Use of chemicals or bacterial activity (E21B43/22)

E   Fixed constructions(158735)
E21B43        Obtaining fluids from wells(11343)
E21B43/22                     Use of chemicals or bacterial activity (e21b0043270000 takes precedence;chemical or bacterial compositions therefor c09k0008580000; chemical features in extracting oils from oil sands or shales c10g)(1335)

ethod of multi-stage treatment of injection well bottomhole zone in terrigenous and carbonate formations // 2642738
FIELD: oil and gas industry.SUBSTANCE: method of multi-stage treatment of injection well bottomhole zone in terrigenous and carbonate formations includes hydrochloric acid treatment with acid composition of 0.5-1m3/m volume followed by pressing with aqueous solution of colloidal silicon dioxide nanoparticles or aqueous solution of surface-active substance of 2-3 m3/m volume; clay-acid treatment with clay-acid composition based on hydrochloric and hydrofluoric acids with 0.8 0.5 m3/m volume followed by pressing with aqueous solution of colloidal silicon dioxide nanoparticles or an aqueous solution of surface-active substance of 2-3 m3/m volume, treatment with hydrocarbon solvent of 0.5 m3/m volume and with clay-acid composition based on hydrochloric and hydrofluoric acids with 0.5 m3/m volume then by spraying aqueous solution of colloidal silicon dioxide nanoparticles or aqueous solution of surface-active substance of 2-3 m3/m volume. The following composition is used as acid composition, vol %: 30% hydrochloric acid 50-63; diethylene glycol 6-16; acetic acid 1-3; water-repellent agent based on amides, 1-3; corrosion inhibitor, 1.5-2; the rest is process water. The following composition is used as the clay-acid composition, vol %: 30% hydrochloric acid 48-60; hydrofluoric acid 1-4; diethylene glycol 6-16; acetic acid 1-3; water-repellent agent based on amides, 1-3; corrosion inhibitor, 1.5-2; the rest is process water. As aqueous solution of colloidal silicon dioxide nanoparticles, 1-2%- aqueous solution of colloidal silicon dioxide nanoparticles is used, containing wt %: colloidal silicon dioxide in acrylic acid, 32-40; propylene glycol monomethyl ether, 59.5-67.5; the rest is water. Aqueous solution of surface-active substance is 2-4% aqueous solution of surface-active substance containing, wt %: diethylene glycol, 1-3; hydrophobic agent based on amides, 0.5-2; the rest is process water. Solvent based on toluene fraction of straight-run gasoline or based on an aromatic hydrocarbon concentrateC10 is used a hydrocarbon solvent.EFFECT: increased efficiency injection wells, reduced time for implementation of the method, its simplification and reduced cost.2 cl, 7 dwg

ethod for development of nonuniform permeability reservoirs // 2639341
FIELD: oil and gas industry.SUBSTANCE: method involves injecting aqueous suspension of pre-crosslinked polymer into the formation. For this purpose, a brand of pre-crosslinked polymer and processing technological parameters are selected taking into account individual geological and physical characteristics of the facility. Initial suspension of the pre-crosslinked polymer is prepared on the well by mixing at least two volumes of water and one volume of reagent, which is particles with initial size from 0.1 to 10 mm. After maturation for not more than 120 min the produced suspension is stirred in tank with water and pumped into injection well in working concentration of 0.1-0.5%. When pumping, the suspension of reagent particles is maintained in suspended state. At the same time, it prevents filtration of reagent particles into low- permeability portion of the reservoir due to initial sizes of reagent particles and their subsequent swelling. The range of permeability threshold below which the reagent is not filtered into the formation is permitted from 200 to 500 md depending on initial fraction and swelling value. Reagent concentration is controlled depending on reagent injection pressure.EFFECT: increased efficiency when developing non-uniform permeability reservoirs with water drive operation mode due to additional oil production, reduced or stabilized rate of water content growth.6 cl, 7 dwg, 1 tbl

Particles containing one or multiple crosslinked active substances with controlled release // 2639232
FIELD: chemistry.SUBSTANCE: particle of cross-linked substance preventing the formation of deposits for oil production operations, for a cooling tower water source, comprising a substance preventing the formation of deposits and a crosslinking reagent. The substance preventing the formation of deposits is crosslinked with a crosslinking reagent. A method of producing particles according to the present invention. Methods for performing a mechanical fracturing operation to reduce formation of deposits in an oil well and in a cooling column using particles according to the present invention. The invention is developed in the dependent points of the formula.EFFECT: increasing the efficiency of processing by using these particles.41 cl, 35 ex, 13 tbl, 1 dwg

Fluids and method including nanocellulose // 2636526
FIELD: oil and gas industry.SUBSTANCE: fluid for treating a subterranean formation containing an aqueous two-phase system comprising a first aqueous phase and a second aqueous phase, wherein the first phase comprises NCC containing nanocrystalline cellulose comprising NCC core particles having a crystal structure, the NCC particle concentration in the first phase is higher than their concentration in the second phase, and the fluid is capable to become more viscous than either the first phase or the second phase, when the aqueous two-phase system passes into a single-phase system. The method for treating the subterranean formation comprises injecting said fluid into the subterranean formation. The fluid for treating the subterranean formation contains a solvent, a composition comprising nanocrystalline cellulose containing rod-shaped NCC particles having a crystalline structure and gas. The fluid is a foamed cement suspension comprising gas in amount of approximately 10 to 80% by volume of the suspension. The invention is developed in subclaims.EFFECT: increase of processing efficiency.27 cl, 6 dwg, 7 tbl

