EP3194521A1 - Procédé et agent chimique améliorés pour la réduction de la production d'eau à partir de puits contenant du pétrole et du gaz - Google Patents

Procédé et agent chimique améliorés pour la réduction de la production d'eau à partir de puits contenant du pétrole et du gaz

Info

Publication number
EP3194521A1
EP3194521A1 EP15842152.9A EP15842152A EP3194521A1 EP 3194521 A1 EP3194521 A1 EP 3194521A1 EP 15842152 A EP15842152 A EP 15842152A EP 3194521 A1 EP3194521 A1 EP 3194521A1
Authority
EP
European Patent Office
Prior art keywords
water
chemical substance
core
coating layer
hydrophobic
Prior art date
Legal status (The legal status 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 status listed.)
Withdrawn
Application number
EP15842152.9A
Other languages
German (de)
English (en)
Other versions
EP3194521A4 (fr
Inventor
Lars Kilaas
Heidi Johnsen
Current Assignee (The listed assignees may be inaccurate. Google has not performed a legal analysis and makes no representation or warranty as to the accuracy of the list.)
WELLCEM INNOVATION AS
Original Assignee
WELLCEM INNOVATION AS
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 WELLCEM INNOVATION AS filed Critical WELLCEM INNOVATION AS
Publication of EP3194521A1 publication Critical patent/EP3194521A1/fr
Publication of EP3194521A4 publication Critical patent/EP3194521A4/fr
Withdrawn legal-status Critical Current

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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
    • C09K8/50—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls
    • C09K8/516—Compositions for plastering borehole walls, i.e. compositions for temporary consolidation of borehole walls characterised by their form or by the form of their components, e.g. encapsulated material

