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Dokumentenidentifikation EP1373680 24.08.2006
EP-Veröffentlichungsnummer 0001373680
Titel BOHRLOCHBEHANDLUNGSMETHODE
Anmelder Statoil ASA, Stavanger, NO
Erfinder KOTLAR, Statoil ASA, Hans Kristan, N-4035 Stavanger, NO;
SCHILLING, Statoil ASA, Bridgette, N-4035 Stavanger, NO;
SJÖBLOM, Statoil ASA, Johan, N-4035 Stavanger, NO
Vertreter derzeit kein Vertreter bestellt
DE-Aktenzeichen 60213078
Vertragsstaaten AT, BE, CH, CY, DE, DK, ES, FI, FR, GB, GR, IE, IT, LI, LU, MC, NL, PT, SE, TR
Sprache des Dokument EN
EP-Anmeldetag 27.03.2002
EP-Aktenzeichen 027274976
WO-Anmeldetag 27.03.2002
PCT-Aktenzeichen PCT/EP02/03509
WO-Veröffentlichungsnummer 2002079608
WO-Veröffentlichungsdatum 10.10.2002
EP-Offenlegungsdatum 02.01.2004
EP date of grant 12.07.2006
Veröffentlichungstag im Patentblatt 24.08.2006
IPC-Hauptklasse E21B 33/138(2006.01)A, F, I, 20051017, B, H, EP
IPC-Nebenklasse E21B 43/02(2006.01)A, L, I, 20051017, B, H, EP   

Beschreibung[en]

The present invention relates to a method of well treatment of a hydrocarbon well (e.g. to reduce or divert undesired water flow within the matrix surrounding the well bore) and also to a composition for use in such a well treatment method.

During the operation of a hydrocarbon well (i.e. a gas or oil well) various down-hole problems arise such as corrosion of metal fittings, hydrocarbon flow-inhibiting deposition (e.g. of scale, gas clathrates, metal sulphides, waxes, gel polymers, microbial debris, etc.), generation of toxic hydrogen sulphide by sulphate-reducing bacteria, increased water flow into the producer bore, etc.

Thus, for example, where sea water is injected through an injection bore hole into an oil-bearing stratum to drive oil through the formation (i.e. the rock) into the producer well hole, differences in solutes in the injection water and the water already present in the formation can cause metal salts to precipitate as scale so causing gradually increasing clogging of the producer well hole.

Typically this is dealt with by applying a "squeeze" of scale inhibitor chemicals, i.e. chemicals which break down the scale and increase oil or gas flow. This generally involves ceasing hydrocarbon flow, forcing an aqueous solution of the scale inhibitor down the producer bore under pressure to drive the inhibitor solution into the formation, and restarting production. Such treatment generally allows a further six or so months of hydrocarbon flow before a further squeeze is required and each squeeze causes some damage to the formation surrounding the producer bore hole and as a result an increased flow of formation fragments (i.e. rock grains etc.) into the bore.

The producer bore hole in an oil well is generally lined in the hydrocarbon bearing stratum with "gravel packs", sand containing filter elements, which serve to trap formation fragments and it has been proposed to include in such gravel packs ceramic particles coated with or impregnated with well treatment chemicals such as scale inhibitors (see EP-A-656459 and WO 96/27070) or bacteria (see WO 99/36667). Likewise treatment of the formation surrounding the producer well bore hole with well treatment chemicals before hydrocarbon production begins has also been proposed, e.g. in GB-A-2290096 and WO 99/54592.

Various polymeric, oligomeric, inorganic and other particulate carriers for well treatment chemicals are also known, e.g. ion exchange resin particles (see US-A-4787455), acrylamide polymer particles (see EP-A-193369), gelatin capsules (see US-3676363), oligomeric matrices and capsules (see US-A-4986353 and US-A-4986354), ceramic particles (see WO 99/54592, WO 96/27070 and EP-A-656459), and particles of the well treatment chemical itself (see WO 97/45625).

