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WO2000075262A1 - Procede permettant de reduire l'acidite du petrole - Google Patents

Procede permettant de reduire l'acidite du petrole Download PDF

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Publication number
WO2000075262A1
WO2000075262A1 PCT/GB2000/002068 GB0002068W WO0075262A1 WO 2000075262 A1 WO2000075262 A1 WO 2000075262A1 GB 0002068 W GB0002068 W GB 0002068W WO 0075262 A1 WO0075262 A1 WO 0075262A1
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WO
WIPO (PCT)
Prior art keywords
oil
water
crude oil
phase
aqueous phase
Prior art date
Application number
PCT/GB2000/002068
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English (en)
Inventor
Ian Ralph Collins
Simon Neil Duncum
Christopher George Osborne
Original Assignee
Bp Exploration Operating Company Limited
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 Bp Exploration Operating Company Limited filed Critical Bp Exploration Operating Company Limited
Priority to EP00931456A priority Critical patent/EP1194505A1/fr
Priority to AU49406/00A priority patent/AU4940600A/en
Publication of WO2000075262A1 publication Critical patent/WO2000075262A1/fr
Priority to US09/997,239 priority patent/US20020125175A1/en

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Classifications

    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G27/00—Refining of hydrocarbon oils in the absence of hydrogen, by oxidation
    • C10G27/02—Refining of hydrocarbon oils in the absence of hydrogen, by oxidation with halogen or compounds generating halogen; Hypochlorous acid or salts thereof
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G33/00—Dewatering or demulsification of hydrocarbon oils
    • C10G33/04—Dewatering or demulsification of hydrocarbon oils with chemical means
    • C—CHEMISTRY; METALLURGY
    • C10—PETROLEUM, GAS OR COKE INDUSTRIES; TECHNICAL GASES CONTAINING CARBON MONOXIDE; FUELS; LUBRICANTS; PEAT
    • C10G—CRACKING HYDROCARBON OILS; PRODUCTION OF LIQUID HYDROCARBON MIXTURES, e.g. BY DESTRUCTIVE HYDROGENATION, OLIGOMERISATION, POLYMERISATION; RECOVERY OF HYDROCARBON OILS FROM OIL-SHALE, OIL-SAND, OR GASES; REFINING MIXTURES MAINLY CONSISTING OF HYDROCARBONS; REFORMING OF NAPHTHA; MINERAL WAXES
    • C10G53/00—Treatment of hydrocarbon oils, in the absence of hydrogen, by two or more refining processes
    • C10G53/02—Treatment of hydrocarbon oils, in the absence of hydrogen, by two or more refining processes plural serial stages only
    • C10G53/12—Treatment of hydrocarbon oils, in the absence of hydrogen, by two or more refining processes plural serial stages only including at least one alkaline treatment step