ethod and composition to increase oil recovery on basis of supercritical carbon dioxide and nonionic surfactant // 2635307
FIELD: oil and gas industry.SUBSTANCE: oil recovery composition comprises: dimeric nonionic surfactant of the present structural formula I or a regioisomer thereof and/or trimeric nonionic surfactant of the present formula II and carbon dioxide. The oil recovery method comprises: providing a flow of carbon dioxide to the oil pool, introducing said dimeric nonionic surfactant or its regioisomer into the carbon dioxide flow to form the mixture and injecting the mixture into the oil pool. The invention has been developed in the dependent claims.EFFECT: improving the efficiency of the method.9 cl, 1 dwg, 3 tbl, 3 ex

In situ completed upgrading by injecting hot fluid medium // 2634135
FIELD: oil and gas industry.SUBSTANCE: recovery method and in-situ performing the hydrocarbon upgrading in the pair of wells, consisting of the injection well and the recovery well within the oil-bearing reservoir, containing the heavy hydrocarbons, includes the following operations: injection of the hot pumped fluid selected amount, including the heavy hydrocarbons fraction, into the injection well to facilitate the recovery of hydrocarbons and in-situ upgrading; the hydrocarbons extraction from the recovery well.EFFECT: increase of the hydrocarbons extraction with simultaneous upgrading, the impact on the environment reduction, energy costs decrease.67 cl, 10 dwg
Composition of surfactant for recoverying underground liquid fossil fuel // 2633842
FIELD: chemistry.SUBSTANCE: in the present invention, a surfactant composition is provided for the use in the treatment and recovery of liquid fossil fuels from a subterranean formation. A surfactant composition for treating a carrier, a liquid fossil fuel of a subterranean formation containing a primary surfactant - SAA, an agent giving the composition stability selected from the group consisting of auxiliary molecules, dialkyl sulfosuccinate, a solvent, and a mixture thereof, and also water for injection, the primary surfactant comprising a substance represented by the above formula, a substance represented by another reduced formula, and an auxiliary molecule substance is characterized by the formula given for it. The method for producing the above composition that comprises mixing the primary surfactant with the said agent. The method for recovering liquid fossil fuels from a subterranean bearing formation thereof, consisting of injecting the above composition along one or more injection wells, such that oil emerges from one or more production wells. The invention is developed in subclaims.EFFECT: increasing the efficiency of oil recovery.10 cl
Treatment method of bottom-hole formation zone // 2631460
FIELD: oil and gas industry.SUBSTANCE: method for treatment of bottomhole formation zone, characterized in that bottomhole formation zone is treated successively with emulsion solution-ES, oil fringe and acid composition consisting of 15% hydrochloric acid, diethylene glycol, acetic acid, water-repellent agent based on amides, corrosion inhibitor and industrial water, at that, wetability of bottomhole formation zone rock of production formation is preliminary determined and in case of rock hydrophilicity of productive interval, direct type ES of the following composition is used, wt %: hydrocarbon phase in the form of diesel fuel or prepared oil from oil-collecting station 20 -25, emulsifier of Sinol-EM type or sinol EMP 3-5, colloidal solution of silicon dioxide nanoparticles containing (wt %): colloidal silicon dioxide in acrylic acid 40, propylene glycol monomethyl ether 59.5 and water - the rest, 0.5-3, aqueous phase in the form of solution of calcium chloride or sodium chloride solution-the rest, in case of hydrophobic properties of these rocks an ES of reverse type is used in the following composition (wt %): said hydrocarbon phase 40-45, said emulsifier 3-5, said colloidal solution of nanoparticles of silicon dioxide 1-3, aqueous phase in the form of solution of calcium chloride or sodium chloride solution-the rest.EFFECT: increased emulsion solutions stability for complex technology of oil production intensification, obtained additional oil production, increased efficiency of wells with high production rate.13 ex, 7 dwg
ethod of oil recovery from the underground formation // 2630509
FIELD: oil and gas industry.SUBSTANCE: method of the oil recovery from the underground formation, containing the step of the aqueous composition containing from 0.05% to 5 wt % pumping into the indicated formation on the basis of the total amount of the aqueous surfactant-carboxylate alkyl- or alkenyloligoglycoside (ether) composition in accordance with the above structural formula through at least one injection wellbore and recovering the crude oil from the underground formation through at least one production wellbore. The invention has been developed in the dependent claims.EFFECT: increase of the waterflooding efficiency.21 cl, 2 ex, 2 tbl
Composition of surface-active substances for gas condensate wells // 2629509
FIELD: oil and gas industry.SUBSTANCE: composition contains, wt %: polyethylene glycol-4000 - 30-49.9 and polyvinyl alcohol grade 18/11 - 10-15, additionally contains potassium carbonate or sodium carbonate - 10-15, sodium silicate - 10-15, OP-10 - 20-35 and indilin - 0.1-1.EFFECT: increase in the efficiency of removal of the water-condensate mixture from gas condensate wells to the conditions of low reservoir pressures and gas well rates.1 cl
Application and method of stability increase of foam // 2629034
