WO2024125751A1 - Procédé d'extraction de pétrole - Google Patents

Procédé d'extraction de pétrole Download PDF

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WO2024125751A1
WO2024125751A1 PCT/EA2023/050009 EA2023050009W WO2024125751A1 WO 2024125751 A1 WO2024125751 A1 WO 2024125751A1 EA 2023050009 W EA2023050009 W EA 2023050009W WO 2024125751 A1 WO2024125751 A1 WO 2024125751A1
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slug
formation
surfactant
oil
polymer
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PCT/EA2023/050009
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English (en)
Russian (ru)
Inventor
Михаил Юрьевич БОНДАРЬ
Игорь Николаевич КОЛЬЦОВ
Андрей Валерьевич ОСИПОВ
Сергей Васильевич МИЛЬЧАКОВ
Андрей Андреевич ГРОМАН
Георгий Юрьевич ЩЕРБАКОВ
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Общество с ограниченной ответственностью "Газпромнефть-Технологические партнерства" (ООО "Газпромнефть-Технологические партнерства")
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Priority claimed from EA202293304 external-priority patent/EA044722B1/ru
Application filed by Общество с ограниченной ответственностью "Газпромнефть-Технологические партнерства" (ООО "Газпромнефть-Технологические партнерства") filed Critical Общество с ограниченной ответственностью "Газпромнефть-Технологические партнерства" (ООО "Газпромнефть-Технологические партнерства")
Publication of WO2024125751A1 publication Critical patent/WO2024125751A1/fr

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  • the invention relates to the oil production industry, in particular, to methods of oil production using tertiary methods, namely, to chemical methods for increasing oil recovery, and can be used to produce residual oil in fields at the third and fourth stages of development.
  • CMOR enhanced oil recovery
  • a preliminary slug (pre-skin) into the formation in front of the main slug, which is a solution of a surfactant-polymer composition.
  • a method for developing oil deposits is known from the prior art (RF Patent No. 2592005, published July 20, 2016), which involves pumping into the formation through an injection well a composition in the form of an aqueous solution of a surfactant, an alkaline agent (inorganic alkali) and a polymer.
  • a slug of low-mineralized water is preliminarily pumped into the injection well, and the volume of this slug is calculated depending on the initial salinity of water in the formation.
  • the mentioned composition is pumped in, in which nonionic and anionic surfactants are used as surfactants, then a slug of a polymer solution with a viscosity equal to the viscosity of reservoir oil is pumped in an amount from 0.3 to 0.6 pore volumes, after which they switch to conventional flooding.
  • a significant drawback of the known technical solution is the composition of the slug, which is low-mineralized water, which is pumped when implementing the method in front of the composition slug in the form of a solution of a surfactant, an alkaline agent and a polymer, since the injection of this slug leads to swelling of the clays, after which the contact area of the surfactant and charged substances increases clay particles, which ultimately leads to an increase in the adsorption of surfactants and, accordingly, to their high losses.
  • low-mineralized water as a preliminary slug leads to accelerated clogging of the formation, loss of injectivity, and a decrease in the coverage of the formation by chemical flooding, since the initial salinity of the formation water is the highest compared to the injected low-mineralized water.
  • the listed undesirable effects that appear due to the use of low-mineralized water in front of the composition rim in the form of a solution of a surfactant, an alkaline agent and a polymer lead to a decrease in the efficiency of oil production, in particular, to a decrease in sweep and displacement coefficients.
  • a significant disadvantage of the known method is the high losses of surfactants caused by the injection of a polymer solution (PAA) as a preliminary slug, during which a redistribution of flows occurs, the so-called leveling of the injectivity profile, which allows reducing the losses of subsequently injected reagents, in particular surfactants, only in highly permeable and washed channels, while due to the large size of the polymer molecules (PAA), adsorption in low-permeability channels is not fully inhibited.
  • PAA polymer solution
  • the polymer when adsorbed, can partially reduce the adsorption of surfactants, but only with a significant volume of the rim, while shielding residual oil in pinched pores and pore traps, and the polymer adsorbed on the rock does not allow the surfactant to mobilize residual oil, which ultimately leads to low displacement coefficient (K out ).
