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WO2008089262A1 - Procédé et pilule permettant de remédier aux blocages dus à des hydrates dans des pipelines - Google Patents

Procédé et pilule permettant de remédier aux blocages dus à des hydrates dans des pipelines Download PDF

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Publication number
WO2008089262A1
WO2008089262A1 PCT/US2008/051200 US2008051200W WO2008089262A1 WO 2008089262 A1 WO2008089262 A1 WO 2008089262A1 US 2008051200 W US2008051200 W US 2008051200W WO 2008089262 A1 WO2008089262 A1 WO 2008089262A1
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WO
WIPO (PCT)
Prior art keywords
hydrate
glycol
pill
gas
push
Prior art date
Application number
PCT/US2008/051200
Other languages
English (en)
Inventor
Michael A. Freeman
Robert L. Horton
Lee Conn
John W. Vian
Morris Arvis, Jr.
Original Assignee
M-I Llc
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 M-I Llc filed Critical M-I Llc
Publication of WO2008089262A1 publication Critical patent/WO2008089262A1/fr

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Classifications

    • 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
    • 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
    • C10L5/00—Solid fuels
    • C10L5/02—Solid fuels such as briquettes consisting mainly of carbonaceous materials of mineral or non-mineral origin
    • C10L5/34—Other details of the shaped fuels, e.g. briquettes
    • C10L5/36—Shape
    • 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

  • Embodiments disclosed herein relate generally to push pills for use in remediating hydrate condensate blockage in pipelines.
  • Low-molecular-weight hydrocarbons such as methane, ethane, propane, butane and iso-butane, and sometimes other low-molecular-weight species such as CO 2 and H 2 S, are normally present in pipelines or other conduits used in the transportation and processing of natural gas and crude oil.
  • gas hydrate crystals typically are formed.
  • LDHFs low-dosage-hydrate-inhibitors
  • Gas hydrates are clathrates (inclusion compounds) in which small hydrocarbon molecules are trapped in a lattice consisting of water molecules. Hydrates form as a consequence of the tendency of water to reorient in the presence of a non-polar solute (typically light hydrocarbon gases such as methane) to stabilize the lattice through, typically, van der Waals interactions while maintaining the hydrogen bonding between the water molecules.
  • a non-polar solute typically light hydrocarbon gases such as methane
  • Tetrahydrofuran, jy-dioxane, CO 2 , and H 2 S to name a few other compounds in addition to the low-molecular- weight hydrocarbons are capable of occupying the interior positions in a clathrate lattice of water molecules and stabilizing the overall structure so that it does not decompose until a relatively substantial increase in temperature or decrease in pressure occurs or both occur.
  • Tetra-hydrofuran and />-dioxane are not commonly found in pipelines; but CO 2 , H 2 S, and low-molecular-weight hydrocarbons are.
  • the volume of methanol or ethylene glycol needed to effect dissolution of the plug may far exceed the amount required to sufficiently dilute the melt water. In fact, it may be necessary to entirely fill the pipeline from the point of injection to beyond the location of the hydrate plug with solvent. This large volume may exceed the total globally available solvent readily available on short notice.
  • Other fluids such as non-hydrate forming gases or liquids, such as oil or natural gas condensate, may be available to fill the pipe and deliver the hydrate-melting solvent to the plug, but many pipelines follow a course of rising and falling elevations along their route. The "valleys" formed between elevations serve as low points where higher density fluids may settle out.
  • solvents effective for dissolving water and hydrate and preventing re-formation of hydrates are denser than oil, and especially gas condensate.
  • the pill should spontaneously de-viscosify upon contact with the hydrate or water so as to release the solvent for combination with the aqueous phase.
  • viscosifiers such as xanthan gum, hydroxyethyl cellulose (HEC), etc.
  • HEC hydroxyethyl cellulose
  • the viscosified pill may de-viscosify upon contact with the hydrate or water, so as to release solvent for combination with the aqueous phase.
  • embodiments disclosed herein relate to a method for dissolving a gas-hydrate agglomerate, comprising introducing a push pill to the gas-hydrate agglomerate, the push pill comprising a hydrate inhibitor; and a viscosifying agent wherein when said viscosifying agent is exposed to free water, the viscosifying agent does not substantially result in an increase in viscosity.