FIELD: oil and gas industry.SUBSTANCE: method for increasing oil production from an oil formation inside a reservoir, comprising: (a) the introduction of foaming composition comprising an alpha-olefin sulfonate into the oil formation under pressure, (b) introduction of gas into the oil formation under pressure, wherein the presence of the foaming composition influences gas flow within the oil formation, and (c) extraction of oil through a wellbore in the reservoir, wherein the foaming composition comprises a foam stabiliser selected from alkylamidopropyl-hydroxysulfobetaine or alkyl-hydroxysulfobetaine, wherein the alkyl group is a group that contains from about 10 carbon atoms to about 24 carbon atoms. A method for increasing oil production from an oil formation inside a reservoir, comprising: (a) introducing of a foaming composition containing an alpha-olefin sulfonate into the oil formation under pressure, (b) introduction of gas into the oil formation under pressure, wherein the presence of the foaming composition influences gas flow within the oil formation, and (c) extraction of oil through a wellbore in the reservoir, wherein the foaming composition comprises a foam stabiliser having the formula I where R1 is an alkylamid group or a linear or branched alkyl group; R2 and R3 represent individually hydrogen, a methyl group or a hydroxyethyl group; R4, R5 and R6 represent individually hydrogen or a hydroxy group, provided that at least one of R4, R5 and R6 represents hydroxy group, wherein alkyl group represents group that contains from about 10 carbon atoms to about 24 carbon atoms. The invention has been developed in the dependent claims.EFFECT: improved mobility control.25 cl, 6 ex, 3 tbl
ethod for regulating intake capacity profile of pressure well (versions) // 2627785
FIELD: oil and gas industry.SUBSTANCE: method for regulating intake capacity profile of a pressure well, including the preparation and injection of gel-forming composition into formation, comprising xanthan, chromium acetate, surfactant - SAS and water, and a process exposure for formation of gel, the intake capacity of the pressure well is predetermined. According to the first one version, with intake capacity of 150-300 m3/day before injecting the gel-forming agent, perform injection of aqueous solution rim of alkaline reagent with a concentration of 0.05-5.0 wt % of 5-10 m3 in volume, then the gel-forming composition is added, additionally comprising a bactericide-formalin or glutaraldehyde, with a content of components, wt %: xanthan - 0.2-0.4, chromium acetate - 0.02-0.04, surfactant - 0.1-0.2, bactericide - 0.05-2.0, the rest is fresh water. After that inject aqueous solution rim of alkaline reagent and a surfactant containing, wt %: alkaline reagent - 0.1-2.0, surfactant - 0.005-3.0, the rest is water with mineralization 0.15-300 g/l, at volume ratio of gel-forming composition to aqueous solution rim of alkaline reagent and surfactant, chosen depending on the intake capaity of the pressure well and equal to 1: (0.5÷3), force said rim into the formation with water with mineralization of 0.15-300 g/l in a volume of 10-15 m3 and stop the well for a technological exposure for 2 to 5 days. According to the second version, with intake capacity of 300-500 m3/day before injecting the gel-forming agent, an aqueous solution rim of an alkaline reagent with a concentration of 0.05-5.0 wt % of 10-20 m3 in volume, inject a gel-forming composition, additionally comprising a bactericide-formalin or glutaraldehyde, with a content of components, wt %: xanthan - 0.3-1.0, chromate acetate - 0.03-0.1, surfactant - 0.15-2.0, bactericide - 0.05-2.0, the rest is fresh water. After that inject aqueous solution rim of alkaline reagent and surfactant at their content, wt %: alkaline reagent - 0.1-2.0, surfactant - 0.005-3.0, the rest is water with mineralization 0.15-300 g/l, at the volume ratio of gel-forming composition to said rim, chosen depending on the intake capacity of the pressure well and equal to 1:(2÷4), force said rim into the formation with water with mineralization of 0.15-300 g/l in a volume of 10-15 m3 and stop the well for a technological exposure for 2 to 5 days. According to the third version, with intake capacity of 500-600 m3/day preliminary inject 50-100m of a dispersion composition rim into the formation, then an aqueous solution rim of alkaline reagent with concentration of 0.05-5.0 wt % of 20-30 m3 in volume, after that inject gel-forming composition, additionally comprising a bactericide-formalin or glutaraldehyde and a polymer, with a content of components, wt %: xanthan - 0.5-2.0, chromate acetate - 0.05-0.2, surfactant - 0.5-4.0, bactericide - 0.05-2.0, polymer - 0.1-1.0, the rest is fresh water. After injecting the gel-forming agent, perform injection of aqueous solution rim of alkaline reagent and surfactant at their content, wt %: alkaline reagent - 0.1-2.0, surfactant - 0.005-3.0, the rest is water with mineralization of 0.15-300 g/l, at the volume ratio of gel-forming composition to said rim, chosen depending on the on the intake capacity of the pressure well and equal to 1:3, force said rim into the formation with water with mineralization of 0.15-300 g/l in volume of 10-15 m3 and stop the well for a technological exposure for 4 to 12 days. Use sodium hydroxide or trisodium phosphate, or sodium liquid glass as alkaline reagent, a dispersed composition rim as aqueous dispersion of the filler with a concentration of 0.01-10.0 wt % or an aqueous dispersion of the filler and polymer with a component ratio, wt %: filler - 0.01-10, polymer - 0.005-1.0, the rest is water with mineralization 0.15-300 g/l, dolomite or wood flour, or bentonite clay powder used as a filler, as polymer - polyacrylamide or sodium carboxymethylcellulose, or hydroxyethylcellulose, said oxyethylated alkylphenols used as surfactant.EFFECT: increased formation recovery, increased efficiency of formation coverage with impact and expansion of technological capabilities of the method.3 cl, 4 tbl