  • this method is characterized by low efficiency of oil production during surfactant-polymer flooding.
  • a significant disadvantage of the method is the use of non-surfactants in surfactant-polymer rims, which does not allow to significantly reduce the interfacial tension when implementing the method, which also leads to a low displacement coefficient (K ext ).
  • a common disadvantage of the technical solutions described above is the high losses of surfactants when implementing the surfactant-polymer flooding method, due to the unreasonable composition and volume of the slug injected into the formation in front of the main slug.
  • a common disadvantage of the above methods, in which inorganic alkali is used at different stages of oil production, is the need for additional water preparation for its softening (removal of hardness cations) and stabilization.
  • intensive salt deposition occurs inside the surface equipment, pipelines, bottomhole formation zone and interwell space, including due to geological heterogeneity along the lateral and section, which leads to a decrease in injectivity , failure of submersible pumps, including electric centrifugal pumps, and an increase in the frequency of well repairs.
  • the objective of the present invention is to create a method of oil production that ensures the effective involvement of residual oil reserves into development with reduced surfactant consumption.
  • the technical result of the invention is to increase the efficiency of using surfactants during surfactant-polymer flooding of the formation, which is expressed in the form of additional oil production per unit mass of the surfactant injected into the formation, and to reduce non-target losses of the surfactant.
  • the injection well and at least one production well are in hydrodynamic communication.
  • the injection well and at least one production well may be located in the same area of the field.
  • oil production can be carried out through at least one production well adjacent to the injection well.
  • the first rim can be prepared by mixing a surfactant and organic alkali with a pre-prepared polymer solution.
  • the polymer content in the first fringe can be set in the range from 0.05 to 0.25 wt.% of the total mass of the first fringe.
  • sodium lignosulfonate can be used as a surfactant in the first slug.
  • monoethanolamine, diethanolamine or triethanolamine can be used as an organic alkali in the first slug.
  • the second slug can be injected into the formation in an amount from 0.3 to 0.5 parts of the pore volume.
  • the third slug can be injected into the formation in an amount from 0.5 to 1 fraction of the pore volume.
  • the first fringe (pre-fringe) is pumped into the formation in an amount from 0.05 to 0.2 parts of the pore volume, which is a polymer solution with an adsorption inhibitor, for which a mixture of surfactants is used in an amount of 0. 25 to 0.5 wt. % of the total mass of the first slug and organic alkali in an amount from 0.25 to 2 wt. % of the total mass of the first slug.
  • the first slug is pumped into the formation in order to prepare the bottom-hole zone and inter-well space, passivate the formation rock, shield the rock clays, which subsequently leads to a decrease in the adsorption of reagents, in particular surfactants, when injecting the second (main) slug, which is a solution of a surfactant-polymer composition.
  • the polymer solution in the first slug simultaneously serves as a viscosity modifier, allowing uniform injection of an adsorption inhibitor, which is a mixture of surfactants and organic alkali, and evenly distributing their flows, and is also an agent for leveling the injectivity profile, reducing the volume of injection of subsequent reagents into flushed and highly permeable channels.
  • an adsorption inhibitor which is a mixture of surfactants and organic alkali
  • Any water-soluble high-molecular substance known from the prior art that can equalize the mobility coefficients of oil and the aqueous phase and increase the viscosity of water can be used as a polymer in the first rim, including: polyacrylamides or partially hydrolyzed polyacrylamides or copolymers of acrylamide, acrylic acid, 2-acrylamidomethylpropanesulfonates and n-vinylpyrrolidone in any ratio, polyacrylates, ethylene copolymers, biopolymers, carboxymethylcellulose, polyvinyl alcohols and others.
  • a partially hydrolyzed polyacrylamide in particular a copolymer of tert-butylsulfonic acid acrylamide with a molecular weight of 6-8 MDa, a degree of hydrolysis of 20-38% and a sulfonic acid content of 5-10 wt, can be used as a polymer solution in the first rim. %.