  • embodiments disclosed herein relate to a method for treating a hydrocarbon conduit that includes emplacing a push pill in the hydrocarbon conduit, wherein the hydrocarbon conduit has a gas-hydrate agglomerate therein, the push pill comprising: a hydrate inhibitor; and a viscosifying agent wherein when said viscosifying agent is exposed to free water, the viscosifying agent does not substantially result in a increase in viscosity of the push pill; and substantially reducing the gas-hydrate agglomerate.
  • embodiments disclosed herein relate to a method for dissolving a gas-hydrate agglomerate that includes introducing a push pill to the gas- hydrate agglomerate, the push pill comprising: a glycol; a chelating or viscosifier- so lvati on-promoting agent; a viscosifier wherein when the viscosifier is exposed to free water, the viscosifier does not substantially result in an increase in the viscosity of the treatment pill; and a glycol-soluble base capable of neutralizing or partially neutralizing acidity induced by the addition of said chelating or viscosifier-so ⁇ vation- promoting agent.
  • embodiments disclosed herein relate to push pills for use in remediating a conduit or pipeline having a gas-hydrate plug or agglomeration of crystals therein.
  • embodiments disclosed herein relate to push pills that may be used in conjunction with other remediation techniques (such as hot condensates) to assist in remediating the conduit.
  • a high glycol push pill is desired to assist in applying condensate at, for example, 80 0 C to melt away a partial ( ⁇ 70%) plug in a 36" gas pipeline because the glycol will contact the hydrate.
  • a high glycol push pill is desired to assist in applying condensate at, for example, 80 0 C to melt away said partial plug in a 36" gas pipeline because as the hot condensate contacts hydrate agglomerates and begins to melt them, any water that comes from melted hydrate will be "sopped up" or captured by the glycol in the push-pill. Capture of the water released from the gas-hydrate is necessary to ensure that the released water does not subsequently cool down and re-form hydrates.
  • the pill when the pill is formulated with conventional polymers, such as, for example, HEC or xanthan gum, the pill will only have a suitable viscosity to serve as a push pill with a sufficient amount of polymer dissolved in the pill; but when the pill starts melting away the hydrate or when the hot condensate pill that the viscosified glycol pill is pushing begins to melt away the hydrate (or both), the resulting water can cause the polymer in the push pill to hydrate and yield, making a very high viscosity plug, even a semi-solid.
  • conventional polymers such as, for example, HEC or xanthan gum
  • the push pills of the present disclosure may include a hydrate inhibitor, a viscosifier (or viscosifying agent), and optionally, a chelating agent (or viscosifier-solvation-promoting agent).
  • Hydrate inhibitors suitable for use in the remediating pills of the present disclosure include those compounds, such as glycols, methanol or other alcohols, or brine which act to melt gas-hydrate crystals, releasing water molecules from surrounding gas molecules.
  • the mechanism through which an alcohol may work to melt a gas-hydrate is thought to be twofold. First, an alcohol may form hydrogen bonds with water using its OH-groups, and secondly it tends to cluster water molecules around its hydrocarbon ends, which effectively "captures" the released water and may reduce or prevent any subsequent re-formation of gas-hydrates.
  • the hydrate inhibitor may be present in the pill in an amount ranging from 30 to 99.9 percent by weight of the pill.
  • the hydrate inhibitor may include a C2-C6 alkyl glycol.
  • the hydrate inhibitor may include at least one of ethylene glycol, propylene glycol, butylene glycol, and combinations thereof.
  • Brines suitable for use as a hydrate inhibitor may include seawater, aqueous solutions wherein the salt concentration is less than that of sea water, or aqueous solutions wherein the salt concentration is greater than that of sea water.
  • the salinity of seawater may range from about 1 percent to about 4.2 percent salt by weight based on total volume of seawater.
  • the solutions typically contain metal salts, such as but not limited to, transition metal salts, alkali metal salts, alkaline earth metal salts, and mixtures thereof.
  • Exemplary salts include halides of zinc, calcium, and mixtures thereof.
  • the solution can include zinc halide, such as zinc bromide or zinc chloride or both, optionally in combination with calcium bromide or calcium chloride or both.
  • Salts that may be found in seawater include, but are not limited to, sodium, calcium, aluminum, magnesium, potassium, strontium, and lithium salts of chlorides, bromides, carbonates, iodides, chlorates, bromates, formates, nitrates, oxides, silicates, sulfates, phosphates, and fluorides.
  • Salts that may be incorporated in a given brine include any one or more of those present in natural seawater or any other organic or inorganic dissolved salts.
  • brines that may be used in the fluids disclosed herein may be natural or synthetic, with synthetic brines tending to be much simpler in constitution.