Definitions

  • the invention relates to a chemical substance for reducing water production from subterranean zones surrounding oil and gas wells after being inserted into the formation.
  • the invention further relates to a method of reducing water production from subterranean zones surrounding oil and gas wells, wherein the method comprises the step of inserting such chemical substance.
  • the invention also relates to a method of manufacturing such chemical substance.
  • Produced water is thus not only an economic disadvantage for the oil companies but also a significant environmental challenge. In many cases produced water is reinjected to maintain the pressure. This also involves costs. The best technical and economical solution would be to shut off the water selectively in the reservoir, which is the object of the present agent and method.
  • water swellable polymers based on positively or negatively charged (ion active) monomers and polymers based on non-ion active monomers. Some polymers are particulate during injection but are stretched out to linear polymers when swelled in water. Some of these can again have functional groups like P0 4 , which are intended to form some kind of bond (hydrogen bond or ion bond) or adhesion to the surface of the formation. In general it is positive for the ability of the polymer to take up water that it is not strongly cross-linked but able to be converted to a substantially linear polymer when swelled in water. This way many water molecules may be associated to the polymer chain. On the other hand the same property (low degree of cross-linking) is negative for the stability of the polymer both with respect to remaining in position within the formation and with respect to maintaining the desired properties, such as viscosity and general chemical stability with respect to chemical influences from the environment.
  • US 2011/0098377 Al discloses a technology where water production from a subterranean formation is inhibited or controlled by pumping a fluid containing coated compact particles through a wellbore into the formation.
  • the particles have been previously coated with a relative permeability modifier (RPM).
  • RPM relative permeability modifier
  • the RPM coating expands or swells and inhibits and controls the production of water.
  • the "core” particles themselves do not swell. It is only the coating that swells in contact with water.
  • the RPM may be a water hydrolysable polymer having a weight average molecular weight greater than 100,000.
  • the particles may be conventional proppants or gravel.
  • the RPM has the further property that it may deswell when oil returns after that the water has made the particles swell (and block the formation).
  • the problem is that in that scenario both oil and water may be produced simultaneously. The water present in the oil will prevent de-swelling of the coating, and hence the system will continue to block oil production.
  • the particles are hard and sized between 75 ⁇ and 2000 ⁇ , which renders the particles unsuitable for being inserted into the formation, which typically has much smaller pores, often less than 50 ⁇ .
  • US 2010/0132944 Al discloses a method of removing a partial amount of water in a well, comprising deploying a differential filter downhole; and performing a downhole operation.
  • the differential filter comprises a swellable polymer that swells after contacting water such that permeability of the differential filter is reduced by removing said partial amount of water.
  • the swellable polymer is non-soluble in the water and/or hydrocarbon and wherein the swellable polymer comprises at least one selected from the group consisting of poiyacryiic acid, poiyacryiate, poiymethacryiic acid, poly maleic anhydride, polyacrylamide, polyvinyl alcohol, latex, polyamide, polyester, and a copolymer thereof.
  • a disadvantage of the technology described in this document is that water content is reduced, but not completely removed. Furthermore, the described method can reduce the water production in the production wellbore, but is not applicable for blocking the water within the pore structure out in the reservoir/formation.
  • US 6,884,760 Bl discloses a technology, which uses a wellbore fluid comprising a fluid loss additive and a bridging material that are hydrophobic in nature, hydrophobically modified or oil wettable.
  • the wellbore fluid generates an active filter cake that once formed, is impermeable to an aqueous phase, thus reducing fluid loss and ensuring reduced damage to the formation, yet simultaneously is permeable to the back flow of hydrocarbons during a hydrocarbon recovery process.
  • the problem with using filter cakes is that their flow resistance gets worse over time as the filter gets thicker over time, i.e. the efficiency of this technology over time reduces.
  • a further problem with this technology is that its applicability is limited to the wellbore and therefore not very effective. During clean-up processes and restart of wells, a huge amount of well chemicals are specifically used for removing all sorts of filter cakes, and hence there are large risks for simultaneously damage the filter cake disclosed in this document.
  • the invention has for its object to remedy or to reduce at least one of the drawbacks of the prior art, or at least provide a useful alternative to prior art. It is a further object of the invention to provide a technology, which effectively combines the advantages of the various technologies of the prior art discussed before.
  • the invention relates to a chemical substance for reducing water production from subterranean zones surrounding oil and gas wells after being inserted into the formation.
