WO2018114801A1 - Récupération assistée du pétrole - Google Patents

Récupération assistée du pétrole Download PDF

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Publication number
WO2018114801A1
WO2018114801A1 PCT/EP2017/083308 EP2017083308W WO2018114801A1 WO 2018114801 A1 WO2018114801 A1 WO 2018114801A1 EP 2017083308 W EP2017083308 W EP 2017083308W WO 2018114801 A1 WO2018114801 A1 WO 2018114801A1
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WO
WIPO (PCT)
Prior art keywords
formation
polymer
oil
reducing agent
process according
Prior art date
Application number
PCT/EP2017/083308
Other languages
English (en)
Inventor
Gerardus GLASBERGEN
Carolus Hendricus Theodorus VAN RIJN
Ramez Masoud Azmy NASRALLA
Original Assignee
Shell Internationale Research Maatschappij B.V.
Shell Oil Company
Priority date (The priority date is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the date listed.)
Filing date
Publication date
Application filed by Shell Internationale Research Maatschappij B.V., Shell Oil Company filed Critical Shell Internationale Research Maatschappij B.V.
Publication of WO2018114801A1 publication Critical patent/WO2018114801A1/fr

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Classifications

    • C—CHEMISTRY; METALLURGY
    • C09—DYES; PAINTS; POLISHES; NATURAL RESINS; ADHESIVES; COMPOSITIONS NOT OTHERWISE PROVIDED FOR; APPLICATIONS OF MATERIALS NOT OTHERWISE PROVIDED FOR
    • C09K—MATERIALS FOR MISCELLANEOUS APPLICATIONS, NOT PROVIDED FOR ELSEWHERE
    • C09K8/00—Compositions for drilling of boreholes or wells; Compositions for treating boreholes or wells, e.g. for completion or for remedial operations
    • C09K8/58—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids
    • C09K8/588—Compositions for enhanced recovery methods for obtaining hydrocarbons, i.e. for improving the mobility of the oil, e.g. displacing fluids characterised by the use of specific polymers
    • 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
    • C09K2208/20—Hydrogen sulfide elimination
    • 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
    • C09K8/528—Compositions for preventing, limiting or eliminating depositions, e.g. for cleaning inorganic depositions, e.g. sulfates or carbonates