Development method of non-homogeneous oil formation with use of polymer-dispersed composition // 2627502
FIELD: oil and gas industry.SUBSTANCE: in a development method of non-homogeneous oil formation comprising injecting an aqueous polymer dispersion containing polyacrylamide-PAA, a cross-linking agent and a micro-reinforcing additive into the well, and squeezing it to the formation with water, a polymer composition containing, wt %: partially hydrolysed PAA 12.00-17.00, microsilica or microcalcite is the rest, chromium (III) acetate or a cross-linking composition is used as a cross-linking agent, wt %: chrome (III) acetate 2.00-10.00 and 20.0-23.0% hydrochloric acid is the rest, the noted composition being obtained by introducing into the water of fresh or mineralized water with a density of up to 1.012 g/cm3 of the noted polymer composition containing microsilica, while stirring it to complete hydration of the PAA and then introducing a chromium (III) acetate crosslinking agent or the noted cross-linking composition upon pumping into the well, with the following component ratio, wt %: the noted polymeric composition containing microsilica 1.0-7.0, chromium (III) acetate 0.01-0.1 or the noted cross-linking composition 0.5-1.5, the noted water is the rest, or introducing into the water of fresh or mineralized water with a density of up to 1.012 g/cm3 of the noted polymeric composition containing a microcalcite, while stirring it to complete hydration of the PAA and then introducing a chromium (III) acetate crosslinking agent upon pumping into the well, at the following component ratio, wt %: the noted polymer composition containing a microcalcite of 1.0-7.0, chromium (III) acetate 0.01-0.1, the noted water is the rest.EFFECT: increased homogeneity of the composition and provided possibility of adjusting the cross-linking time.2 tbl, 9 ex
ethod for acid treatment of bottomhole well zone // 2623380
FIELD: oil and gas industry.SUBSTANCE: method for acid treatment of the bottomhole well zone involves pumping into the formation in an amount of 4-10 m3 per 1 metre of perforated formation thickness an acid-free oil emulsion of inverse type, containing, vol. %: emulsifier Devon-4v 1.0-4.0; hydrocarbon liquid 5.0-20.0; saturated aqueous solution of calcium chloride 3.0-80.0; mineralized water to 100; pumping into the formation in the amount of 1.8-2.5 m3 per 1 metre of the perforated formation thickness an oil-acid emulsion containing, vol. %: emulsifier Devon-4n 3.0-8.0; hydrocarbon liquid 10.0 to 20.0; saturated aqueous solution of calcium chloride 4.0-10.0; 12-15% aqueous hydrochloric acid solution up to 100; for the emulsion decomposition, the 5.0-20.0% aqueous solution of detergent composition Devon-5 is pumped in the amount of 10-20% of the volume of the previous oil-acid emulsion injection, wherein the emulsion and the detergent are pumped once or in alternating batches 2-3 times.EFFECT: increasing the selectivity and depth of penetrating acid treatment of the formation, increasing the flushing degree of the bottomhole zone from the reaction products and pollutants, reducing the time to put the well into operation.2 tbl
Alkaline persulfate to liquefy process fluid gelled by branched polymer at low temperatures // 2621236
FIELD: chemistry.SUBSTANCE: method to liquefy a fluid having an apparent viscosity of more than 5 cP and used for oil or natural gas production, where the liquid contains a water-soluble branched polysaccharide dissolved in water, selected from the group consisting of xanthan, diutan, and any derivatives thereof, and the method comprises the step of fluid contacting with one or more water-soluble persulfates and one or more strong bases, which is carried out at one or more temperatures less than 100°F (37.8°C). The method of well treatment comprises the following steps: creation of process fluid containing water, one or more branched aforementioned polysaccharides present in the water at a concentration at least sufficient to ensure process fluid viscosity of at least 5 cP, one or more water-soluble persulfates and one or more strong bases, introduction of this fluid into the well and its direction to one part of the well having a design temperature less than 100°F (37.8°C), wherein the step of fluid introduction further comprises injection under a pressure exceeding the subterranean formation fracture pressure. The invention is developed in subclaims.EFFECT: increased processing efficiency at low and very low temperatures.17 cl, 5 tbl
Alkaline persulfate to liquefy process fluid gelled by branched polymer at low temperatures // 2621233
FIELD: chemistry.SUBSTANCE: method to liquefy a fluid having an apparent viscosity of more than 5 cP and used for oil or natural gas production, containing one or more water-soluble synthetic polymers selected from the above group, includesthe step of fluid contacting with one or more water-soluble persulfates and one or more strong bases, which is carried out at one or more temperatures less than 100°F (37.8°C). The method of well treatment comprises the following steps: creation of process fluid containing water, one or more water-soluble synthetic polymers selected from the above group, present in the water at a concentration at least sufficient to ensure process fluid viscosity of at least 5 cP, one or more water-soluble persulfates and one or more strong bases, fluid introduction into the well and its direction to one part of the well having a design temperature less than 100°F (37.8°C). The method of well treatment comprises the following steps: creation of the first process fluid containing water, one or more water-soluble synthetic polymers selected from the above group, present in the water at a concentration at least sufficient to ensure process fluid viscosity of at least 5 cP, creation of the second process fluid containing one or more water-soluble persulfates and one or more strong bases, first process fluid introduction into the well, second process fluid introduction into the well to provide their contact in one part of the well having a design temperature less than 100°F (37.8°C). The invention is developed in subclaims.EFFECT: improved method efficiency at low temperatures.17 cl, 5 tbl