  • the density of the fluid may be controlled by increasing the salt concentration in the brine (up to saturation).
  • a brine may include halide or carboxylate salts of mono- or divalent cations of metals, such as cesium, potassium, calcium, zinc, and/or sodium.
  • the brine solution can include the salts in conventional amounts, generally ranging from about 1% to about 80%, and preferably from about 20% to about 60%, based on the total weight of the solution, although as the skilled artisan will appreciate, amounts outside of this range can be used as well.
  • embodiments of the present disclosure may further use "specialty" brines that include at least one alkali metal salt of a transition metal oxy-anion or polyoxy-anion, such as, for example, an alkali metal polytungstate, an alkali metal heteropolytungstate, an alkali metal polymolybdate or an alkali metal heteropolymolybdate.
  • a transition metal oxy-anion or polyoxy-anion such as, for example, an alkali metal polytungstate, an alkali metal heteropolytungstate, an alkali metal polymolybdate or an alkali metal heteropolymolybdate.
  • Viscosifying agents or viscosifiers suitable for use in the pills of the present disclosure include those compounds that do not substantially hydrate or result in a substantial increase in a viscosity when exposed to free water. That is, as the gas- hydrate agglomerate is melted by the hydrate inhibitor of the present disclosure, releasing free water, the formation of a hydrated viscosifier may be at least reduced or prevented.
  • the viscosifier may be at least one of diutan gum.
  • the viscosifier may be present in an amount ranging from about 0.1 percent by weight of the pill up to its solubility limit in glycol.
  • viscosifier is ECF-612, which is commercially available from M-I LLC, Houston, TX, and which as a chemical structure as follows:
  • WO07/005499 which is herein incorporated by reference in its entirety, describes such types of crosslinked polymers that may be used as a viscosifier in the push pill of the present disclosure.
  • An example of a commercially available source of a crosslinked polymer additive that may be used in a push pill of the present disclosure is SAFE-LINKTM, available from M-I LLC (Houston, Texas).
  • Embodiments of crosslinked polymers of the present disclosure may use a number of "natural" polymers.
  • Such polymers include HEC, derivatized HEC, guars, derivatized guars, starches, derivatized starches, scleroglucans, wellan gums, locust bean gum, karaya gum, gum tragacanth, carrageenans, alginates, gum arabic, and biopolymers, such as, for example that derived from fermentation with xanthomonas campest ⁇ s, and other similar polymers.
  • embodiments of the present disclosure may also use a number of
  • “synthetic” polymers either exclusive of the aforementioned “natural” polymers or in combination therewith.
  • “Synthetic” polymers include poly(ethylene glycol) (PEG), poly(diallyl amine), poly(acrylamide), poly(acrylonitrile), polyvinyl acetate), poly(vinyl alcohol), poly(aminomethylpropylsulfonate[AMPS]), poly(vinyl amine), polyvinyl sulfonate), poly(styryl sulfonate), poly(acrylate), poly(methyl acrylate), poly(methacrylate), poly(methyl methacrylate), polyvinylpyrrolidone), poly(vinyl lactam), co-, ter-, and quater-polymers of the following co-monomers: ethylene, butadiene, isoprene, styrene, divinylbenzene, divinyl amine, l,4-pentadiene-3-one
  • crosslinked HEC and its derivates may be used as the viscosifier to form the push pill of the present disclosure.
  • ECF-680 may be used.
  • ECF-680 is a slurry of a doubly derivatized hydroxyethyl cellulose in an inert, water-miscible carrier fluid.
  • ECF-680 is available commercially from Special Products, Inc., a subsidiary of Champion Technologies,
  • DDHEC may be synthesized by grafting monomers of vinyl phosphonic acid (VPA) onto cellulose polymers according to methods disclosed in U.S. Pat No. 5,304,620 (Holtmyer '620), U.S. Pat. No.
  • VPA vinyl phosphonic acid
  • a crosslinking agent In order to form a suitable crosslinked polymer, typically a crosslinking agent must be added to whatever polymer - natural or synthetic - is used.
  • magnesium oxide is used as a crosslinking agent or as a crosslinking activator.
  • One suitable form of magnesium oxide is a very fine powder is a highly reactive form, i.e., having small particle size, high surface area, and ready accessibility for reaction.
  • One example of such a fine powder magnesium oxide is available commercially from M-I LLC under the trade name of DI-BALANCETM.