  • the chemical substance comprises a plurality of particles, wherein each particle has a water-swellable core.
  • Each core has been coated with a flexible coating layer which is hydrophobic under all circumstances in the well and which does not swell in the presence of water nor react with water.
  • the flexible coat ing layers from different particles contacting each other have the property of forming an interconnected hydrophobic network (or pathway) of "channels", at least in a swollen condition of the core, for allowing hydrocarbons to go through this hydrophobic network/pathway while simultaneously preventing water (hydrophilic) to go through the "channels".
  • the effects of the combination of the features of the invention are as follows.
  • the cores which swell in the presence of water effectively block the formation after being inserted there into.
  • the particle concentration (weight percentage) may be tailored such that the swollen particles form a "jelly" mass of swollen deformed particles contacting each other while securing completely filling of pore voids.
  • the provision of such described particles having a stable and flexible (covalently linked) hydrophobic coating leads to an in-situ generation of a hydrophobic connected
  • the invention is particularly advantageous, because water and hydrocarbons are often produced simultaneously.
  • the water-swellable core comprises a material, which initially is hydrophobic and convertible to hydrophilic by means of hydrolysis.
  • This embodiment has the advantage that insertion into the formation is rendered much easier, particularly when there is already water produced or present in the formation.
  • the chemical substance in this embodiment comprises a plurality of particles, wherein each particle initially has a water-non- swellable core (hydrophobic), and wherein the property of the core changes into a hydrophilic swellable core.
  • this embodiment of the chemical substance enables placing the system in the formation without early blocking the pores during placement due to the delayed swelling property, i.e. no swelling occurs before the system is set in place and hydrolysis due to well temperature occurs. In this way it is feasible to prevent a filter cake to be built up.
  • the cores in the chemical substance comprises polymer, cross- linked particles which are stable in water-free solvents, wherein a) the particles are manufactured in an oil-in-oil emulsion and are cross-linked with at least one water- stable cross-linker and at least one water-labile cross- linker, the water-labile cross- linker being chosen among cross-linkers able to, when opened in a reaction with water, form a hydrophilic seat which increases the particles' water-swelling ability, and that b) the particles contains a controlled amount of at least one immobilized chemical compound that by means of said reaction between water and reactive groups in the polymer skeleton is able to form a new chemical bonding to another particle, to a nother reactive seat in the same particle, to other immobilized compounds or to other compounds.
  • the cores in this embodiment have the advantageous property of changing from hydrophobic to hydrophilic under hydrolysis.
  • These particles are hydrophobic when produced and squeezed into the formation. When water meets the particles in the pores, a hydrolysis takes place. This hydrolysis is faster when the temperature is increased in the well. That means there is time for squeezing the system into formation before hydrolysis starts.
  • the hydrophobic cores then convert to hydrophilic cores due to the generation of hydrophilic groups like carboxylic acids from anhydrides (hydrophobic) during the hydrolysis.
  • the initial particles are cross-linked with both a stable and labile cross-linker. The water splits the labile cross-linker (anhydride) into two carboxylic acid groups.
  • the stable cross-linker retains the particle "shape" and integrity. Low amount of stable cross-linker leads to higher swelling capacity.
  • the material here described and many examples thereof are well explained in WO 2007/126318 Al .
  • the coating layer comprises oligomeric or polymeric materials as homopolymers or copolymers based on monomers selected from a group comprising : styrene and styrene derivatives, acrylics and acrylic derivatives, methacrylics and methacrylic derivatives, amides and imides, carbonates, dienes, esters, ethers, vinyl acetals, vinyl esters, vinyl ethers and ketones, vinylpyridine and vinylpyrrolidone, fluorocarbons, hydrophobic siloxanes like fluorinated siloxanes, or materials like condensation polymers based on epoxy or urethane resins.
  • monomers selected from a group comprising : styrene and styrene derivatives, acrylics and acrylic derivatives, methacrylics and methacrylic derivatives, amides and imides, carbonates, dienes, esters, ethers, vinyl acetals, vinyl esters, vinyl ethers and ketones, vinylpyridine and vinyl
  • the coating layer comprises styrene and styrene derivatives, e.g. p-tert butylstyrene, 4-(trifluoromethyl)styrene, 2,4-dimethylstyrene, or acrylic and methacrylic derivatives. These materials are easily available and give a tailored hydrophobic effect.
  • the materials and groups of materials in this embodiment of the invention have been shown to provide, after swelling (by hydrolysis) of the core, the effect of forming an interconnected network/pathway from the hydrophobic coating and thus to facilitate the production of hydrocarbons while blocking water production.
  • the core in an unswollen condition of the core, has a size in the range from ⁇ , ⁇ to 75 ⁇ , preferably in the range from ⁇ , ⁇ to ⁇ , and most preferably in the range from ⁇ to 40 ⁇ .