Oil fields treatment fluid // 2620672
FIELD: oil and gas industry.SUBSTANCE: well servicing method comprises ingredients mixing to form a well servicing fluid, wherein the ingredients include: (i) the first surfactant selected from alcohol ethoxylates; the second surfactant selected from C4-C12 primary alcohols; the third surfactant selected from ethoxylated propoxylated alcohols; (Ii) an inverse emulsion with an aqueous phase containing a zwitterionic polymer, wherein the aqueous phase is dispersed in the form of droplets in the hydrophobic continuous phase, and the polymer comprises at least one Ab monomer comprising a betaine group, and optionally one or more nonionic monomer Va; (Iii) water-based saline solution, and injection of the well servicing fluid into the hydrocarbon well.EFFECT: reduced mixing time of well servicing fluid ingredients, the ability to mix in the application.26 cl, 20 dwg, 8 tbl, 11 ex
Highly concentrated flowable salt alkylpolyalkoxysulphates salts // 2619612
FIELD: chemistry.SUBSTANCE: highly concentrated composition of APAS for use as metal processing working fluids, chemicals for application in oil fields, chemicals for application in gas and/or tertiary oil production fields, flowable at min. 25°C, comprising: more than 75 wt % of APAS salts, where APAS contain an average of 3 to 20 alkoxy groups, at least 2/3 alkoxy groups are propoxy groups, and alkyl radicals are radicals of fatty alcohols containing 12 to 18 carbon atoms, and from 1 to less than 25 wt % of water, wherein the composition has a viscosity less than 10,000 mPas⋅, measured according to DIN 53019 standard at a temperature of 25°C and a shear rate of D=10 c-1. The method for productio of the said composition comprises at least the following steps: alkoxylated fatty alcohol is reacted with SO3 in a falling film reactor, the said alcohol comprises an average of 3 to 20 alkoxy groups, at least 2/3 alkoxy groups are propoxy groups, and alkyl radicals are radicals of fatty alcohols containing 12 to 18 carbon atoms, and gas-liquid separation is performed, at that, the liquid phase is neutralized by an aqueous solution of alkali metal hydroxide, containing more than 25 wt % of alkali metal hydroxide. Application of the above composition after dilution and addition of other substances to support crude oil extraction, as well as application of the said composition in enhanced oil extraction or tertiary oil extraction, optionally after dilution with additional components, is proposed. The invention is developed in subclaims.EFFECT: increased emulsifying effect.21 cl, 1 tbl, 1 ex
ethod for development of water-flooded oil reservoir with unhomogeneous geologic structure // 2619575
FIELD: oil and gas industry.SUBSTANCE: method for development of a water-flooded oil reservoir with unhomogeneous geologic structure includes injecting a water-based residue gellant containing an alkali silicate and a divalent metal chloride into the reservoir. First, sodium powdered glass is injected as an alkali silicate in the form of a suspension into the reservoir via an injection well, while using fresh or mineralized water with a mineralization of not more than 50 g/l. Said suspension is forced into the reservoir by a water buffer volume of 3-15 m3. Then magnesium chloride and/or calcium chloride is injected as a divalent metal chloride into the injection well. After that, the reagents are forced in with a water buffer volume of 15-30 m3. Then, the well is kept for reaction for 8-24 hours. Further, the well is put into operation, wherein the commodity forms of calcium chloride or mineralized water with a mineralization of not more than 50 g/l are used.EFFECT: increased development efficiency.4 ex

In situ extraction from oil-bearing sand by ammonia // 2618798
FIELD: oil and gas industry.SUBSTANCE: method for recovering oil from the subterranean container is carried out by introducing waterless gaseous ammonia at a higher temperature, than the temperature of the container, and at the pressure that allows gaseous ammonia to fill the cavity in the subterranean container to condense upon contact with the oil to form liquid ammonia, reacting with oil components to form the surface acting agents, effective to form the emulsion of oil in ammonia, followed by extraction of the emulsion formed from the subterranean container. The invention is developed in subclaims.EFFECT: increased oil extraction efficiency.8 cl, 1 dwg, 1 ex

Composition and method for selection of hydrocarbon fluids from undergound reservoir // 2618239
FIELD: chemistry.SUBSTANCE: invention relates to the composition comprising cross-linked swellable polymeric microparticles that can be hydrolyzed under neutral or lower value of pH, and the method of altering the water permeability of an underground formation by introducing such compositions into an underground formation. The composition for modifying the water permeability of an underground formation comprising swellable cross-linked polymeric microparticles with a mean diameter of unswollen particles of from about 0.05 to about 2000 microns, and a crosslinking agent content of from about 50 to about 200,000 ppm of at least one of the labile crosslinking agent with respect to the molar ratio of the said polymeric microparticles, capable of splitting or at neutral and lower values of pH and at about 0-900 ppm of at least one non-labile cross-linking agent, with respect to the molar ratio, wherein the said labile crosslinking agent is selected from at least one from these structures. The method of modifying the water permeability of an underground formation comprising introducing into an underground formation a composition comprising swellable cross-linked polymeric microparticles as defined above, wherein the diameter of the microparticles is less than the diameter of the pores of the underground formation and the labile crosslinking agents break under the conditions of the underground formation. The invention is developed in subclaims.EFFECT: invention provides increased mobility and / or selection rate of hydrocarbon fluids which are present in underground formations.18 cl, 2 ex, 5 tbl, 1 dwg