Definitions

  • This invention relates to a process for the de-acidifying of crude oil and/or a crude oil distillate.
  • Crude oil and distilled fractions thereof may contain acid impurities such as naphthenic acid.
  • Typical Total Acid Number (TAN) values as measured by ASTM Method D0664, for such acidic oils are in the range of 0.5 to 4 mg KOH g. These acid impurities can cause corrosion problems, particularly in refinery operations where temperatures of 200°C and above are encountered. For this reason, it is desirable to reduce the acidity of crude oils, for example, by reducing the amount of naphthenic acid present.
  • TAN Total Acid Number
  • oil are known.
  • an alkali such as aqueous sodium hydroxide or aqueous potassium hydroxide is contacted with the oil to neutralise any acid present.
  • the reaction produces an aqueous phase comprising water, and alkali metal naphthenate. This aqueous phase has to be removed from the deacidified oil, before the oil can be used or sold.
  • alkali metal naphthenates are chemically similar to soap, and tend to emulsify hydrocarbon and aqueous phases. This emulsion interferes with the efficient separation of the deacidified oil and aqueous phase.
  • the solubility of alkali metal naphthenates in the aqueous phase increases as the concentration of alkali in the aqueous phase decreases.
  • a dilute solution of sodium or potassium hydroxide the tendency of alkali naphthenate to emulsify hydrocarbon phases is reduced. Accordingly, the problem of emulsion formation may be alleviated by using a dilute solution of the aqueous base.
  • EP 0 881 274 endeavours to improve the process of US 4 199 440 by avoiding the formation of a stable emulsion.
  • stable emulsions are formed when bases are added to oil at an oil to base ratio of 1 : 1 or less.
  • oil is added to aqueous base at an oil to base ratio of 1 :3 to 1 : 15.
  • an unstable dispersion of oil in a continuous aqueous base phase is produced. This unstable emulsion is easily broken, allowing the alkali metal naphthenates and aqueous base to be conveniently removed from the oil phase.
  • EP 0 881 274 A problem with EP 0 881 274 is that it requires large volumes of aqueous base to be used. This makes the process relatively uneconomic, particularly when very large volumes of oil require treatment. Thus, it is desirable to reduce the volume of aqueous base required to deacidify a given quantity of oil.
  • WO 97/08270 describes a process in which the volume of aqueous base employed is relatively small.
  • the reference describes a deacidification process in which a Group IA or Group IIA metal oxide, hydroxide or hydroxide hydrate is contacted with crude oil in the presence of from zero to 7 wt % water.
  • a Group I A compound is employed, the process does not require the addition of water.
  • a Group IIA metal compound is employed, a small amount of water must be present to render the base effective for neutralising acid.
  • the treatment produces a treated crude having a reduced acidity. Any solid suspended in the oil after treatment is separated by centrifugation.
  • a demulsifier can be employed to ensure that even in the presence of relatively low concentrations of water, oil can be treated with base to produce at least three separate phases: an oil-rich phase consisting essentially of deacidified oil, an aqueous phase consisting essentially of water, and an interface layer disposed between the oil-rich phase and aqueous phase.
  • the interface layer comprises accumulated solids, such as neutralisation salts. The interface layer is immiscible with both the deacidified oil and water, and is thus easily removed.
  • Group IIA metal hydroxide and water in an amount effective to cause the mixture to separate into an oil-rich phase, an aqueous phase and an interface layer disposed between the oil-rich phase and aqueous phase.
  • Steps a) and b) of the present invention may be carried out at a temperature of 5 to 200°C, preferably 10 to 70°C, most preferably, 20 to 50°C, and especially 30 to 40°C.
  • the crude oil and/or crude oil distillate may be heated using an external or dedicated heat source.
  • the process is carried out without heating the crude oil and/or crude oil distillate.
  • step a crude oil and/or crude oil distillate (hereinafter “oil”) is contacted with Group IIA metal hydroxide in the presence of water, to produce water and neutralisation salts.
  • This contacting step is preferably carried out by adding the hydroxide to the oil, such that a water-in-oil type emulsion is produced.
  • This neutralisation reaction causes the acidity of the oil to be reduced, which enables the treated oil (oil-rich phase) to be used directly, to be exported, to be sold or to be further processed, for example, by fractional distillation.
  • Suitable Group IIA metal hydroxides include barium hydroxide, magnesium hydroxide, and preferably, calcium hydroxide.
  • Group IIA metal hydroxides tend to be relatively insoluble in water (and oil), such that any excess hydroxide remains substantially undissolved in the aqueous phase (and oil-rich phase).
  • the aqueous phase consists essentially of water and is either neutral, or only very mildly alkaline.
  • the concentration of water employed in step a) is 0.01 to 100 wt % of oil.
  • Water is believed to aid the neutralisation reaction by catalysing the transfer of hydrogen ions between the oil and base (Group IIA metal hydroxide).