  • magnesium oxide system One useful feature of the magnesium oxide system is that the crosslinking does not occur immediately, but instead occurs over the course of several hours, leading to doubling of the apparent viscosity of the mixture during the first part of an hour and gradually increasing to about 50 percent of its ultimate value upon sitting for several hours at room temperature.
  • other polymers similar to DDHEC including, for example, similarly modified cellulose, guar, or hydroxypropyl guar or synthetic co- or ter-polymers in which one of the co-monomers is vinyl phosphonic acid, such as, for example, those disclosed in U.S. Patent Application No. 60/948,833, filed on July 10, 2007, which is assigned to the present assignee and herein incorporated by reference in its entirety.
  • crosslinking HEC other compounds for crosslinking HEC may be used.
  • titanium or zirconium may be used to crosslink HEC.
  • U.S. Patent No. 6,342,467 discloses one method for crosslinking HEC that involves the use of zirconium or titanium.
  • the crosslinking agent can be any convenient source of zirconium ions.
  • a preferred crosslinking additive is a zirconium chelate such as zirconium lactate.
  • suitable zirconium compounds include zirconyl chloride, sodium zirconium lactate and zirconium acetylacetonate.
  • the delay agent is preferably the sodium counterpart of these zirconium compounds.
  • the push pill may include a mixture of viscosifiers such that the mixture of viscosifiers does not substantially hydrate or result in a substantial increase in viscosity when exposed to free water.
  • a mixture of viscosifiers such as diutan and HEC or xanthan gum, may be used in the push pill.
  • diutan and HEC or xanthan gum may be used in the push pill.
  • the amounts or ratios of diutan to either HEC or xanthan gum, for example may depend on the ability of the mixture to avoid substantial hydration.
  • a push pill may contain 1.33 ppb diutan (such as ECF-612, available from M-I LLC) with either 0.133 ppb HEC or 0.133 ppb xanthan gum (such as FLO- VIS ® , available from M-I LLC).
  • one embodiment of the viscosified push pill of the present disclosure may be formed in situ, for example, by crosslinking between glycol, such as those described above, and calcium present in a brine.
  • such resulting crosslinked glycol push pill may include both the hydrate inhibitor and viscosifier as described herein. The formation of a plug by the reaction of calcium and a glycol is described in U.S.
  • a calcium brine may be present in or may be injected into a conduit having a hydrate agglomerate therein.
  • a glycol pill may be emplaced in the conduit, whereby upon reaction with calcium, the push pill of the present disclosure may be formed in situ.
  • the water activity of the released water may be reduced by presence of the pill components such that hydrate agglomeration may be reduced or prevented.
  • chelating agents include at least one of ethylenediamine tetraacetic acid, citric acid, glutamic diacetic acid, nitrilotriacetic acid, the alkali and alkaline earth salts of these, and combinations thereof.
  • the chelating agent may be present in amount ranging from about 0.1 percent by weight of the pill up to its saturation point in the glycol.
  • no chelating (or viscosifier-solvation-promoting agent) is present in the push pill.
  • a viscosifier-solvation-promoting for example ethylene glycol, propylene glycol, and/or butylene glycol, may be used to assist in the formation of the push pill.
  • a viscosifier-solvation-promoting agent may be used as a "co-solvent" to hydrate or solvate a solid or slurry of viscosifier, such as a DDHEC.
  • a crosslinking agent such as MgO, may be added to raise the pH and cause crosslinking of the polymer and an increase in the viscosity of the pill.
  • a glycol-soluble base may be included in the push pill that is capable of neutralizing or partially neutralizing acidity induced by the addition of said chelating or viscosifier-solvation-promoting agent.
  • the glycol-soluble base may include a morpholine or a morpholine process residue
  • ECF-612, ECF-687, SAFE- CORTM, SAFE-CIDETM, and EMI-530 are available from M-I LLC, Houston, TX.
  • Embodiments disclosed herein may further comprise other additional components, including, but not limited to, different controlling chemistries such as neutralizers, corrosion inhibitors, wax inhibitors, asphaltene inhibitors and other hydrate inhibitors and/or solvents.
  • controlling chemistries such as neutralizers, corrosion inhibitors, wax inhibitors, asphaltene inhibitors and other hydrate inhibitors and/or solvents.
  • the push pill disclosed herein may also contain at least one additional salt, including any salt that may be incorporated in brines, as disclosed herein.
  • at least one of sodium chloride, calcium chloride, potassium chloride, and sodium carbonate may be incorporated in the push pill disclosed here.