ethod of electrochemical liquid preparation, injected in the oil and gas-bearing formation, in order to change the sorption capacity of the header // 2618011
FIELD: oil and gas industry.SUBSTANCE: for electrochemical preparation of the liquid, injected into the oil and gas bearing formation, it is used the electrode pairs with the areas ratio not equal to 1, located in different bodies from electrical insulating materials. Create potential difference on the electrode pairs due to polarization of the liquid pumped through them or by supplying to them the potential difference from the DC power supply, wherein the main part of the electric power is consumed not to cause the electrolysis processes, but to change polarization component of the liquid pumped through the electrode pairs. The electrical load is connected in any sequence to all or one of the electrode pairs, thus, keeping the potential, induced in the electrode pair, but not equal to 0 V.EFFECT: sorption capacity change of the oil and gas header and the oil and gas production capacity due to the oil recovery factor change on the basis of minimization of any type of reagent interference in the relic component of the oil and gas bearing formation.1 dwg
ethod of cleaning bottomhole zone from clay formations // 2617135
FIELD: oil and gas industry.SUBSTANCE: in a method of cleaning bottomhole zone (BHZ) from clay formations a loose part of clay formations is removed by washing BHZ with process water, after which a clarifying water-based reagent comprising sodium bisulfate in the amount of 15-17 wt % and hydroquinone in the amount of 2-4 wt % is injected into BHZ and held until destruction of the dense part of the clay formations, then washing from the reaction products is carried out and acid aqueous solution comprising oxyethylidenediphosphonic acid in the amount of 17-19 wt % is injected, then the specified acid aqueous solution is held during the time necessary for dissolution of residual clay formations, and well development is carried out.EFFECT: increased efficiency of bottomhole zone cleaning due to maximum build-up of productive formation permeability.3 ex,1 tbl

ethod for oil production from underground oil deposits // 2614827
FIELD: oil industry.SUBSTANCE: invention relates to oil production. Method for oil extraction from underground oil deposits, having at least one injection well and at least one production well, including at least following steps: (1) injecting steam into at least one injection well and extraction of oil by at least one production bore, temperature at injection hole according to process step (1) ranges from 90 to 320 °C, (2) blocking highly permeable zones of oil field in region between at least one injection well and at least one production well by injecting aqueous formulations by at least injection well, formulations water and chemical components contain after injection into reservoir under influence can form gels reservoir temperature, (3) continuing production of oil by at least one production well. Step (2) is performed by separate series pumping into deposit of at least acid composition F1, containing at least water, as well as a water-soluble salt of aluminium (III) and/or partially hydrolysed aluminium (III) salt in amount of 3 to 30 wt% (relative to anhydrous compounds of aluminium) in terms of sum of all components of composition, and composition of F2, containing at least water and at least one water-soluble activator in an amount of 3–60 wt% in terms of sum of all components of composition, which while heating to temperature higher than 50 °C increases pH and is a compound selected from a group comprising urea and water-soluble substituted ureas, under condition that temperature of pumped compositions F1 and F2 before pumping is less than 40 °C. Said compositions when pumping into oil reservoir are mixed with each other and as a result of heating, caused by heat of deposit, form viscous gels.EFFECT: reduction of water content and increasing oil recovery in beds with very hot zones.15 cl, 7 dwg, 2 tbl
Desorbents for enhanced oil recovery // 2611088
FIELD: oil industry.SUBSTANCE: present invention relates to improvement of oil recovery from underground formations. Use of at least one nonionic surfactant – NIS, selected from compounds of formula R-O-(-CH2-CH(-CH3)-O-)m-(-CH2-CH2-O-)n-H, where R is a dodecyl group -(CH2)11-(CH3), m is an integer from 0 to 20; n is a number greater than m and ranging from 5 to 40, to prevent retention of anionic surfactant in oil reservoir, in particular, in a carbonated or clay reservoir, said NIS is used as at least as an agent preventing retention of anionic surfactant introduced in combination with it, and/or as a protective agent, introduced before introducing anionic surfactant, and/or for desorption of anionic surfactant, previously contained in reservoir. Method for improved oil recovery from underground formation, including said application, comprising steps of: injecting into said underground formation via at least one injection well, a fluid comprising at least an aqueous medium, an anionic surfactant and optionally an anionic cosurfactant, then injecting fluid containing said NIS and said fluid moving oil coming from an underground formation, extracted by means of at least one agent. Invention is developed in subclaims.EFFECT: technical result is high efficiency of oil recovery.13 cl, 4 tbl, 4 ex
Justification method of input profile in injection well // 2610961