Definitions

  • the present invention is directed to a process for recovering oil from an oil- bearing formation.
  • One enhanced oil recovery method utilizes aqueous polymer mixtures to flood an oil-bearing formation to increase the amount of oil recovered from the formation.
  • Aqueous dispersion of a polymer is injected into an oil-bearing formation to increase recovery of oil from the formation, either after primary recovery or after a secondary recovery water flood.
  • Such processes are described in GB2220687A,
  • the polymer increases the viscosity of the enhanced oil recovery oil recovery formulation, preferably to the same order of magnitude as the oil in the formation in order to force the mobilized oil through the formation for production by the polymer containing flood.
  • Other benifical effects which may take place are changes in pressure profiles due to the injection of the polymer and crossflow of oil from low into higher permeability parts of the reservoir.
  • a disadvantage of flooding a formation with polymer mixture is that the polymer containing mixtures to be injected tend to have a relatively high viscosity which makes it difficult to inject these into the formation. It has been investigated whether polymers can be made to increase in viscosity after having been injected into the formation. Such polymers are known in the art and have been described in documents such as US20140209304, US8389446 and US7300973. Expansion is generally induced by an increase in temperature in the targeted part of the formation. Polymers of which the viscosity increases after having been injected into a formation, are hereinafter referred to as expandable polymers. A secondary benefit of these expandable polymers is that they are much more resistant to mechanical shear forces.
  • the present invention is directed to a process for recovering oil from an oil-bearing formation by injecting an enhanced oil recovery formulation comprising expandable polymer into the formation which process comprises:
  • the process for oil production comprises injecting into an oil-bearing formation an enhanced oil recovery formulation comprising an adsorption reducing agent.
  • an adsorption reducing agent e.g., adsorption reducing agent
  • expandable polymer tends to adhere less to a formation if adsorption reducing agent was previously injected into the formation.
  • Reduction of adsorption can be due to change in the adsorption capacity of the formation such as in the case of alkali or can be due to other compounds such as sacrifycing agents already having been adsorbed.
  • the process involves the injection of a pre-treating composition comprising the adsorption reducing agent.
  • Pre-treating involves injecting a total amount of adsorption reducing agent composition which is smaller than the total amount of enhanhanced oil recovery formulation injected into the same part of the formation.
  • a suitable amount of pre-treating composition would be of from 0.0001 to 0.2 pore volume of the formation, more specifically at least 0.0005, more specifically at least 0.001, more specifically at least 0.005 pore volume.
  • the pre-treating involves a limited amount of adsorption reducing agent composition such as at most 0.15 pore volume, more specifically at most 0.10 pore volume, more specifically less than 0.10 pore volume.
  • the pore volume is the volume of the relevant part of the formation in so far as the volume is available for the storage of liquid before start of the enhanced oil recovery.
  • the pore volume can be determined in any way known to the person skilled in the art.
  • the process also involves injecting the oil recovery formulation.
  • a suitable amount of oil recovery formulation can be of from 0.1 to 1 pore volume of the formation, more specifically at least 0.11, more specifically at least 0.15, more specifically at least 0.20 pore volume of the formation.
  • the amount of oil recovery formulation is limited to the amount required and preferably is less than 1 pore volume, more preferably less than 0.9 pore volume, more preferably less than 0.8 pore volume of the formation.
  • the adsorption reducing agent is chosen from the group consisting of alkali, polymers including but not limited to expanded expandable polymers, surfactants and scale inhibitors.
  • the polymer preferably is an enhanced oil recovery polymer.
  • the surfactant preferably is an enhanced oil recovery surfactant.
  • the adsorption reducing agent is a sacrifycing agent selected from the group consisting of surfactants and polymers including but not limited to expanded expandable polymers. More preferably, the adsorption reducing agent is a polymer, more specifically an enhanced oil recovery polymer, including but not limited to expanded expandable polymer.
  • the adsorption reducing agent is an organic compound having a weight average molecular weight of at least 100 dalton, more preferably at least 150 dalton, more preferably at least 200 dalton, more preferably at least 300 dalton, more preferably at least 400 dalton, more preferably at least 500 dalton.
  • An organic compound consists of carbon and hydrogen and optionally oxygen and/or sulphur. The deprotonated form of an acid is considered for determining whether either the acid per se or the deprotonated acid is considered organic.