  • the polymer content in the first slug varies from 0.05 to 0.25 wt.% of the total mass of the slug, which is explained by the achievement of a sufficient level of viscosity to equalize the mobility coefficients of oil and aqueous phase, which, in turn, further enhances the achievement of the technical result.
  • An adsorption inhibitor which is a mixture of a surfactant and an organic alkali, in the context of the present invention should be understood as a mixture of substances with surfactant properties and substances with basic or alkaline properties.
  • the adsorption inhibitor due to the adsorption inhibitor, preliminary inactivation of adsorption points is ensured before the introduction of the second (main) slug, which is a solution of a surfactant-polymer composition.
  • the use of an adsorption inhibitor as part of the first slug (pre-skin) is important to achieve the stated technical result.
  • the content of the adsorption inhibitor in the first slug can vary from 0.5 to 2.5 wt.%, which is explained by a sufficient increase in the pH relative to the formation water and a sufficient surfactant content to passivate the rock away from the bottomhole zone of the formation.
  • a distinctive feature of the proposed method is that a mixture of surfactant and organic alkali is used as an adsorption inhibitor in the first slug, which allows for preliminary inactivation of adsorption points before introducing the second (main) slug.
  • a mixture of surfactants in an amount of 0.25 to 0.5 wt. can be used as an adsorption inhibitor. % of the total mass of the first slug and organic alkali in an amount from 0.25 to 2 wt. % of the total mass of the first slug. This is due to the fact that with such a combination, the required pH level and sufficient surfactant concentration are achieved for their adsorption on the rock, which, in turn, further enhances the achievement of the technical result. When the surfactant content is less than 0.25 wt. % of the total mass of the first slug and organic alkali is less than 0.25 wt.
  • sodium lignosulfonate is used as a surfactant in the first slug, which, in turn, also ensures the achievement of the technical result. This is explained by the fact that sodium lignosulfonate is, on the one hand, a substance with pronounced surface-active properties, on the other hand, its molecules are large enough to inactivate the active centers of the formation rock.
  • Formation waters of oil fields contain hardness cations, such as calcium, barium, strontium and magnesium, as well as bicarbonate and carbonate anions, and when mixed with such formation water, aqueous solutions containing an excess of inorganic alkali, for example, sodium carbonate or its hydroxide, there is an increase in the pH value, a decrease in water stability, precipitation first of calcium carbonates, then, with an increase in pH, magnesium hydroxides and other insoluble salts and compounds of hardness cations, which leads to intense salt deposition inside surface equipment, pipelines, the bottomhole zone of the formation and interwell space.
  • hardness cations such as calcium, barium, strontium and magnesium, as well as bicarbonate and carbonate anions
  • organic alkali is used in the composition of the first slug, so, in one embodiment of the invention, ethanolamines are used as organic alkalis, in particular monoethanolamine or diethanolamine or triethanolamine, which is explained by the fact that monoethanolamine or diethanolamine or triethanolamine are highly soluble organic substances with basic properties, which, in turn, further enhances the achievement of the technical result.
  • organic alkalis monoethanolamine or diethanolamine or triethanolamine in the first slug does not imply an increase in the pH value, which, in turn, results in intense precipitation of salts or a decrease in water stability.
  • the volume of the first fringe can be from 0.05 to 0.2 parts of the pore volume, which, in turn, also ensures the achievement of the technical result.
  • the given volume is due to the fact that the first slug should have a smaller volume than the second (main) slug, since the mobilization of residual oil occurs precisely by injecting the second (main) slug, which is a solution of a surfactant-polymer composition.
  • the volume of the first slug is less than 0.05 of the pore volume, sufficient propagation of such a slug from the injection well deep into the interwell space is not ensured, and injection of more than 0.2 of the pore volume is not advisable.
  • the corresponding surfactant and organic alkali are mixed with a pre-prepared polymer solution.
  • the importance of correct preparation of the first slug is due to the fact that when preparing a polymer solution in water that already contains a surfactant, intense foaming occurs during mixing, which can lead to the failure of mixing and other equipment, and will also lead to difficulty injecting the first slug into the formation.