FIELD: petroleum industry.SUBSTANCE: justification method of an input profile in an injection well includes the pumping of a compound containing water suppression of polyacrylamide (PAA), cellulose ether, chromium acetate, and a filler into a shelf. Piolyanionic cellulose (PAC) or carboxymethyl cellulose (CMC) is used as a cellulose ether, the mass ratio of PAA and PAC or CMC is (1-4):1; solid microparticles of dolomitic powder or wood powder or zeolite-containing arterial with the concentration of 0.001-0.45 mass. % is used as a filler; after the pumping of the compound into a shelf, water solution fringe of a surface-active agent (SAA) and alkaline agent at the following mixture ratio, mass. %: SAA - 0.01-0.2, alkaline agent - 0.1-2.5, water - the rest, is additionally pumped; nonylphenol ethoxylate of complex SAA is used as SAA; sodium hydroxide or alkali salt is used as a alkaline agent, whereupon, the said compound and the fringe are pumped in a volumetric ratio of (2-5):1; the shelf is squeezed down by the pumped water in the volume of 10-20 m and the well is left for the process soak period of 4 days.EFFECT: increasing of efficiency of the method by means of reduction of an induction period of gel formation, improvement of strength performance of obtained compounds leading to the increasing of oil recovery from non-uniform permeable shelves, as well as the expansion of process capabilities of the method.3 tbl
Oil reservoir development method (versions) // 2610959
FIELD: oil-and-gas industry.SUBSTANCE: present invention relates to oil industry, in particular to microbiological methods of oil recovery. The process includes four possible methods forof development of oil reservoir, where in each case the injectivity of the injection well and water salinity are clarified in advance. The first and the second methods comprise depending the well injectivity 100 - 300 m3/day and the water salinity 0.15 - 100 g/l or 100-220 g/l, pre-injection of the mixture of hydrogen peroxide in the mineral salt solution in the volume 5-10 m3 or 10-15 m3 is performed then the cyclic injecting by alternating fringes is performed in the volume ratio 1: 1 of hydrocarbon oxidizing microorganism in the solution of mineral salts and in the mixture of hydrogen peroxide in the solution of mineral salts, and punching into the reservoir by the water with the salinity 0.15 - 100 g/l or 100-220 g/l in the volume 10-15 m3 and well shutdown for production seasoning within for 10-12 days. According to the third and the forth methods depending the well injectivity 300 - 500 m3/day and the water salinity 0.15 - 100 g/l or 100-220 g/l, pre-injection into the formation of the the water dispersion of wood flour with the concentration ot 0.005 - 1.0 wt.% is performed, then the mix of hydrogen peroxide solution in the mineral salt solution in the volume 5-10 m3 or 10-15 m3 is injected, then the cyclic injecting by alternating fringes is performed in the volume ratio 1: 1 of hydrocarbon oxidizing microorganism in the solution of mineral salts and in the mixture of hydrogen peroxide in the solution of mineral salts, and punching into the reservoir by the water with the salinity 0.15 - 100 g/l or 100-220 g/l in the volume 10-15 m3 and well shutdown for production seasoning for 10-12 days.EFFECT: invention improves the efficiency of microbial stimulation, increases the coverage of the reservoir and minimize the watering.12 cl, 3 tbl
ethod of development of oil deposit // 2610958
FIELD: oil-and-gas industry.SUBSTANCE: invention relates to oil industry, in particular to development of oil fields and crude oil production, and can be used for formations oil recovery increasing. The method of oil deposit development comprising oil driving from the formation by successive oil rings of displacement fluid with regulated viscousity and water, for fields with low formation temperature the displacement fluid is composition at the following ratio of components in wt %: complex SAA Neftenol VVD or mixture of non-ionic SAA - neonol AF9-12 or NP-40, or NP-50, and anionic SAA - volgonat or sulphanole - in ratio 2:1, 1.0-2.0, ammonium nitrate 10.0-15.0, carbamide 20.0-30.0, aluminium chloride or aluminium nitrate waterless or hydrated or their partially hydrolyzed forms 1.0-3.0, soda ash, or potassium carbonate, or ammonium carbonate, or hexamethylenetetramine (hexamin), or sodium nitrite 0.5-6.0, rest for water.EFFECT: method of efficiency increasing of oil recovery from formation with low formation temperature by increasing of oil recovery factor.3 dwg, 1 tbl, 7 ex
ethod for development of carbonate oil reservoir (versions) // 2610051
FIELD: oil industry.SUBSTANCE: invention relates to oil industry, in particular to development of carbonate oil formations. Technical result is higher reservoir recovery and reduction of watering of extracted product. Method for development of carbonate oil reservoir, containing sulphate-reducing bacteria – SRB, which involves activation of formation microflora through injection into formation through of an aqueous suspension of nutrients, predetermining injectability of injection well, for injectability of injection well from 100 to 150 m3/day, method includes injecting aqueous solution of said salts with concentration of 1.0 to 1.5 wt% or aqueous solution of sodium or potassium nitrate with concentration from 0.1 to 1.0 wt%, injecting water with said mineral content in an amount of 5–15 m3 and stopping well for suppression of SRB, injecting aqueous solution of said surfactant or complex surfactant with said pour point, containing a mixture of nonionic and cationic surfactant, with concentration of 0.01–0.3 % or aqueous solution of edible diammonium phosphate or trisodium phosphate, or sodium hydroxide with concentration of 0.2–1.5 %, injecting aqueous suspension of nutrients, containing sapropel, starch and edible diammonium phosphate, injecting into formation water with said mineral content in an