  • Surfactant for use as adsorption reducing agent can be any surfactant known to be suitable by somebody skilled in the art.
  • the surfactant can be cationic, nonionic or anionic.
  • the surfactant will be a nonionic surfactant or an anionic surfactant or a mixture of these.
  • nonionic surfactants are alcohol ethoxylates such as NEODOL 91-8 and NEODOL 2512.
  • NEODOL is a trademark of the Shell group of companies.
  • the anionic surfactant is chosen from the group consisting of hydrocarbon sulphates and hydrocarbon sulphonates wherein the hydrocarbon consists of hydrogen, carbon and optionally oxygen.
  • the surfactant is selected from the group consisting of an alpha olefin sulfonate compound, an internal olefin sulfonate compound, a secondary alkyl sulfonate compound, a branched alkyl benzene sulfonate compound, a propylene oxide sulfate compound, an ethylene oxide sulfate compound, a propylene oxide-ethylene oxide sulfate compound, or a blend thereof.
  • the surfactant preferably contains of from 10 to 30 carbon atoms.
  • Specific surfactants which can be used are ENORDET surfactant J771, ENORDET surfactant Jill 11, ENORDET surfactant J13131, ENORDET surfactant 0352, ENORDET surfactant 0242, ENORDET surfactant 0342, ENORDET surfactant 0332, ENORDET surfactant A771, PETROSTEP surfactant Al, PETROSTEP surfactant A6, PETROSTEP surfactant S 1 , PETROSTEP surfactant
  • PETROSTEP surfactant S-8 PETROSTEP surfactant S-9, PETROSTEP surfactant S-10, PETROSTEP surfactant S-13, STEOL surfactant CS330,
  • ENORDET is a trademark of the Shell group of companies.
  • PETROSTEP and STEOL are trademarks of Stepan Company.
  • Scale inhibitors which can be used as adsorption reducing agent preferably are chosen from the group consisting of phosphates, phosphate esters, phosphoric acids, phosphonates and phosphonic acids.
  • Alkali which can be used as adsorption reducing agent preferably is selected from the group consisting of ammonia, lithium hydroxide, sodium hydroxide, potassium hydroxide, lithium carbonate, sodium carbonate, potassium carbonate, lithium bicarbonate, sodium bicarbonate, potassium bicarbonate, lithium silicate, sodium silicate, potassium silicate, lithium phosphate, sodium phosphate, potassium phosphate, and mixtures thereof. Most preferably, the alkali is sodium hydroxide.
  • the adsorption reducing agent is polymer, more preferably enhanced oil recovery polymer, including but not limited to expanded expandable polymer.
  • the enhanced oil recovery polymer for use as adsorption reducing agent preferably is polyacrylamide, more specifically an at least partially hydrolyzed polyacrylamide.
  • the adsorption reducing agent is selected from the group consisting of polyacrylamide, partially hydrolyzed polyacrylamide, hydrolyzed polyacrylamide and expanded expandable polymer. Expansion of the expandable polymer can be attained in any way known to somebody skilled in the art.
  • the adsorption reducting agent is selected from the group consisting of polyacrylamide, partially hydrolyzed polyacrylamide and hydrolyzed
  • the weight average molecular weight of the adsorption reducing agent preferably is at least the weight average molecular weight of the expandable polymer.
  • the adsorption reducing agent preferably has an anionc charge density which is at least the anionic charge density of the expandable polymer, preferably higher than the anionic charge density of the expandable polymer.
  • the anionic charge density is also sometimes referred to as anionicity and can be determined by
  • Each the adsorption reducing agent and the expandable polymer generally will be injected into the formation as a mixture of water and adsorption reducing agent and expandable polymer, respectively.
  • Pure water can be preferred but pure water is not always available in sufficient quantity.
  • Pure water is considered to be water having a total dissolved solids content (TDS, measured according to ASTM D5907) of at most 4000 ppm, more specifically at most 2000 ppm, more specifically at most 1000 ppm, most specifically at most 500 ppm.
  • TDS total dissolved solids content
  • an alternative preferred embodiment is to apply a combination of pure water and water having a relatively high TDS or use water from other sources such as sea water, brackish water, aquifer water, formation water and brine.
  • Water which can be used with the adsorption reducing agent and/or with the expandable polymer generally has a TDS of more than 1,000 ppm, more specifically at least 2,000 ppm, more specifically at least 4,000 ppm, more specifically at least 5,000 ppm.
  • the water has a TDS of less than 20,000 ppm, more specifically less than 15,000 ppm, more specifically is at most
  • the water used for preparing the aqueous mixture has a reduced ionic strength namely of 0.15 M or less.
  • the water preferably has an ionic strength of at most 0.1 M or at most 0.05 M, or at most 0.01 M, and may have an ionic strength of from 0.01 M to 0.15 M, or from 0.02 M to 0.125 M, or from 0.0 3M to 0.1 M. Ionic strength, as used herein, is defined by the equation
  • c the molar concentration of ion i
  • z the valency of ion i
  • n the number of ions in the measured mixture.