  • Water is also required for the formation of the aqueous phase and interface layer. For these reasons, water may have to be added to the reaction mixture.
  • Water is also produced during the deacidification reaction, and therefore the water concentration increases during the process of the present invention. For water to be generated in this manner, however, at least some traces of water must be initially present in the reaction mixture of step a).
  • water concentrations of 0.01 to 30, more preferably 0.01 to 25 wt %, even more preferably, 0.1 to 20 wt % of oil, most preferably, 3 to 20 wt %, and especially 10 to 15 wt % of oil are employed.
  • phase transfer agent may also be added to the reaction mixture formed in step a). This phase transfer agent may further catalyse the neutralisation reaction by aiding the transfer of hydrogen ions between the oil and base (Group IIA metal hydroxide).
  • a suitable phase transfer agent is represented by the formula:
  • Y is Cl, Br or I, and preferably, is Br;
  • R 1 is an alkyl group having a carbon number in the range of 10 to 20, preferably, 14 to 18; R 1 is preferably a straight chain alkyl group; and
  • R 2 , R 3 , R 4 are each independently an alkyl group having a carbon number in the range of 1 to 5, preferably, 1 to 4.
  • R 2 , R 3 and R 4 are the same alkyl group.
  • Another suitable phase transfer agent is represented by the formula:
  • R 5 and R 6 are each independently an alkyl group having a carbon number in the range of 10 to 20, preferably, 14 to 18; R 5 and R 6 are preferably straight chain alkyl groups; and
  • R 7 and R 8 are each independently an alkyl group having a carbon number in the range of 1 to 5, preferably, 1 to 4.
  • R 5 and R 6 are the same.
  • R 7 and R 8 are the same.
  • phase transfer agents include cetyltrimethyl ammonium bromide (CTAB), didodecyltrimethyl ammonium bromide, tetrabutyl ammonium bromide (TBAB) and tetrapentyl ammonium bromide.
  • CTAB cetyltrimethyl ammonium bromide
  • TBAB tetrabutyl ammonium bromide
  • Phase transfer agent concentrations 0.01 to 40 wt %, preferably 5 to 20 wt % and most preferably, 5 to 15 wt % based on the weight of Group IIA metal hydroxide are employed.
  • An emulsifier may be also be added to the reaction mixture formed in step a).
  • suitable emulsifiers include sorbitan monooleate, sorbitan monostearate, sorbitan trioleate, sorbitan monopalmitate, sorbitan tristearate, non-ionic block co- polymers, polyoxyethylene stearyl alcohols, polyoxyethylene cocoa amines, fatty amine ethoxylates, polyoxyethylene oleyl alcohols, polyoxyethylene stearyl alcohols, polyoxyethylene cetyl alcohols, fatty acid polyglycol esters, glyceryl stearate, glyceryl oleate, propylene glycol stearate, polyoxyethylene oleates, polyoxyethylene stearates, diethylene glycol stearate, and fatty acid polyamine condensates.
  • the emulsifier is a fatty acid polyalkylene polyamine condensate (preferably those condensates sold under the Trademark Atlox LP6 or Hypermer LP6), a fatty amine ethoxylate (preferably Hypermer "" B246) or sorbitan monooleate.
  • the concentration of emulsifier is less than 5% wt oil, preferably less than 1% wt oil.
  • a mutual solvent for the oil-rich and aqueous phases
  • the mutual solvent may be a non-ionic amphiphilic solvent, such as an alcohol or preferably a polyol, for example, an alkyltriglycol ether.
  • the alkyl group of the alkyltriglycol ether may be straight or branched chain and suitably has 3-6 carbon atoms, preferably 3-5 carbon atoms.
  • the alkyl group in the alkyltrigycol ether more preferably has 4 carbon atoms and is especially n-butyltriglycol ether (also known as triethylene glycol mono-n-butyl ether).
  • glycol ethers include ethylene glycol mono butyl ether and butyl diglycol ether.
  • these non-ionic amphiphilic solvents act to couple oil and water together forming a phase of density intermediate between that of the oil-rich phase and the aqueous phase (hereinafter referred to as "middle phase").
  • the middle phase exhibits low interfacial tension between the oil and water.
  • the middle phase has a large capacity to solubilise, or dissolve, ionic species and thus can extract the naphthenic acids and/or neutralised naphthenic acid salts from the oil phase.
  • the middle phase may partition into the interface layer or may separate into a distinct phase.
  • the mutual solvent is chosen such that the middle phase partitions into the interface layer.
  • a step a) the contacting of the crude oil and/or crude oil distillate (such as gasolene, gas oil, diesel, or kerosene) with the Group IIA metal hydroxide may take place in the presence of an organic diluent such as a C -Ci6 alkane (for example, decane).
  • an organic diluent such as a C -Ci6 alkane (for example, decane).
  • the concentration of the optional organic diluent in step a) is 1 to 100wt% of oil, for example, 3 to 20wt% of oil.
  • the oil is contacted with a slurry comprising a suspension of the Group IIA metal hydroxide in water.
  • the Group IIA metal hydroxide comprises l-20%w, preferably 2-10%w, more preferably, 5- 10%w of the slurry.
  • the slurry contains at least one of the phase transfer agents mentioned above.
  • the slurry contains at least one of the mutual solvents mentioned above.
  • the resulting mixture may be stirred or agitated in a mixing unit.
  • the mixture may be stirred using a mechanical stirrer, an ultrasonic stirrer or by bubbling an inert gas through the reaction mixture.