  • a second slug which is a solution of a surfactant-polymer composition
  • the second slug is injected into the formation in order to mobilize residual oil and transport it from the injection well to the production well, while the surfactant mixture mobilizes the residual oil, washing it from the walls of pores and channels, including in pinched pores and trap pores. Oil mobilization occurs due to a decrease in interfacial tension at the interface between water and oil, so the surfactant mixture is selected based on the ability to achieve the required value.
  • An individual anionic surfactant or a mixture of anionic and nonionic surfactants which are sulfonates, sulfates, carboxylates, phosphates of compounds based on alpha-olefins, internal olefins, benzenesulfonate compounds with a branched alkyl chain, can be used as an anionic surfactant in the second rim.
  • the content of the surfactant mixture in the second slug can vary from 0.3 to 1 wt.%. In one of the variants of using the method, the content of anionic surfactant is 0.5 wt.%, since at this concentration the optimal interfacial tension and solubilization coefficient are achieved.
  • a solution of a surfactant-polymer composition containing a mixture of a nonionic surfactant, an anionic surfactant, and a cosolvent in a concentration of 0.3 to 0.6 wt. can be used as a second rim. % based on the active substance, and partially hydrolyzed polyacrylamide.
  • the co-solvent in the composition of the second rim acts as an agent that increases the solubility and stability of the surfactant mixture; in particular, it lowers the freezing point of the surfactant mixture.
  • Ethanol, butanol, isobutanol and propanol, as well as their derivatives, can be used as a co-solvent according to the invention.
  • Partially hydrolyzed polyacrylamide in the second slug acts as a viscosity modifier and an agent that equalizes the mobility of oil and the injected aqueous solution. It can be represented by partially hydrolyzed sulfonated polyacrylamide with a molecular weight of 6-8 MDa, a degree of hydrolysis of 20-38% and a sulfonic acid content of 5-10 wt. %, with a concentration of 0.15 wt.%. The content of partially hydrolyzed polyacrylamide in the second slug can vary from 0.05 to 0.25%.
  • the second slug is injected into the formation in an amount of 0.3 to 0.5 percent of the pore volume, which is sufficient volume to mobilize residual oil in the formation.
  • a third slug which is a polymer solution, is pumped into the formation through the same injection well.
  • the third slug is injected into the formation for the purpose of efficient transport of the first (preliminary) and second (main) slugs and their uniform advancement from the injection well to the production well, which are in hydrodynamic communication.
  • the volume of the third slug that is injected into the formation may be from 0.5 to 1 fraction of the pore volume. The specified volume is sufficient for efficient transport of the first slug and the second slug towards the production well.
  • Any water-soluble high-molecular substance known from the prior art can be used as a polymer in the third rim, including: polyacrylamides or partially hydrolyzed polyacrylamides or copolymers of acrylamide, acrylic acid, 2-acrylamidomethylpropanesulfonates and n-vinylpyrrolidone in any ratio, polyacrylates, ethylene copolymers, biopolymers, carboxymethylcelluloses, polyvinyl alcohols and others.
  • a partially hydrolyzed polyacrylamide in particular a copolymer of tert-butylsulfonic acid acrylamide with a molecular weight of 6-8 MDa, a degree of hydrolysis of 20-38% and a sulfonic acid content of 5-10 wt, can be used as a polymer solution in the third rim. %.
  • the content of partially hydrolyzed polyacrylamide in the third rim can vary from 0.05 wt.% to 0.25 wt. %.
  • water is pumped into the formation through the same injection well and then oil is produced through at least one production well, and the duration of production is determined depending on the profitability of the well.
  • formation water or water from the reservoir pressure maintenance system can be used. Water injection ensures transport of previously injected slugs and their uniform advancement from the injection well to the production well.
  • the volume of injected water is regulated by the geological and physical characteristics of the formation of a particular field and the need for additional displacement of oil and pre-injected rims.