  • the water used for preparing the aqueous mixture contains a limited amount of divalent ions such as less than 4000 ppm, more specifically less than 2000 ppm, more specifically less than 1000 ppm, more specifically less than 500 ppm, more specifically less than 100 ppm, most specifically less than 20 ppm of divalent ions based on total amount of water. More specifically, these amounts relate to the calcium and/or magnesium containing salts.
  • Water of appropriate TDS content can be obtained by reverse osmosis of saline water using a membrane having a first surface and a second surface and (i) feeding the saline source water to the first surface of the membrane, and (ii) removing treated water of reduced salinity from the second surface of the membrane.
  • the expandable polymer is injected subsequent to injection of the adsorption reducing agent. It is preferred that most, and more preferably substantially all, of the formation has been in contact with the adsorption reducing agent before being brough into contact with the expandable polymer. Adsorption reducing agent can still be in a certain part of the formation when injection of the expandable polymer starts into another part of the formation.
  • the expandable polymer generally is intended to provide the oil recovery formulation with a viscosity of the same order of magnitude as the viscosity of oil in the formation under formation temperature conditions to allow the oil recovery formulation to drive mobilized oil across the formation for production from the formation with a minimum of fingering of the oil through the oil recovery formulation and/or fingering of the oil recovery formulation through the oil.
  • the expandable polymer can be a single compound or can be a mixture of compounds.
  • the polymer is selected from the group consisting of polyacrylamide; partially hydrolyzed polyacrylamide; polyacrylate; ethylenic co-polymer;
  • carboxymethylcelloluse polyvinyl alcohol; polystyrene sulfonate;
  • polyvinylpyrrolidone polyvinylpyrrolidone; biopolymers; 2-acrylamide-methyl propane sulfonate (AMPS); styrene-acrylate copolymer; co-polymers of acrylamide, acrylic acid, AMPS and n- vinylpyrrolidone in any ratio; and combinations thereof.
  • ethylenic co-polymers include co-polymers of acrylic acid and acrylamide, acrylic acid and lauryl acrylate, and lauryl acrylate and acrylamide.
  • biopolymers include xanthan gum, guar gum, schizophyllan and scleroglucan.
  • the expandable polymer is polyacrylamide or hydrolyzed polyacrylamide or partly hydrolyzed polyacrylamide.
  • expandable polymers have a particle size after expansion of at 2 least times the particle size before expansion, more specifically at least 5 times, more especially at least 10 times, more specifically at least 20 times, more specifically at least 50 times, most specifically at least 100 times.
  • the particle size is the longest distance across the particle such as its length in case of a fiber or rod shaped particle.
  • expandable polymers are expandable crosslinked polymeric microparticles as described in US20140209304. More specifically, these polymers have an unexpanded volume average particle size diameter of from 0.05 to 10 microns. Expansion of the polymer is caused by differences in conditions between the environment in the formation and outside the formation before injection. The expansion generally will be triggered by an increase in temperature and/or a change in pH.
  • the process of the present invention is especially suitable for use offshore in which case the oil containing formation is located under a layer of water more specifically under the seabed.
  • the concentration of the polymer in the oil recovery formulation to be injected into the formation preferably is sufficient to provide the oil recovery formulation with a dynamic viscosity in the formation of at least 0.3 mPa s (0.3 cP), more specifically at least 1 mPa s (1 cP), or at least 10 mPa s (10 cP), or at least 100 mPa s
  • the concentration of polymer in the oil recovery formulation preferably is from 250 ppm to 10000 ppm, or from 500 ppm to 5000 ppm, or from 1000 to 2000 ppm.
  • the molecular weight number average of the polymer in the oil recovery formulation preferably is at least 10000 dalton, or at least 50000 dalton, or at least 100000 dalton.
  • the polymer preferably has a molecular weight number average of from 10000 to 30000000 dalton, or from 100000 to 15000000 dalton.
  • the oil recovery formulation may also comprise co- solvent with water, where the co-solvent may be a low molecular weight alcohol including, but not limited to, methanol, ethanol, and iso-propanol, isobutyl alcohol, secondary butyl alcohol, n- butyl alcohol, t-butyl alcohol, or a glycol including, but not limited to, ethylene glycol, 1,3-propanediol, 1 ,2-propanediol, diethylene glycol butyl ether, triethylene glycol butyl ether, or a sulfosuccinate including, but not limited to, sodium dihexyl sulfosuccinate.
  • the co-solvent may be a low molecular weight alcohol including, but not limited to, methanol, ethanol, and iso-propanol, isobutyl alcohol, secondary butyl alcohol, n- butyl alcohol, t-butyl alcohol, or a glycol including, but not limited to