  • the mixing step may last 2 to 30 minutes, preferably, 5 to 20 minutes and most preferably, 8 to 15 minutes.
  • the mixing step may be carried out at a temperature of 5 to 200°C, preferably 10 to 70°C, most preferably, 20 to 50°C, and especially 30 to 40°C.
  • the mixing is carried out without heating the crude oil and/or crude oil distillate.
  • the reaction mixture may be fed into a coalescer, which may help to agglomerate solid particles in the mixture.
  • This treatment may aid separation of the mixture into an oil-rich phase, aqueous phase and interface layer, when the demulsifier is added in step b).
  • a demulsifier is added to the reaction mixture.
  • the reaction mixture may be allowed to settle, for example, in a settling unit. This causes the reaction mixture to separate into at least three phases: an oil-rich phase, aqueous phase and an interface layer disposed between the aqueous and oil-rich phases.
  • the oil-rich phase may be isolated from the settling unit and used directly, sold or further processed, for example, by fractional distillation.
  • the demulsifier ensures that the water present in the reaction mixture separates from the oil phase. Water is present in the aqueous phase, and is usually also present in the interface layer.
  • the aqueous phase may be recovered and purified, before being recycled back to the contacting step a). Water present in the interface layer may also be recovered, purified and recycled to step a).
  • the demulsifier also ensures that any solids present in the reaction mixture (eg unreacted Group IIA metal hydroxide and/or salt of neutralisation) gather as a layer at the interface of the oil-rich and aqueous phases.
  • This interface layer may be regarded as consisting essentially of an aqueous suspension of the solid product (eg calcium naphthenate) of the neutralisation reaction and any unreacted solid base (eg calcium hydroxide).
  • This layer usually also contains some deacidified oil, for example, in an amount of 1 - 10 wt %, preferably 1 to 5 wt %. Where a mutual solvent is employed, this may preferentially partition into the interface layer.
  • the deacidified oil is recovered from the interface layer, for example, by using a hydrocyclone, electrostatic coalescer and/or, preferably, a centrifuge.
  • the interface layer is allowed to settle for sufficient time to allow the deacidified oil to separate from the aqueous phase.
  • the recovered deacidified oil may be used directly, exported or processed.
  • demulsifier suitable for breaking water-in-oil type emulsions may be employed.
  • the demulsifier comprises at least one surfactant selected from the group consisting of:
  • polyamine salts such as polyester amines, amino methylated poly acrylamide, poly di-methyl amino propyl methacrylamide, poly dimethyl amino ethyl acrylate, poly ethylene imine, poly vinyl pyrrolidone, caprolactam-based polymers and quaternised versions of the above.
  • the molecular weight of the polyamine salt is above 3000;
  • polyethers such as sulfated triglycerides
  • polyethers such as copolymers of ethylene oxide and propylene oxide and the reaction products of such copolymers with diacids, diepoxides, diisocyanates, aldehydes, and diamines.
  • the molecular weight of the polyether is above 2000; and
  • p-alkylphenol-formaldehyde resins and ethylene oxide and/or propylene oxide derivatives thereof are examples of the polyethers thereof.
  • the demulsifier comprises a solution of the surfactant(s) dissolved in a solvent such as monoethylene glycol (MEG), tetraethylene glycol (TEG), butylethylene glycol (BGE), butyldiethylene glycol (BDGE), water, xylene and toluene.
  • a solvent such as monoethylene glycol (MEG), tetraethylene glycol (TEG), butylethylene glycol (BGE), butyldiethylene glycol (BDGE), water, xylene and toluene.
  • Suitable demulsif ⁇ ers may also be prepared by reacting I) an addition product of a phenol and formaldehyde or acetaldehyde, with II) a block polymer containing nitrogen.
  • the mole ratio of I to II is 1 - 20 : 1.
  • Such demulsifiers are described in US 4 474 682.
  • the addition product (I) may be obtained by reacting phenol with formaldehyde or acetaldehyde in a molar ratio of 1 : 1 to 3, preferably 1 : 1.8 to 2.2 at a temperature of 50° to 80°C, in the presence of an alkaline catalyst.
  • the block polymer (II) may be obtained by an addition reaction between ethylene oxide, propylene oxide and ethylenediamine, propylenediamine, polyethylenepolyamines, polypropylenepolyamines or mixtures thereof.
  • 10 to 80 moles, more preferably, 30 to 70 moles, of ethylene oxide and propylene oxide are added, as a statistical average per nitrogen atom.
  • the molar ratio of ethylene oxide to propylene oxide is 1:0.5 to 14, preferably, 1:1 to 8.
  • a preferred demulsifier is ML 3407TM (supplied by Baker Petrolite).
  • the concentration of demulsifier employed in step b) may be 0.01 to 5 wt %, preferably, 0.1 to 2 wt % and especially 0.1 to 0.5 wt % of oil.
  • the water in the aqueous phase and/or interface layer may have formed during the course of, for example, steps a) and/or b). Alternatively or additionally, the water may have been added some time during the deacidification process.
  • the interface layer may represent 1 to 40 vol %, preferably, 5 to 20 vol %, and especially 8 to 11 vol % of the total volume of the reaction mixture.