There is a particular problem in that water in the hydrocarbon bearing strata can enter the producer bore and be recovered together with the desired hydrocarbon. Such "produced water" then has to be separated out from the hydrocarbon product, cleaned and returned to the environment. As mentioned above, such water moreover can cause deposits within and corrosion of down-hole equipment causing the flow of hydrocarbon from the well to reduce and occasioning the need for periodic closure and squeeze treatment of the producer bore. These effects naturally have serious implications for the economy and efficiency of operation of hydrocarbon wells, especially offshore wells.

Methods of well treatment to reduce formation permeability in areas of a subterranean formation where water flow is causing problems are known. Thus for example US-A-5048607 describes injection of an oil-in-water emulsion in which the oil phase droplets consist of styrene, divinylbenzene and a free radical polymerization initiator. Such an emulsion produces polystyrene particles by in situ polymerization. EP-A-651131 describes the use of an aqueous solution of a water-soluble acrylic monomer, a cross-linker and a polymerization initiator. Such a solution produces a gel by in-situ polymerization.

The present invention is likewise concerned with administration into the formation surrounding a well bore of an emulsion which is polymerizable to produce polymer particles within the formation. However it has been realized that it is beneficial for the discontinuous phase of the emulsion to contain a non-polymerizable liquid carrier, e.g. such that it contains only a minor proportion of polymerizable monomer; in this way, when the discontinuous phase of the emulsion is miscible with the ambient fluid in the matrix undesirable particle formation is minimized since the emulsion droplets will become diluted. -Moreover the particles produced by the polymerization in the discontinuous phase of the emulsion may serve as reservoirs for well treatment chemicals, e.g. scale inhibitors.

Thus viewed from one aspect the invention provides a method of well treatment comprising introducing into the matrix surrounding a hydrocarbon well bore hole an emulsion the discontinuous phase of which comprises a non-polymerizable, water or oil miscible liquid carrier, a polymerizable monomer and a thermally activated polymerization initiator, said monomer constituting from 2 to 40% wt. of said discontinuous phase.

Viewed from a further aspect the invention provides a well treatment emulsion the discontinuous phase of which comprises a non-polymerizable, water or oil miscible liquid carrier, a polymerizable monomer and a thermally activated polymerization initiator, said monomer constituting from 2 to 40% wt. of said discontinuous phase.

Viewed from a still further aspect the invention also provides the use of an emulsion as hereinbefore described as a hydrocarbon well treatment agent.

The emulsions of or used according to the invention may be either oil-in-water or water-in-oil emulsions, i.e. the continuous phase may be either water- or oil-miscible and the discontinuous phase may be respectively either oil- or water-miscible. In general, oil-in-water emulsions will generally be preferred. However water-in-oil emulsions may for example be used if for some reason it is desired to reduce hydrocarbon flow rate in a hydrocarbon bearing stratum or if it is desired to place reservoirs of water-soluble well treatment chemicals in a zone of a hydrocarbon bearing stratum in advance of arrival of significant quantities of water in that zone.

The terms oil-in-water emulsion and water-in-oil emulsion are used herein to relate to emulsions having a continuous liquid phase and a discontinuous liquid phase, one of which is water-miscible and the other of which is not. Thus while the water-miscible phase will generally be aqueous, it need not be and may for example comprise a solvent or solvent mixture, such as an alcohol which is water-miscible, in place of water.