  • three slugs of a given composition and water are sequentially injected into the formation through an injection well, after which oil is produced through one or more production wells.
  • injection of slugs and water into the formation can be carried out both in a continuous mode and with maintenance of technological pauses.
  • Example 1 Simulation of the method of oil production according to the proposed invention in laboratory conditions.
  • the proposed method was tested on a bulk reservoir model prepared from crushed core material taken from the Kholmogory field, characterized by the following set of geological and physical characteristics: the oil content of the field is associated with chalk deposits, the initial oil reserves are 70 million tons, the target terrigenous object located on the fourth development phase, lies at a depth of 2432 m, the type of deposit of the field is strata-vault, the type of reservoir corresponds to terrigenous.
  • the first slug was pumped into the bulk model in the amount of 0.2 parts of the pore volume, which is a polymer solution with an adsorption inhibitor, which was used as a mixture of surfactants, in particular, sodium lignosulfonate, in an amount of 0.25 wt. % of the total mass of the first slug and organic alkali, in particular monoethanolamine, in an amount of 0.25% of the total mass of the first slug.
  • the polymer used was partially hydrolyzed polyacrylamide, in particular a copolymer of tert-butylsulfonic acid acrylamide with a molecular weight of 6-8 MDa, a degree of hydrolysis of 20-38% and a sulfonic acid content of 5-10 wt%.
  • the polymer content in the first slug was 0.25 wt.% of the total mass of the first slug.
  • the first slug was prepared by mixing sodium lignosulfonate and monoethanolamine with a pre-prepared polymer solution of partially hydrolyzed sulfonated polyacrylamide.
  • the second rim was pumped into the bulk reservoir model, which was a solution of a surfactant-polymer composition containing a mixture of a nonionic surfactant in an amount of 0.3 wt.%, an anionic surfactant, in particular a mixture of sodium alkylbenzene sulfonates and sodium salts of alpha olefin sulfonates, in an amount of 0.5 wt.%, co-solvent, in particular 2-(2-butoxyethoxy)-ethanol, in an amount of 0.3 wt. % in terms of active substance and 0.15 wt.
  • a surfactant-polymer composition containing a mixture of a nonionic surfactant in an amount of 0.3 wt.%, an anionic surfactant, in particular a mixture of sodium alkylbenzene sulfonates and sodium salts of alpha olefin sulfonates, in an amount of 0.5 wt.%, co-solvent
  • a third slug which is a polymer solution
  • a third slug was pumped into the bulk reservoir model, in particular a solution of partially hydrolyzed sulfonated polyacrylamide with a molecular weight of 6-8 MDa, a degree of hydrolysis of 20-38% and a sulfonic acid content of 5-10 wt. .%.
  • the polymer content in the third rim was 0.25 wt. % of the total mass of the selvedge.
  • the size of the third rim was 1 fraction of the pore volume.
  • water was pumped into the bulk model for filtration in order to simulate the process of oil displacement (oil production) in field conditions. Filtration was carried out at a constant filtration rate of 250 ⁇ l/min, with an injection volume of 3.0 units. pore volume. After that, oil was sampled from the bulk reservoir model through core material and the amount of oil at the outlet and the concentration of surfactants from the second slug in the resulting filtrate were measured.
  • a comparative experiment was also presented, the conditions of which coincided with the conditions described above.
  • the difference was in the composition of the first rim, namely, a polymer solution was used as the first rim, in particular, partially hydrolyzed sulfonated polyacrylamide with a molecular weight of 6-8 MDa, a degree of hydrolysis of 20-38% and a sulfonic acid content of 5-10 wt.%.
  • oil was withdrawn from the bulk reservoir model through core material. Measurements were made of the amount of oil at the outlet and the concentration of surfactants from the second slug in the resulting filtrate. The results obtained were used to construct a graph reflecting the dependence of the ratio of the concentration of the extracted surfactant from the second slug to its initial concentration on the pumped volume of the slugs ( , curve 1).
  • Example 2 Testing of the method according to the invention in field conditions at the Kholmogory field, characterized by a set of geological and physical characteristics described above.