  • the range of core diameters of this embodiment has been proven being a convenient size for insertion into the formation. It must be stressed that the cores do not need to be spherical in the invention, i.e. they may have other shapes. What is important is that the (initial hydrophobic) cores have the property of swelling (after being hydrolysed) in the presence of water at a suitable well temperature, such that water production is blocked as the cores completely block the formation. In case of non-spherical shapes the diameter refers to an average diameter. In a swollen state, the cores may not be spherical, due to deformation and swelling to fill completely the pore voids.
  • the flexible coating layer in an unswollen condition of the core, has a thickness in the range from 10 nm to 600 ⁇ , preferably in the range from 50nm to 200 ⁇ , and most preferably in the range from 200nm to 50 ⁇ .
  • the range of coating layer thickness of this embodiment has been proven being a convenient size for insertion into the formation.
  • the invention relates more particularly to a method of reducing water production from subterranean zones surrounding oil and gas wells, wherein the method comprises the step of inserting the chemical substance according to the invention into the formation of the well.
  • the invention relates more particularly to the method comprising the step of forming the coating layer on the cores during the formation of said water- swellable cores, or after that said water-swellable cores have been formed as a separate post process step.
  • An oil-in-oil emulsion process is a very convenient process to make the chemical substance of the invention.
  • Fig. la shows a chemical substance as known from the prior art when in an un- swollen condition
  • Fig. lb shows the chemical substance of Fig . la when in a swollen condition
  • Fig. 2a shows a chemical substance in accordance with the invention when in an unswollen condition
  • Fig. 2b shows the chemical substance of Fig. 2a when in the swollen condition.
  • Fig. la shows a chemical substance 100 as known from the prior art when in an unswollen condition.
  • This figure shows an earlier developed particle-based system (or substance) as known from the prior art (see patent application publication WO
  • the substance 100 comprises a plurality of particles 110, which have the property of swelling in the presence of water, the water induce hydrolysis of the hydrophobic core to give a hydrophilic swellable core.
  • Such initially unswollen particles 110 are to be injected into the formation of a well where they swell strongly over time when in contact with water in the pores of the formation.
  • Fig. lb shows the chemical substance 100 of Fig. la when in the swollen condition, where it is schematically illustrated that the pore voids (not shown) are hermetically closed by the swollen particles 110'.
  • any oil 10 which may be produced simultaneously with the water, cannot go through this swollen particle gel, i.e. is blocked (as illustrated by the cross) .
  • Fig. 2a shows an improved chemical substance 200 in accordance with the invention when in an unswollen condition.
  • the improved chemical substance 200 comprises a plurality of particles 210, each comprising a water-swellable core 220, which is coated with a flexible coating layer 230.
  • the water-swellable cores 220 may be of the same composition as the particles 110 in Figs, la, but the invention is not limited to such water-swellable cores.
  • the flexible coating layer 230 comprises a material, which is hydrophobic under all circumstances in the well.
  • this layer has the property of forming an interconnected hydrophobic network (not shown) of channels at least in the swollen condition of the core 220, which network of channels facilitates hydrocarbons to go through, while water is blocked (due to the hydrophobic nature of the material).
  • Fig. 2b shows the improved chemical substance 200 of Fig. 2a when in the swollen condition.
  • the cores 220' have swollen, while the coating layers 230' are now stretched and contact each other to block the formation for water production.
  • the hydrophobic network in the coating layer 230' allows for hydrocarbons to go through, thus facilitating hydrocarbon production.
  • the particle core diameter D and the coating layer thickness T in unswollen condition of the cores 220 has been illustrated in Fig. 2a, as well as the particle core diameter D' in a swollen condition of the cores 220'.
  • Chemical agent for reducing water production from subterranean zones surrounding oil and gas wells comprising polymer, cross-linked particles which are stable in water- free solvents, wherein a) the particles are manufactured in an oil-in-oil emulsion and are cross-linked with at least one water-stable cross-linker and at least one water- labile cross-linker, the water-labile cross-linker being chosen among cross-linkers able to, when opened in a reaction with water, form a hydrophilic seat which increases the particles' water-swelling ability, and that b) the particles contains a controlled amount of at least one immobilized chemical compound that by means of said reaction between water and reactive groups in the polymer skeleton is able to form a new chemical bonding to another particle, to another reactive seat in the same particle, to other immobilized compounds or to other compounds.
  • polymer cross-linked particles have a skeleton chosen among functionalized homo and copolymers of methacrylates, acrylates, acrylamides, vinyl alcohols, alginates, chitosan, xanthan, dextrans, gelatine, cellulose, amylose, biopolymers in general, vinyl pyrrolidone, vinyl sulfonates, derivat- ized polyethylene glycols, siloxanes, isocyanates, lactones and epoxides, being functionalized with hydroxyl, vinyl, primary, secondary, tertiary or quaternary amines, carboxylic acids, acryl, methacryl, sulfonic acids, hydroxy succinimides, anhydrides, esters, lactones, azalactones, epoxides or thiols.