The emulsions of or used according to the invention will generally contain at least one stabilizer, for example a surfactant (e.g. an amphiphile) or a macromolecule, for example a polysaccharide or polysaccharide derivative, such as a cellulosic ether, e.g. hydroxypropylmethylcellulose. If desired, the emulsions may also contain gums and/or gelling agents as stabilizers. The stabilizer will preferably be used as a minor component of the emulsion, e.g. in quantities sufficient to stabilized the emulsion for the period between production and down hole placement. In general the stabilizer will constitute up to 20% wt. of the continuous phase, e.g. 0.5 to 10% wt., preferably 1 to 5% wt., especially 1.5 to 3% wt. Examples of suitable stabilizer surfactants include the Span and Tween surfactants. Non ionic surfactants such as Berol 06 (available from Akzo Nobel and referred to herein as 10EO since the stabilizer contains 10 ethoxy groups per molecule), HTAB (hexadecyltrimethylammonium bromide), Berol 26 (available from Akzo Nobel) and, especially, Span 80 are particularly preferred.

The term monomer is used herein to refer to the molecular building blocks from which a polymer may be produced. The term thus includes the primary monomer, as well as any branching or non-branching comonomers, or crosslinking agents. In general however non-branching/non-crosslinking monomers will constitute at least 80% wt., preferably at least 90% wt., more preferably at least 95% wt. of the overall monomer.

For the oil-in-water emulsions, the monomer is preferably selected from acrylic, vinylic and styrenic monomers, and co-monomers, cross-linking agents, branching monomers, etc., polymerizable therewith. Examples of appropriate monomers include vinyl aliphatic monomers such as esters of acrylic and methacrylic acids, acrylonitrile, and vinyl aromatic monomers such as styrene and substituted styrenes. Preferred are styrenic monomers, optionally and preferably together with cross-linkers, e.g. with divinyl benzene, and methyl methacrylate optionally and preferably together with cross-linkers such as EGMA (ethyleneglycoldimethacrylate). If desired, one or more of the monomers may be functionalised, e.g. to provide surface acidic or basic groups (e.g. carboxyl or amino functions) on the resulting polymer particles, for example to scavenge metal atoms from water reaching the particles so as to reduce scale formation, to promote particle adhesion to formation surfaces, to promote or hinder particle aggregation, etc. Suitable vinylic monomers include compounds of formula CH2=CR2 where each R independently represents an aliphatic, cyclic hydrocarbyl, or functional group (e.g. containing up to 10 carbons).

For the water-in-oil emulsions, the monomers are preferably acidic vinylic, styrenic or acrylic monomers, e.g. acrylic acid, methacrylic acid, etc. Again a cross-linking agent is preferably included, e.g. Bis (N,N'-methylenebisacrylamide).

The monomer preferably comprises 2 to 30% wt. of the discontinuous phase, more preferably 3 to 20% wt., especially 5 to 15% wt.

Cross-linking monomers, e.g. divinylbenzene and Bis, are preferably used in a weight ratio to the non-crosslinking monomers of up to 1:1, especially 1:100 to 1:2, more especially 1:10 to 1:3.

The discontinuous phase of the emulsion also contains a polymerization initiator, preferably a thermally activated initiator, more preferably one activated at temperatures above 70°C. This initiator will generally be present as from 0.01 to 2% wt. of the discontinuous phase, more preferably 0.02 to 0.2% wt.

Examples of oil soluble initiators include AIBN (2,2'-azobis(2-methylpropionitrile)), and diazo and organic peroxide or peroxyester compounds, especially such compounds containing lipophilic carbon chains, and examples of water-soluble initiators include NH4S2O8, K4S2O8, water-soluble diazo salts and other ionic salts.

It is especially preferred that the discontinuous phase in an oil-in-water emulsion contain: 2 to 30% wt. of a non-cross-linking oil-soluble monomer, more preferably 5 to 8% wt.; 0.5 to 20% wt. of a cross-linking oil-soluble monomer, more preferably 1 to 2% wt.; and 0.04 to 0.15% wt. of a polymerization initiator.