  • the at least one additional salt may incorporated into the push pill disclosed herein in an amount ranging from about 0.5 weight percent to salt saturation.
  • a push pill of the present disclosure may emplaced in a conduit in a variety of manners and means, such as by a progressive cavity pump, and may be moved within the conduit as a piston, with the application of pneumatic or hydraulic pressure.
  • the movement of the push pill may be used to push or convey materials (fluid or solid materials) along the conduit and/or may be used to separate two species from each other in the conduit.
  • a push pill(s) of the present disclosure may be emplaced to dissolve a hydrate agglomerate, assist in absorbing water released from a hydrate agglomerate, and/or assist in the emplacement of a hydrate inhibitor, for example, an unviscosified inhibitor, to dissolve a hydrate agglomerate.
  • a hydrate inhibitor for example, an unviscosified inhibitor
  • a first push pill comprising a glycol and a diutan gum may emplaced, optionally behind a slug of unviscosified hydrate inhibitor(s) and/or a slug of hot condensate.
  • a second pill comprising a brine and a crosslinked DDHEC may optionally be emplaced in conjunction with (either prior to or following) the first pill, or alternatively, the second pill may be emplaced without the first pill.
  • the push pills of the present disclosure may be pumped from the conduit, such as by means similar to those used in emplacing the pill, or alternatively, in the case of a crosslinked viscosifier, the pill may be optionally "broken" in situ, for example, by the application of a weak acid or pH 4 buffer solution.
  • the gas hydrate plug has separated a pipe into two zones: a high pressure zone between the head well and the hydrate plug and a low pressure zone between the hydrate plug and the production facilities area
  • the pressure in the pipeline may be raised in the zone between the push pill and the production facilities area, preferably to the point that the pressure between the push pill and the production facilities area is equal to or greater than that in the "high pressure" zone between the head well and the hydrate plug.
  • This pressurization could be effected using "dry" gas containing little or no hydrate-forming components or condensate or diesel fuel containing little or no hydrate-forming components.
  • hot condensate for example, may optionally be injected between the push pill and the hydrate plug.
  • the composition of the hot condensate would be controlled so as to contain little or no hydrate-forming components.
  • This injection may be accompanied by further increase in the pressure between the push pill and the production facilities area so that if the hydrate plug were suddenly to become unstuck from the pipe wall, any projectile generated would tend to move away from the facilities apparatus, reducing or eliminating any risk that the pipeline in this area or the production facilities farther downstream might be damaged. While there may still be a potential risk for generation of a projectile, in some embodiments, this may be desired, such as when the pipeline leading to the reservoir and the reservoir itself possess a buffering volume that could receive the reflux without much increase in pressure.
  • remediation techniques of the present disclosure may also be used in any other types of storage vessels or containers in which gas hydrates may have formed, such as, for example, natural gas storage chambers.
  • Pills 1 and 2 Two remediating push pill, Pills 1 and 2, were formulated as shown in Table 2 below.
  • Pills 1 and 2 were investigated, at various temperatures and conditions, with increasing amounts of water present, using a Farm 35 viscometer. The results are presented in Table 3a and 3b below.
  • Tables 3a and 3b shows that Pills 1 and 2 have a sufficient viscosity for effective emplacement, and are likely to act as thermodynamic hydrate inhibitors which will contact the hydrate condensate directly, melt or extract water therefrom, and thereby remove the blockage from the pipeline. Further, as Pills 1 and 2 were diluted with increasing amounts of water, it can be shown that the viscosity of the fluid did not substantially increase, and in fact the rpm measurements show a decrease in viscosity. [0051] Example 2
  • Pills 3-5 Three remediating push pill, Pills 3-5, were formulated as shown in Table 4 below.
  • a push pill having properties such as viscosity, thermal stability, ability to suppress conductive heat loss, and/or heat conveyance, may be used in remediating conduits having gas-hydrate agglomerates stuck therein. If used in conjunction with a primary remediation technique, such as a hot condensate, the pills of the present disclosure may capture released water to at least reduce the incidence of further formation of gas hydrates.
  • the pill may have a sufficient viscosity to drive the emplacement of a hot condensate to the blockage in a conduit, while remaining intact with close exposure to the elevated temperature of the hot condensate. Further, a sufficient emplacement viscosity may be obtained with minimal occurrence of complicating side effects, such as polymer hydrate blockage.