  • the first slug was injected into the formation through an injection well in the amount of 0.05 of the pore volume, which is a polymer solution with an adsorption inhibitor, for which a mixture of surfactants was used, in particular, sodium lignosulfonate, in an amount of 0. 5 wt. % of the total mass of the first slug and organic alkali, in particular monoethanolamine, in an amount of 2 wt. % of the total mass of the first slug.
  • the pore volume which is a polymer solution with an adsorption inhibitor, for which a mixture of surfactants was used, in particular, sodium lignosulfonate
  • organic alkali in particular monoethanolamine
  • the polymer used was partially hydrolyzed sulfonated polyacrylamide with a molecular weight of 6-8 MDa, a degree of hydrolysis of 20-38% and a sulfonic acid content of 5-10 wt%.
  • the polymer content in the first slug was 0.05 wt.% of the total weight of the first slug.
  • the first slug was prepared by mixing sodium lignosulfonate and monoethanolamine with a pre-prepared polymer solution of partially hydrolyzed sulfonated polyacrylamide.
  • a second slug was injected into the formation through the same injection well, which was a solution of a surfactant-polymer composition containing a mixture of nonionic surfactant in an amount of 0.3 wt.%, anionic surfactant, in particular a mixture of sodium and sodium alkylbenzene sulfonates salts of alpha-olefin sulfonates, in an amount of 0.5 wt.%, co-solvent, in particular 2-(2-butoxyethoxy)-ethanol, in an amount of 0.3 wt. % in terms of active substance and 0.15 wt.
  • anionic surfactant in particular a mixture of sodium and sodium alkylbenzene sulfonates salts of alpha-olefin sulfonates
  • co-solvent in particular 2-(2-butoxyethoxy)-ethanol
  • a third slug was injected into the formation through the same injection well, which was a polymer solution, in particular a solution of partially hydrolyzed sulfonated polyacrylamide with a molecular weight of 6-8 MDa, a degree of hydrolysis of 20-38% and a sulfonic acid content of 5 -10 wt.%.
  • the polymer content in the third rim was 0.25 wt. % of the total mass of the selvedge.
  • the size of the third slug was 0.5 of the pore volume.
  • water was injected into the formation through the same injection well, after which oil was produced through production wells that were in hydrodynamic connection with the injection wells.
  • the experimental studies described in the examples confirm the industrial applicability of the claimed invention.
  • the data presented indicate that the proposed method ensures the achievement of a technical result, which consists in increasing the efficiency of surfactant use during surfactant-polymer flooding of the formation, which is expressed in the form of additional oil production per unit mass of surfactant injected into the formation, and reducing non-target surfactant losses.

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Abstract

L'invention se rapporte à l'industrie d'extraction du pétrole, notamment à des procédés d'extraction de pétrole selon des procédés de récupération assistée, et peut être utilisée pour extraire du pétrole dans des gisements aux troisième et quatrième stades de développement. Le résultat technique de l'invention consiste en une augmentation de l'utilisation efficace de STA lors de l'inondation par une STA polymère de la strate qui se traduit par une extraction supplémentaire du pétrole par unité de poids de la STA pompée dans la strate, ainsi qu'une diminution des pertes de STA inutiles. Ce procédé d'extraction de pétrole comprend les étapes suivantes: pomper dans la strate un premier anneau consistant en une solution polymère avec un inhibiteur d'adsorption; pomper dans la strate un deuxième anneau consistant en une solution de composition polymère de STA; pomper dans la strate un troisième anneau consistant en une solution polymère; pomper de l'eau dans la strate; et extraire le pétrole.
PCT/EA2023/050009 2022-12-12 2023-12-07 Procédé d'extraction de pétrole WO2024125751A1 (fr)

Applications Claiming Priority (2)

Application Number Priority Date Filing Date Title
EA202293304 EA044722B1 (ru) 2022-12-12 Способ добычи нефти
EA202293304 2022-12-12

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WO2024125751A1 true WO2024125751A1 (fr) 2024-06-20

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