme inhibiteurs d'hydrates
RU2508308C2 (ru) * 2009-01-26 2014-02-27 Статойл Петролеум Ас Способ регенерации ингибитора образования гидратов

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