  • a skeleton chosen among functionalized homo and copolymers of methacrylates, acrylates, acrylamides, vinyl alcohols, alginates, chito
  • water-labile cross-linker is chosen among compounds having functional groups comprising anhydrides, diesters, diimodo-esters, dihydroxy succinimides and difunctional disulfides.
  • the at least one immobilized compound is chosen among derivatives of phosphonates, borates, reactive polyvinyl alcohols, reactive polysaccarides based on derivatives of gelatine, chitosan, alginat, cell ulose, amylose, dextran, and xanthan; functionalized reactive synthetic polymers of polyethylene glycols, polyacryl amides, polyacrylates, polymethacrylates, polyzwitter ions, peroxides, azo initiators, persulfates, siloxanes or sodium silicates.
  • Chemical agent as described in clause 8, wherein the functionalized, reactive synthetic polymers of polyethylene glycols comprise diepoxy functionalized polyethylene glycols, diamino functionalized polyethylene glycols, dithio functionalized polyethylene glycols or divinyl functionalized polyethylene glycols.
  • the at least one immobilized compound comprises at least one biopolymer with an epoxy group, amino group, thiol group, or free radical polymerizable group such as e.g. vinyl, allyl.
  • Chemical agent as described in clause 1, wherein the at least one immobilized compound is chosen such that it contributes to increased swelling, such as e.g. polymers of 2-acrylamido propanesulfonic acid, chitosan, poly n- acryloyltris(hydroxymethyl) aminomethane (NAT) and amino functionalized gelatine.
  • the at least one immobilized compound is chosen such that it contributes to increased swelling, such as e.g. polymers of 2-acrylamido propanesulfonic acid, chitosan, poly n- acryloyltris(hydroxymethyl) aminomethane (NAT) and amino functionalized gelatine.
  • material that is preferably used for the core relates to a chemical agent in the form of a polymer particle system which is manufactured in an oil-in-oil emulsion.
  • the polymer particles can be manufactured by means of a free radical polymerization process or a step polymerization (often also denoted condensation polymerization).
  • a free radical polymerization process or a step polymerization (often also denoted condensation polymerization).
  • condensation polymerization By using an oil-in-oil emulsion water reactive monomers (mono functional, poly functional) can be used while avoiding contact between particles and water.
  • the desired reactions should only take place subsequent the placement in the subterranean formation and such systems can only be produced in oil-in-oil emulsion systems.
  • the first swelling of the agent in water leads to opening of cross-linking bonds so that hydro- philic seats in the particles become available which again leads to gradually increased rate of swelling of the particles, once initiated.
  • the agent's properties can be further optimized, e.g . to form interparticulate bonds, i.e. bonds between different particles, which also contributes to the stability of the agent in relation to influence imposed in the formation subsequent to the swelling. Said features, characteristics and effects contribute to increased stability with respect to temperature, pressure, back-production, washing-out, as well as chemical (salinity, pH) and mechanical influence.
  • Such immobilized compounds with properties as mentioned can only be included in a water-free environment which is why the manufacture in an oil-in-oil emulsion is imperative.
  • the chemical agent is manufactured in an oil-in-oil emulsion polymerization, i.e an emulsion polymerization free from water. Thereby it is ensured that the agent does not swell prematurely or lead to an early reaction involving solid immobilized compounds, but remains stable until introduced into the formation and contacted by water for the first time.
  • the polymerization can be a free radical polymerization but also a condensation polymerization.
  • the agent can thus be manufactured in a water-free environment in a way with which it allows different chemical compounds to be immobilized thereon, which at a given point in time, in contact with water can contribute to the formation of chemical intra- particulate bonds, interparticulate bonds and bonds between particles and the reservoir formation. Said bonds will contribute to a more stable swollen particle system which maintains the reduced permeability for a long period of time while the system as mentioned becomes more robust in relation to external influence.
  • the invention also relates to a method of injection of the chemical substance into a subterranean zone which reduces the water production from a water permeable zone.
  • a suitable carrier fluid preferable an organic carrier fluid lacking reactive groups like aliphatic or aromatic hydrocarbons or combinations of such together with other hydrophobic, organic solvents which do not comprise thiols, amines or hydroxyl groups.
  • the hydrophobic flexible coating layer 230 of the invention may be manufactured in different ways.
  • a convenient way is to make such layer as a further step in the oil-in- oil emulsion process for making the cores, after that the cores have been formed.
  • this means that a further monomer may be added to the emulsion, which then reacts with the surface of the particles (e.g. grafting) to form the coating layer.
  • the coating layer 230 may be added in a separate post treatment step, for instance in a grafting step or a coating step.
  • Various techniques to apply the coating layer 230 exist and are considered to be well-known to the person skilled in the art.