  • the volume of fluid required to be processed in, for example, a hydrocyclone, electrostatic coalescer and/or centrifuge is relatively small compared to the total volume of the reaction mixture.
  • the interface layer is removed and treated, for example, in a centrifuge, to separate it into a solid layer, an aqueous layer and an oil layer.
  • the oil layer may be recovered, for example, for direct use, export, sale or further processing.
  • Solids recovered from the interface layer include unreacted base (Group IIA metal hydroxide) and neutralisation salts. These solids may be converted into useful feedstocks. For example, some calcium salts of organic acids, can be pyrolysed to produce ketones and calcium carbonates according to the following equation:
  • solids recovered from the interface layer are heated to a temperature of 700 to 900°C, preferably, 750 to 850°C.
  • the process is particularly suitable for producing naphthenic ketones, for example, from calcium naphthenates as described in US 5 550 296.
  • the process of the present invention may be employed to reduce TAN values of oils to 0 to 2 mg KOH/g, preferably, 0.1 to 0.8 mg KOH/g and especially, 0.1 to 0.5 mg KOH/g.
  • the process of the present invention may be carried out on a refinery, or whilst the oil is being transported, for example, in a tanker at sea.
  • Figure 1 is a schematic diagram of an apparatus for carrying an embodiment of the process of the present invention.
  • FIG. 2 shows the area labelled "A" in Figure 1 in greater detail.
  • the apparatus comprises at least one slurry mixing tank 10 (preferably 1-3 slurry mixing tanks), an injection pump 12, a static mixer 14, a series of reaction tanks 16, a coaslecer 18 and a centrifuge 20.
  • the slurry mixing tank 10 is coupled to a supply 22 of calcium hydroxide via a weigh hopper 23.
  • the supply 22 of calcium hydroxide is a bulk storage hopper, preferably 2 bulk storage hoppers.
  • the static mixer 14 is fed with acid crude oil via line 24 and feed pump 25.
  • calcium hydroxide, water and a phase transfer agent for example, CTAB
  • a slurry is formed comprising 5 - 10 % calcium hydroxide by weight of slurry.
  • the neutralisation reaction is initiated when the slurry is contacted with the acidified oil. This occurs when the slurry is added to the acid crude via an injection quill 26.
  • the resulting reaction mixture passes through the static mixer 14, where the mixture is dispersed, and then into the reaction tanks 16, where it has a residence time of between 5 and 20 minutes, The neutralisation reaction predominantly takes place in the reaction tanks 16.
  • calcium hydroxide acts as a base, and reacts with any acid present in the oil to produce a neutralisation salt and water.
  • neutralisation salts include calcium naphthenate. Like calcium hydroxide, this compound is substantially insoluble in water and oil but acts as an emulsifier for the crude oil/slurry mixture. The neutralisation reaction is catalysed by the presence of water.
  • the reaction mixture emerging from the reaction tanks 16, is fed into the coalescer 18.
  • the coalescer 18 comprises a cyclonic coalescer 18a, and a separator coalescer 18b.
  • the cyclonic coalescer promotes the agglomeration of the solid particles prior to entering the separator coalescer 18b.
  • the reaction mixture is allowed to separate, in the presence of a demulsifier, into an oil-rich phase 28, an aqueous phase 30 and an interface or "ragging" layer 32
  • the level of the aqueous phase 30 in the separator coalescer 18b is controlled by means of a level controller 19.
  • the demulsifier may be added to the mixture at point X, Y or both (see Figure 1).
  • the interface layer 32 is disposed between the oil-rich phase 28 and the aqueous phase 30 (see Figure 2).
  • the oil-rich phase 28 consists essentially of deacidified oil. This phase 28 is the least dense of the three phases, and is withdrawn from the separator coalescer 18b via line 34. Once withdrawn, the oil-rich phase 28 is ready for use, export, or further processing, for example, by fractional distillation.
  • the aqueous phase 30 consists essentially of water, and is transferred from the separator coalescer 18b into a water break tank 36 via line 35. Oil contaminated water is withdrawn from the water break tank 36 via line 38 and is passed to a clean-up stage (not shown). Clean water is recycled to the slurry mixing tank 10 via lines 42 and 44 and water recycle pump 46. Fresh water 40 may be added to the tank 36, if required.
  • the interface layer 32 is an aqueous suspension comprising calcium naphthenate and water and some deacidified oil. Other insoluble solids such as unreacted calcium hydroxide may also be present in this phase.
  • This interface layer 32 and optionally a portion of the oil rich phase 28 is introduced into the centrifuge 20, where it is separated into three streams, each consisting essentially of water 48, deacidified oil 50 and solids 52.
  • the rate of withdrawal of the interface layer is controlled so as to achieve a constant loading of insoluble solids in the interface layer 32 of the separator coalescer 18b.
  • the water is recycled back to the slurry mixing tank 10 via the water break tank 36, and the oil is introduced from the centrifuge 20 to the clean oil stream 34 which is withdrawn from the separator coalescer 18b.
  • the solids stream 52 comprises calcium naphthenate and unreacted calcium hydroxide, and can be processed into useful chemical feedstocks, for example, by pyrolysis (not shown).