The discontinuous phase of the emulsion may also, if desired, contain well treatment chemicals or precursors therefor. These may be any agents capable of tackling down hole problems, such as corrosion, hydrocarbon flow reduction, or H2S generation. Examples of such agents include scale inhibitors, foamers, corrosion inhibitors, biocides, surfactants, oxygen scavengers,- bacteria etc. Thus for example typical scale inhibitors include inorganic and organic phosphonates (e.g. sodium aminotrismethylenephosphonate), polyaminocarboxylic acids, polyacrylamines, polycarboxylic acids, polysulphonic acids, phosphate esters, inorganic phosphates, polyacrylic acids, inulins (e.g. sodium carboxymethyl inulin), phytic acid and derivatives (especially carboxylic derivatives) thereof, polyaspartates, etc. Examples of preferred well treatment chemicals include: hydrate inhibitors, scale inhibitors, asphaltene inhibitors, wax inhibitors and corrosion inhibitors. Such inhibitors are well known to those working in the field of well treatment. Such chemicals may typically constitute up to 20% wt. of the discontinuous phase, e.g. 2 to 10% wt.

The discontinuous phase of the emulsion also contains a non-polymerizable liquid, e.g. a diluent, carrier or solvent. For oil-in-water emulsions this will typically be a hydrocarbon, e.g. a C4 to C60 hydrocarbon, or a mixture of such hydrocarbons, for example an alkane, a mineral oil, a plant oil or an animal oil. One preferred example is lamp oil. For water-in-oil emulsions, the non-polymerizable liquid will typically be water.

This non-polymerizable liquid may constitute up to about 98% wt. of the discontinuous phase, e.g. 60 to 90% wt.

Thus for example an oil-in-water emulsion might have a discontinuous phase containing 85 to 98% wt. of a saturated liquid hydrocarbon.

By liquid here is meant liquid at the pressures and temperatures encountered down-hole. However the liquids are preferably also in the liquid state at atmospheric pressure and 21°C.

The emulsions of the invention desirably have a droplet size for the discontinuous phase (D(v, 0.5)) of from 1 to 50 µm, preferably 4 to 25 µm. This can be achieved using standard emulsification techniques, e.g. using rotor-stator mixers. In the preparation of the emulsion, however, care may need to be taken to ensure that the discontinuous phase does not experience temperatures above the initiation temperature of the initiator or that it does not exceed such temperatures for long.

The emulsions of the invention are preferably relatively dilute, e.g. to achieve greater stability and retain a greater uniformity of droplet size. Accordingly the discontinuous phase preferably constitutes from 2 to 40% by volume, more preferably 5 to 20% by volume, of the emulsions of invention.

In the method of the invention the emulsion may be placed down hole before and/or after hydrocarbon production (i.e. extraction of oil or gas from the well) has begun. Preferably the emulsion is placed down hole before production has begun, especially in the completion phase of well construction.

The emulsion may be placed within the bore hole (e.g. in the hydrocarbon bearing strata or in rat holes) or more preferably within the surrounding formation (e.g. in fissures or within the rock itself). In the former case, the emulsion may conveniently be impregnated into a tubular filter, e.g. a gravel pack or a filter structure as disclosed in EP-A-656459 or WO 96/27070; in the latter case, the emulsion is preferably positioned by squeezing it down the bore hole.

Where the emulsion is placed within the surrounding formation, the pressure used should be sufficient to cause the dispersed phase droplets to penetrate at least 1m, more preferably at least 1.5m, still more preferably at least 2m, into the formation. If desired, the emulsion may be applied in conjunction with proppant particles (e.g. as described in WO 99/54592) to achieve a penetration of up to about 100m into the formation. Emulsions according to the invention further containing proppant particles form a further aspect of the invention.

While the method of the present invention is particularly suited to treatment of producer well holes (i.e. those from which the hydrocarbon is extracted), it can also be used on other well holes. Thus for example it can be used for water shut off of zones or for treatment of injector well holes.

All documents referred to herein are hereby incorporated by reference.

The invention will now be described further with reference to the following non-limiting Examples.