  • the co-solvent may be utilized for assisting in prevention of formation of a viscous emulsion. If present, the co-solvent preferably is present in an amount of from 100 ppm to 50000 ppm, or from 500 ppm to 5000 ppm of the total oil recovery formulation. A co-solvent may be absent from the oil recovery formulation.
  • the oil recovery formulation may additionally contain paraffin inhibitor to inhibit the formation of a viscous paraffin-containing emulsion in the mobilized oil by inhibiting the agglomeration of paraffins in the oil.
  • the mobilized oil therefore, may flow more freely through the formation for production relative to mobilized oil in which paraffins enhance the formation of viscous emulsions.
  • the paraffin inhibitor of the oil recovery formulation may be a compound effective to inhibit or suppress formation of a paraffin-containing emulsion.
  • the paraffin inhibitor may be a compound effective to inhibit or suppress agglomeration of paraffins to inhibit or suppress paraffinic wax crystal growth in the oil of the formation upon contact of the oil recovery formulation with the oil in the formation.
  • the paraffin inhibitor may be any commercially available conventional crude oil pour point depressant or flow improver that is dispersible, and preferably soluble, in the fluid of the oil recovery formulation in the presence of the other components of the oil recovery formulation, and that is effective to inhibit or suppress formation of a paraffin-nucleated emulsion in the oil of the formation.
  • the paraffin inhibitor may be selected from the group consisting of alkyl acrylate copolymers, alkyl methacrylate copolymers, alkyl acrylate vinylpyridine copolymers, ethylene vinylacetate copolymers, maleic anhydride ester copolymers, styrene anhydride ester copolymers, branched poly ethylenes, and combinations thereof.
  • paraffin inhibitors that may be used in the oil recovery formulation include HiTEC 5714, HiTEC 5788, and HiTEC 672 available from Afton Chemical Corp; FLOTRON D1330 available from Champion Technologies; and INFINEUM V300 series available from Infineum International.
  • the paraffin inhibitor is present in the oil recovery formulation in an amount effective to inhibit or suppress formation of a viscous paraffin-containing emulsion when the oil recovery formulation is introduced into an oil-bearing formation and contacted with oil in the formation to mobilize the oil, and the mobilized oil is produced from the formation.
  • the paraffin inhibitor may be present in the oil recovery formulation in an amount of from 5 ppm to 5000 ppm, or from 10 ppm to 1000 ppm, or from 15 ppm to 500 ppm, or from 20 ppm to 300 ppm based on total amount of formulation.
  • the oil recovery formulation is introduced into an oil-bearing formation containing oil having a dynamic viscosity under formation conditions (in particular, at temperatures within the temperature range of the formation) of at least 0.1 mPa s (0.1 cP), or at least 0.5 mPa s (0.5 cP), or at least 1 mPa s (1 cP).
  • the oil contained in the oil-bearing formation may have a dynamic viscosity under formation temperature conditions of at most 10,000 mPa s (10,000 cP), more specifically at most 1,000 mPa s (1,000 cP), more specifically at most 500 mPa s (500 cP), more specifically at most 100 mPa s (100 cP), more specifically at most 50 mPa s (50 cP), more specifically at most 20 mPa s (20 cP), most specifically at most 10 mPa s (10 cP).
  • the present process further comprises a process in which a clean up or stimulation treatment precedes the adsorption reduction and enhanced oil recovery process steps (a), (b) and (c).
  • a solution containing 1,000 parts per million by weight (ppm) of expandable polymer was prepared by diluting concentrated expandable polymer solution with synthetic North Sea water having a total dissolved solids contents (TDS) of 35,878 mg/1.
  • the tracer solution contained 20 ppm KI in water.
  • a first test was performed with a Boise outcrop core of 30 cm. Seawater was injected to saturate the core. After injection of 2 pore volumes of tracer solution, the expandable polymer solution was injected in an amount of 5 pore volumes at 30 cm/day and 25 °C. The pressure drop was stable from which as deduced that there are no issues with plugging or injectivity at this temperature and with this concentration of polymer. Comparison of the profile of polymer production to tracer showed a significant delay of produced expandable polymer namely more than 1.5 pore volume. It is estimated that the retention of the expandable polymer is about 285 x 10 6 g expandable polymer/g core.
  • a further test was performed by injecting several pore volumes of tracer solution followed by several pore volumes of a solution containing 1 ,000 ppm of hydrolyzed polyacrylamide polymer followed by brine injection. Thereafter, 2 pore volume of tracer solution was injected to check the production profile after the hydrolyzed polyacrylamide polymer injection. Finally, 1,000 ppm expandable polymer solution was injected at a rate of 30 cm/day at 25 °C.
  • a further test was performed by injecting several pore volumes of tracer solution followed by 0.15 pore volume of a solution containing 1,000 ppm of hydrolyzed polyacrylamide polymer followed by 2 pore volume of 1,000 ppm expandable polymer solution at a rate of 30 cm/day at 25 °C.