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  • Chemical & Material Sciences (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Engineering & Computer Science (AREA)
  • Chemical Kinetics & Catalysis (AREA)
  • General Chemical & Material Sciences (AREA)
  • Organic Chemistry (AREA)
  • Production Of Liquid Hydrocarbon Mixture For Refining Petroleum (AREA)
  • Organic Low-Molecular-Weight Compounds And Preparation Thereof (AREA)

Abstract

L'invention concerne un procédé permettant de désacidifier du pétrole brut et/ou un produit de distillation de pétrole brut, qui comprend les étapes suivantes : (a) mise en contact du pétrole brut et/ou du produit de distillation de pétrole brut avec un hydroxyde de métal du groupe IIA en présence d'eau, l'eau ayant une concentration de 0,01 à 100 %, en poids, par rapport au pétrole brut et/ou au produit de distillation de pétrole brut; et (b) introduction dans le mélange de pétrole brut et/ou de produit de distillation de pétrole brut, d'hydroxyde de métal du groupe IIA et d'eau, d'un démulsionneur, en quantité efficace pour induire la séparation du mélange en une phase riche en pétrole, une phase aqueuse, et une couche d'interface entre ces deux phases.
PCT/GB2000/002068 1999-06-02 2000-05-30 Procede permettant de reduire l'acidite du petrole WO2000075262A1 (fr)

Priority Applications (3)

Application Number Priority Date Filing Date Title
EP00931456A EP1194505A1 (fr) 1999-06-02 2000-05-30 Procede permettant de reduire l'acidite du petrole
AU49406/00A AU4940600A (en) 1999-06-02 2000-05-30 Process for reducing the acidity of oil
US09/997,239 US20020125175A1 (en) 1999-06-02 2001-11-30 Process for reducing the acidity of oil

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
GB9912842.3 1999-06-02
GBGB9912842.3A GB9912842D0 (en) 1999-06-02 1999-06-02 Process for reducing the acidity of oil

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EP (1) EP1194505A1 (fr)
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AU (1) AU4940600A (fr)
GB (1) GB9912842D0 (fr)
WO (1) WO2000075262A1 (fr)

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WO2002018519A1 (fr) * 2000-09-01 2002-03-07 Bp Exploration Operating Company Limited Procede de desacidification de petrole brut
WO2014137608A1 (fr) * 2013-03-08 2014-09-12 Exxonmobil Research And Engineering Company Procédé et séparateur utilisables en vue du dessalement des huiles brutes de pétrole avec évacuation de la couche d'émulsion
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US20020125175A1 (en) 2002-09-12

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