EXAMPLE 1 Oil-in-water emulsion

Aqueous phase: 10-3M aqueous NaCl solution with added thereto 2% wt. of a nonionic surfactant. Oil phase: 6.5% wt. styrene 1.5% wt. divinylbenzene 0.065% wt. of AIBN ad 100% wt kerosene (Statoil Lamp paraffin)
The oil and aqueous phases were mixed in volume ratios of 1:4 and 1:19 at 20000 rpm using a Bühler homogenizer. Emulsions were prepared using 10EO and HTAB as the surfactant. The 1:4 emulsions were stable for days at 70°C; however 10EO gave longer stability.

EXAMPLE 2 Oil-in-water emulsion

Aqueous phase: 10-3M aqueous NaCl solution with added thereto 2% wt. of a nonionic surfactant. Oil phase: 6.5% wt. methyl methacrylate 1.5% wt. EGMA (ethylene glycol dimethacrylate) 0.065% wt. of AIBN ad 100% wt. kerosene (Statoil Lamp paraffin)

The oil and aqueous phases were mixed in volume ratios of 1:4 and 1:19 at 20000 rpm using a Bühler homogenizer. Emulsions were prepared using 10EO and HTAB as the surfactant. The 1:4 emulsions were stable for days at 70°C. Both surfactants gave comparable stability.

EXAMPLE 3 Test Polymerizations

The compositions of Examples 1 and 2, and equivalent compositions not containing the AIBN initiator, were heated to 70°C for 5 hours and then left overnight. Particle sizes for the resulting polymer particles were then determined using a Malvern Mastersizer. The particles sizes determined are set out in Table 1 below. <u>Table 1</u> Example O/W Ratio Surfactant D(v, 0.1) µm D(v, 0.5) µm D(v, 0.9) µm 1 1:4 10E0 0.57 1.63 5.67 1 1:4 HTAB 0.96 2.08 3.85 1 1:19 10E0 1.19 2.37 5.35 2 1:4 10E0 1.79 6.34 28.77 2 1:4 HTAB 1.19 2.15 3.72 2 1:19 10E0 1.23 2.81 32.96

EXAMPLE 4 Water-in-oil emulsion

Oil phase: Kerosene (Statoil Lamp paraffin) plus 2% wt. surfactant Aqueous phase: 6% wt. acrylic acid 1.5% wt. Bis 0.06% wt. NH4S2O8 ad 100% wt. water

The oil and aqueous phases were mixed in volume ratios of 9:1 and 4:1 at 10000 or 20000 rpm in a Bühler homogenizer. In one case Bis was omitted. Emulsions were prepared using Span 80, Triton N-42 and Berol 26 as surfactants. The emulsions were stable for days at 70°C. Span 80 gave the best results.

EXAMPLE 5 Test polymerizations

The Span 80-containing emulsions of Example 4 were polymerized by heating to 80°C for three hours and leaving overnight at 60°C. Particles sizes were measured as in Example 3 and the results are set out in Table 2 below. <u>Table 2</u> O/W Ratio Shear (rpm) D(v, 0.1) µm D(v, 0.5) µm D(v, 0.9) µm 9:1* 10000 1.55 4.61 15.43 9:1 10000 1.96 12.49 21.85 9:1 20000 1.39 2.53 4.34 4:1 10000 1.27 4.49 10.59 4:1 20000 1.23 2.31 3.99 * Bis omitted

As can be seen, the higher shear rates gave rise to smaller particles.

EXAMPLE 6 Core blocking

In order to demonstrate the ability of the oil-in-water emulsions of the invention to decrease the porosity of the formation (i.e. the surrounding rock), two different core-flooding experiments were carried out. In one, a Bentheimer core was oil-saturated and then at a core temperature of 80°C a water-in-oil emulsion was introduced under pressure; in the second, a Bentheimer core was water-saturated and then at a core temperature of 80°C an oil-in-water emulsion was introduced under pressure. In the first, polymerization of the discontinuous phase would reduce oil permeability, in the second water-permeability. The cores had an initial Kabs of 2.6D indicating a pore throat opening of 25 to 35 µm. Oil permeability was reduced by 15% and water permeability by 34%.