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  • Chemical & Material Sciences (AREA)
  • Oil, Petroleum & Natural Gas (AREA)
  • Life Sciences & Earth Sciences (AREA)
  • General Life Sciences & Earth Sciences (AREA)
  • Engineering & Computer Science (AREA)
  • Materials Engineering (AREA)
  • Organic Chemistry (AREA)
  • Solid-Sorbent Or Filter-Aiding Compositions (AREA)

Abstract

La présente invention concerne un procédé de récupération de pétrole contenu dans une formation pétrolifère par injection dans la formation d'une formulation de récupération du pétrole comprenant un polymère expansible, ledit procédé consistant à : (a) injecter dans la formation une composition de prétraitement comprenant un agent de réduction d'adsorption, (b) injecter ensuite dans la formation la formulation de récupération assistée du pétrole, et (c) récupérer le pétrole contenu dans la formation pétrolifère.
PCT/EP2017/083308 2016-12-19 2017-12-18 Récupération assistée du pétrole WO2018114801A1 (fr)

Applications Claiming Priority (2)

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EP16205041.3 2016-12-19
EP16205041 2016-12-19

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WO2018114801A1 true WO2018114801A1 (fr) 2018-06-28

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Citations (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB2220687A (en) 1986-11-05 1990-01-17 Standard Oil Co Method of enhanced oil recovery using a stabilized polymer combination in chemical flood
US7300973B2 (en) 2000-06-14 2007-11-27 Nalco Company Composition for recovering hydrocarbon fluids from a subterranean reservoir
US20120067579A1 (en) 2010-09-20 2012-03-22 S.P.C.M. Sa Process for enhanced oil recovery using the asp technique
US8389446B2 (en) 2009-05-15 2013-03-05 Conocophillips Company Swellable polymers with hydrophobic groups
WO2014041856A1 (fr) 2012-09-13 2014-03-20 電気化学工業株式会社 Composition de caoutchouc, et vulcanisat et article moulé à base de celle-ci
US20140209304A1 (en) 2013-01-31 2014-07-31 Ecolab Usa Inc. Mobility control polymers for enhanced oil recovery
WO2016100103A1 (fr) 2014-12-15 2016-06-23 Shell Oil Company Processus et composition pour inondation de polymère par un tensioactif

Patent Citations (7)

* Cited by examiner, † Cited by third party
Publication number Priority date Publication date Assignee Title
GB2220687A (en) 1986-11-05 1990-01-17 Standard Oil Co Method of enhanced oil recovery using a stabilized polymer combination in chemical flood
US7300973B2 (en) 2000-06-14 2007-11-27 Nalco Company Composition for recovering hydrocarbon fluids from a subterranean reservoir
US8389446B2 (en) 2009-05-15 2013-03-05 Conocophillips Company Swellable polymers with hydrophobic groups
US20120067579A1 (en) 2010-09-20 2012-03-22 S.P.C.M. Sa Process for enhanced oil recovery using the asp technique
WO2014041856A1 (fr) 2012-09-13 2014-03-20 電気化学工業株式会社 Composition de caoutchouc, et vulcanisat et article moulé à base de celle-ci
US20140209304A1 (en) 2013-01-31 2014-07-31 Ecolab Usa Inc. Mobility control polymers for enhanced oil recovery
WO2016100103A1 (fr) 2014-12-15 2016-06-23 Shell Oil Company Processus et composition pour inondation de polymère par un tensioactif

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