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  • Life Sciences & Earth Sciences (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Chemical & Material Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Materials Engineering (AREA)
  • Organic Chemistry (AREA)
  • Geology (AREA)
  • Mining & Mineral Resources (AREA)
  • Environmental & Geological Engineering (AREA)
  • Fluid Mechanics (AREA)
  • Physics & Mathematics (AREA)
  • Geochemistry & Mineralogy (AREA)
  • Addition Polymer Or Copolymer, Post-Treatments, Or Chemical Modifications (AREA)
  • Physical Or Chemical Processes And Apparatus (AREA)
  • Treating Waste Gases (AREA)

Abstract

L'invention concerne une substance chimique (200) permettant de réduire la production d'eau à partir de zones souterraines entourant des puits de pétrole et de gaz après son insertion dans la formation, ladite substance chimique (200) comprenant une pluralité de particules (210), chaque particule (210) comportant un noyau (220) pouvant gonfler dans l'eau. Chaque noyau (220) a été revêtu d'une couche de revêtement flexible (230) qui est hydrophobe dans toutes les circonstances dans le puits et qui ne gonfle pas en présence d'eau, ni ne réagit avec l'eau. De plus, les couches de revêtements flexibles de différentes particules, en contact les unes avec les autres, ont la propriété de former un réseau (ou chemin) hydrophobe interrelié de « canaux », au moins dans un état gonflé du noyau, pour permettre aux hydrocarbures de traverser ce réseau/chemin hydrophobe tout en empêchant simultanément l'eau (hydrophile) de traverser les « canaux ».
EP15842152.9A 2014-09-17 2015-09-15 Procédé et agent chimique améliorés pour la réduction de la production d'eau à partir de puits contenant du pétrole et du gaz Withdrawn EP3194521A4 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
NO20141125A NO340788B1 (no) 2014-09-17 2014-09-17 Forbedret fremgangsmåte og kjemisk middel for reduksjon av vannproduksjon fra olje- og gassholdige brønner
PCT/NO2015/050160 WO2016043598A1 (fr) 2014-09-17 2015-09-15 Procédé et agent chimique améliorés pour la réduction de la production d'eau à partir de puits contenant du pétrole et du gaz

Publications (2)

Publication Number Publication Date
EP3194521A1 true EP3194521A1 (fr) 2017-07-26
EP3194521A4 EP3194521A4 (fr) 2018-07-25

Family

ID=55533537

Family Applications (1)

Application Number Title Priority Date Filing Date
EP15842152.9A Withdrawn EP3194521A4 (fr) 2014-09-17 2015-09-15 Procédé et agent chimique améliorés pour la réduction de la production d'eau à partir de puits contenant du pétrole et du gaz

Country Status (3)

Country Link
EP (1) EP3194521A4 (fr)
NO (1) NO340788B1 (fr)
WO (1) WO2016043598A1 (fr)

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EP0755946A3 (fr) * 1995-07-24 1997-10-01 Basf Corp Méthode de préparation de polymères en émulsion rendus hydrophobes, les polymères ainsi obtenus et les compositions aqueuses de revêtement contenant ces polymères
GB2351098B (en) 1999-06-18 2004-02-04 Sofitech Nv Water based wellbore fluids
NO20004109L (no) * 2000-08-16 2002-02-18 Sinvent As Stabilisering av formasjoner
GB0028269D0 (en) * 2000-11-20 2001-01-03 Norske Stats Oljeselskap Well treatment
US20050244641A1 (en) * 2004-04-12 2005-11-03 Carbo Ceramics Inc. Coating and/or treating hydraulic fracturing proppants to improve wettability, proppant lubrication, and/or to reduce damage by fracturing fluids and reservoir fluids
US7819192B2 (en) * 2006-02-10 2010-10-26 Halliburton Energy Services, Inc. Consolidating agent emulsions and associated methods
NO324590B1 (no) * 2006-04-26 2007-11-26 Wellcem Innovation As Fremgangsmate og middel for reduksjon av vannproduksjon fra olje- og gassbronner samt fremgangsmate for fremstilling av slikt middel
US8205673B2 (en) 2006-12-18 2012-06-26 Schlumberger Technology Corporation Differential filters for removing water during oil production
US7897546B2 (en) * 2008-04-21 2011-03-01 Nalco Company Composition and method for recovering hydrocarbon fluids from a subterranean reservoir
US9303502B2 (en) 2009-10-27 2016-04-05 Baker Hughes Incorporated Method of controlling water production through treating particles with RPMS
WO2010105070A1 (fr) * 2009-03-12 2010-09-16 Conocophillips Company Polymère réticulé gonflable
AR076870A1 (es) * 2009-05-15 2011-07-13 Conocophillips Co Composiciones que comprenden particulas polimericas expandibles y metodo para aumentar la recuperacion de fluidos hidrocarbonados en una formacion subterranea
US8393395B2 (en) * 2009-06-03 2013-03-12 Schlumberger Technology Corporation Use of encapsulated chemical during fracturing
RU2621239C2 (ru) * 2012-04-19 2017-06-01 Селф-Саспендинг Проппант Ллс Самосуспендирующиеся проппанты для гидравлического разрыва
US20140187451A1 (en) * 2012-12-29 2014-07-03 Yousef Tamsilian Producing Nanostructure of Polymeric Core-Shell to Intelligent Control solubility of Hidrophilic Polymer during Polymer Flooding Process

Also Published As

Publication number Publication date
NO340788B1 (no) 2017-06-19
EP3194521A4 (fr) 2018-07-25
NO20141125A1 (no) 2016-03-18
WO2016043598A1 (fr) 2016-03-24

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