Anspruch[de]
Verfahren zur Bohrlochbehandlung, bei dem man in die ein Kohlenwasserstoff-Bohrloch umgebende Matrix eine Emulsion einbringt, deren diskontinuierliche Phase einen nicht polymerisierbaren, wasser- oder ölmischbaren flüssigen Träger, ein polymerisierbares Monomer und einen thermisch aktivierten Polymerisationsinitiator umfasst, wobei das Monomer 2 bis 40 Gew.-% der diskontinuierlichen Phase ausmacht. Verfahren nach Anspruch 1, wobei die diskontinuierliche Phase sowohl nicht vernetzende als auch vernetzende Monomere enthält. Verfahren nach Anspruch 1 oder 2, wobei die diskontinuierliche Phase ölmischbar ist und die kontinuierliche Phase der Emulsion wässrig ist. Verfahren nach einem der Ansprüche 1 bis 3, wobei die Emulsion außerdem einen Stabilisator enthält. Verfahren nach einem der Ansprüche 1 bis 4, wobei die diskontinuierliche Phase 2 bis 30 Gew.-% eines nicht vernetzenden öllöslichen Monomers, 0,5 bis 20 Gew.-% eines vernetzenden öllöslichen Monomers und 0,04 bis 0,15 Gew.-% eines Polymerisationsinitiators enthält. Verfahren nach einem der Ansprüche 1 bis 5, wobei das Monomer ein styrolisches Monomer ist. Verfahren nach einem der Ansprüche 1 bis 5, wobei das Monomer ein Acryl- oder Vinylmonomer ist. Verfahren nach einem der Ansprüche 1 bis 7, wobei die Tröpfchen der diskontinuierlichen Phase in der Emulsion eine Teilchengröße D (v, 0,5) von 1 bis 50 µm aufweisen. Verfahren nach einem der Ansprüche 1 bis 8, wobei das Bohrloch ein produzierendes Bohrloch ist. Chemische Bohrlochbehandlungsemulsion, deren diskontinuierliche Phase einen nicht polymerisierbaren, wasser- oder ölmischbaren flüssigen Träger, ein polymerisierbares Monomer und einen thermisch aktivierten Polymerisationsinitiator umfasst, wobei das Monomer 2 bis 40 Gew.-% der diskontinuierlichen Phase ausmacht. Emulsion nach Anspruch 10, wobei die diskontinuierliche Phase 85 bis 98 Gew.-% eines gesättigten flüssigen Kohlenwasserstoffs enthält. Emulsion nach Anspruch 10 oder 11, außerdem enthaltend einen Stabilisator. Emulsion nach einem der Ansprüche 10 bis 12, deren diskontinuierliche Phase 2 bis 40 Vol.-% ausmacht. Verwendung einer Emulsion gemäß Definition in Anspruch 10 als Kohlenwasserstoff-Bohrlochbehandlungsmittel.
Anspruch[en]
A method of well treatment comprising introducing into the matrix surrounding a hydrocarbon well bore hole an emulsion the discontinuous phase of which comprises a non-polymerizable, water or oil miscible liquid carrier, a polymerizable monomer and a thermally activated polymerization initiator, said monomer constituting from 2 to 40% wt. of said discontinuous phase. A method as claimed in claim 1 wherein said discontinuous phase contains both non-crosslinking and crosslinking monomers. A method as claimed in either of claims 1 and 2 wherein said discontinuous phase is oil-miscible and wherein the continuous phase of said emulsion is aqueous. A method as claimed in any one of claims 1 to 3 wherein said emulsion further contains a stabilizer. A method as claimed in any one of claims 1 to 4 wherein said discontinuous phase contains 2 to 30% wt. of a non-crosslinking oil-soluble monomer, 0.5 to 20% wt. of a crosslinking oil soluble monomer, and 0.04 to 0.15% wt. of a polymerization initiator. A method as claimed in any one of claims 1 to 5 wherein said monomer is a styrenic monomer. A method as claimed in any one of claims 1 to 5 wherein said monomer is an acrylic or vinyl monomer. A method as claimed in any one of