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Abstract

L'invention concerne un procédé permettant de dissoudre un agglomérat d'hydrate de gaz, comprenant l'introduction d'une pilule de poussée jusqu'à l'agglomérat d'hydrate de gaz, cette pilule de poussée contenant un inhibiteur d'hydrate et un agent de viscosité. Lorsque ce dernier est exposé à de l'eau libre, il n'entraîne pas une augmentation sensible de la viscosité.
PCT/US2008/051200 2007-01-21 2008-01-16 Procédé et pilule permettant de remédier aux blocages dus à des hydrates dans des pipelines WO2008089262A1 (fr)

Applications Claiming Priority (4)

Application Number Priority Date Filing Date Title
US88591407P 2007-01-21 2007-01-21
US60/885,914 2007-01-21
US89436307P 2007-03-12 2007-03-12
US60/894,363 2007-03-12

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WO2010042482A1 (fr) * 2008-10-06 2010-04-15 Nalco Company Compositions et procédés d'inhibition de l'agglomération d'hydrates
WO2010101853A1 (fr) * 2009-03-02 2010-09-10 Nalco Company Compositions contenant des agents tensio-actifs de type amide et procédés d'inhibition de la formation d'agglomérats d'hydrates
WO2010104727A1 (fr) * 2009-03-09 2010-09-16 Nalco Company Compositions et procédés pour inhiber l'agglomération d'hydrates dans un procédé
WO2010129831A2 (fr) 2009-05-08 2010-11-11 M-I L.L.C. Fluides porteurs de gravillonnage des crépines
US8058374B2 (en) 2005-07-21 2011-11-15 Akzo Nobel N.V. Hybrid copolymers
US8105988B2 (en) 2008-10-06 2012-01-31 Nalco Company Corrosion inhibitors for a fluid
US8105987B2 (en) 2008-10-06 2012-01-31 Nalco Company Corrosion inhibitors for an aqueous medium
WO2012080296A1 (fr) * 2010-12-17 2012-06-21 Akzo Nobel Chemicals International B.V. Procédé et solution pour l'amélioration de la perméabilité de formations de grès à l'aide d'un agent chélatant
WO2012080463A1 (fr) * 2010-12-17 2012-06-21 Akzo Nobel Chemicals International B.V. Fluide approprié pour le traitement de formations de carbonate contenant un agent de chélation
WO2012080299A1 (fr) * 2010-12-17 2012-06-21 Akzo Nobel Chemicals International B.V. Sels d'ammonium d'agents chélateurs et leur utilisation dans des applications en champ de pétrole et de gaz naturel
WO2012080297A1 (fr) * 2010-12-17 2012-06-21 Akzo Nobel Chemicals International B.V. Procédé de régulation du fer dans des applications pétrolières et gazières à l'aide d'un agent chélatant
WO2012080298A1 (fr) * 2010-12-17 2012-06-21 Akzo Nobel Chemicals International B.V. Traitement de formations illitiques par utilisation d'un agent de chélation
WO2012089654A1 (fr) * 2010-12-29 2012-07-05 Akzo Nobel Chemicals International B.V. Mélanges hybrides pour applications d'inhibition d'hydrates gazeux
US8227381B2 (en) 2006-07-21 2012-07-24 Akzo Nobel N.V. Low molecular weight graft copolymers for scale control
WO2012171859A1 (fr) * 2011-06-13 2012-12-20 Akzo Nobel Chemicals International B.V. Résistance améliorée à la corrosion par utilisation d'agents de chélation dans un équipement contenant du chrome
EP2651877A2 (fr) * 2010-12-16 2013-10-23 Nalco Company Composition et procédé pour la réduction de l'agglomération d'hydrate
US8674021B2 (en) 2006-07-21 2014-03-18 Akzo Nobel N.V. Sulfonated graft copolymers
US8921478B2 (en) 2008-10-17 2014-12-30 Nalco Company Method of controlling gas hydrates in fluid systems
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EP2651877A4 (fr) * 2010-12-16 2014-08-06 Nalco Co Composition et procédé pour la réduction de l'agglomération d'hydrate
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US10301534B2 (en) 2010-12-17 2019-05-28 Akzo Nobel Chemicals International B.V. Treatment of illitic formations using a chelating agent
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WO2012080298A1 (fr) * 2010-12-17 2012-06-21 Akzo Nobel Chemicals International B.V. Traitement de formations illitiques par utilisation d'un agent de chélation
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US9505707B2 (en) 2010-12-22 2016-11-29 Nalco Company Composition and method for reducing hydrate agglomeration
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