claims 1 to 7 wherein the droplets of the discontinuous phase in said emulsion have a particle size D(v, 0.5) of from 1 to 50 µm. A method as claimed in any one of claims 1 to 8 wherein said bore hole is a producer hole. A well treatment chemical emulsion the discontinuous phase of which comprises a non-polymerizable, water or oil miscible liquid carrier, a polymerizable monomer and a thermally activated polymerization initiator, said monomer constituting from 2 to 40% wt. of said discontinuous phase. An emulsion as claimed in claim 10 wherein said discontinuous phase contains 85 to 98% wt. of a saturated liquid hydrocarbon. An emulsion as claimed in either of claims 10 and 11 further containing a stabilizer. An emulsion as claimed in any one of claims 10 to 12 whereof said discontinuous phase constitutes 2 to 40% by volume. The use of an emulsion as defined in claim 10 as a hydrocarbon well treatment agent.
Anspruch[fr]
Procédé de traitement de puits, comprenant l'introduction dans la matrice entourant un puits de forage d'hydrocarbures d'une émulsion dont la phase discontinue comprend un véhicule liquide non polymérisable miscible à l'eau ou à l'huile, un monomère polymérisable et un amorceur de polymérisation activé thermiquement, ledit monomère constituant de 2 à 40% en poids de ladite phase discontinue. Procédé selon la revendication 1, dans lequel ladite phase discontinue contient des monomères à la fois non réticulants et réticulants. Procédé selon l'une quelconque des revendications 1 et 2, dans lequel ladite phase discontinue est miscible à l'huile et dans lequel la phase continue de ladite émulsion est aqueuse. Procédé selon l'une quelconque des revendications 1 à 3, dans lequel ladite émulsion contient en plus un agent stabilisant. Procédé selon l'une quelconque des revendications 1 à 4, dans lequel ladite phase discontinue contient de 2 à 30% en poids d'un monomère non réticulant soluble dans l'huile, de 0,5 à 20% en poids d'un monomère réticulant soluble dans l'huile et de 0,04 à 0,15% en poids d'un amorceur de polymérisation. Procédé selon l'une quelconque des revendications 1 à 5, dans lequel ledit monomère est un monomère styrénique. Procédé selon l'une quelconque des revendications 1 à 5, dans lequel ledit monomère est un monomère acrylique ou vinylique. Procédé selon l'une quelconque des revendications 1 à 7, dans lequel les gouttelettes de la phase discontinue dans ladite émulsion ont une taille de particules D(v, 0,5) dans la plage de 1 à 50 µm. Procédé selon l'une quelconque des revendications 1 à 8, dans lequel ledit forage est un forage de production. Emulsion de produit chimique de traitement de puits dont la phase discontinue comprend un véhicule liquide non polymérisable miscible à l'eau ou à l'huile, un monomère polymérisable et un amorceur de polymérisation activé thermiquement, ledit monomère constituant de 2 à 40% en poids de ladite phase discontinue. Emulsion selon la revendication 10, dans laquelle ladite phase discontinue contient de 85 à 98% en poids d'un hydrocarbure liquide saturé. Emulsion selon l'une quelconque des revendications 10 et 11, contenant en plus un agent stabilisant. Emulsion selon l'une quelconque des revendications 10 à 12, dont ladite phase discontinue constitue de 2 à 40% en volume. Utilisation d'une émulsion telle que définie dans la revendication 10 comme agent de traitement de puits d'hydrocarbures.






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