amount of 10–50 m3, stopping well for process holding for 3 to 15 days, concentration of reagents aqueous suspension is, wt%: starch 0.1–5.0, sapropel 0.5–5.0, edible diammonium phosphate 0.1–2.0, water with mineral content from 0.15 up to 300 g/l – balance. In another version, for injectability of injection well from 150 to 400 m3/day, method includes injecting aqueous solution of sodium or potassium nitrate, or ammonia with concentration of 1.0 to 1.5 wt% or aqueous solution of sodium or potassium nitrite with concentration from 0.1 to 1.0 wt%, injecting into formation water with said mineral content in an amount of 5-15 m3 and stopping well for suppression of SRB, additionally injecting a locking composition, injecting into formation aqueous solution of oxyethylated alkylphenol or complex surfactant with said pour point, containing a mixture of nonionic and cationic surfactant with concentration of 0.01–0.3 % or aqueous solution of edible diammonium phosphate or trisodium phosphate, or sodium hydroxide with concentration of 0.1–1.5 % and stopping well for process holding, injecting aqueous suspension of nutrients, containing sapropel, starch and edible diammonium phosphate, injecting into formation water with said mineral content in an amount of 10–50 m3, stopping well for process holding with said composition of aqueous suspension.EFFECT: invention is developed in subclaims.3 cl, 2 ex, 8 tbl

ethod of underground reservoir zone processing and media used therein // 2609040
FIELD: mining.SUBSTANCE: invention relates to drilling and well servicing fluids. Method of underground formation zone processing, opened by drilling well, involves use of oily cross-linking liquid composition containing oily liquid, suspending agent, which is clay or fill-silicate material, surfactant and boron-containing cross-linking agent, wherein oily liquid is hydrocarbon oil with flash point of 70–300 °C and contains 0.1 % of aromatic hydrocarbons maximum weight, selected from benzene, toluene, ethylbenzene and m-, o- and p-xylenes (BTEX) and alkyl substituted benzene components, production of formation treatment liquid consisting of water, gelling agent and oily cross-linking liquid composition, and introduction of said fluid for formation treatment in zone inside drilling well opening underground reservoir, oily cross-linking liquid composition contains from 0 to less than 5 ppb of benzene, from 0 to less than 1,000 ppb of toluene, from 0 to less than 700 ppb of ethylbenzene, and from 0 to less than 10,000 ppb of xylene, and from 0 to less than 1,000 ppb of alkyl substituted benzene components, including C2 and C3-benzenes, determined using EPA SW 8260 test method. Oily cross-linking liquid composition for underground wells servicing, containing: oily liquid representing hydrotreated hydrocarbon, boron-containing cross-linking agent with range of solubility in water from 0.1 kg/m3 to 10 kg/m3 at 22 °C and suspending agent, which is clay or fill-silicate material, where oily cross-linking liquid composition contains from 0 to less than 5 ppb of benzene, from 0 to less than 1,000 ppb of toluene, from 0 to less than 700 ppb of ethylbenzene and from 0 to less than 10,000 ppb of xylene, which are determined using EPA SW 8260 test method. Invention is developed in depending points of the formula.EFFECT: increasing safety at maintaining of used hydrocarbon compositions utility during operation of deposits.24 cl, 1 dwg, 2 tbl, 1 ex
ethod of development of inhomogeneous oil formation // 2608137
FIELD: oil industry.SUBSTANCE: invention relates to oil industry, namely to change of filtration characteristics of non-uniform beds, increasing oil deposits recovery and reducing watering of producing wells with obtaining maximum effect at late stage of oil deposit development. Method of development of non-uniform oil deposit, which involves pumping to well of water suspension of wood flour and polymer, involves preliminary determination of initial specific injectivity of well, as disperse phase mixture of wood flour and polymer is used, as dispersion medium water with mineralization from 0.15 up to 300 g/l is injected, as polymer high-viscosity oxyethyl cellulose (OEC) is used, said aqueous suspension of wood flour and OEC is pumped in two volumes, first fringe of said aqueous suspension is injected until specific injectivity of well is reduced by 15–30 % of initial specific injectivity of well in following proportions, wt%: wood flour 0.3–1.5, OEC 0.001–0.5, said water with mineralization from 0.15 up to 300 g/l is the rest, then pumping of second fringe of said aqueous suspension is made until specific injectivity is reduced by 5-10% of initial specific injectivity of well in following proportions, wt%: wood flour 0.001–0.5, OEC 0.005–1.0, said water with mineralization from 0.15 up to 300 g/l is the rest, wherein said fringe is pumped in volume ratio 1:(1-7).EFFECT: technical result is increase of efficiency of oil production due to increased coverage of bed and reducing watering of producing wells, expanded technical performances.1 cl, 3 tbl, 2 ex
ethod of natural gas production from hydrates // 2607849
FIELD: gas industry.SUBSTANCE: invention relates to gas production industry, in particular to methods of gas deposits development from natural hydrates deposits. According to method performing deposit drilling by wells with hydrates formation opening. After that, performing primary agent in form of thermodynamic hydrates formation inhibitor pumping into well with provision of methane hydrates stability equilibrium parameters under thermobaric formation conditions shift into hydrates resistance reduction area. At that, also performing secondary agent pumping, capable of carbon dioxide hydrate forming under thermobaric formation conditions at degree of hydrates formation inhibitor initial concentration dilution with hydrated water of not more than 10 times. Performing developed product extraction. At considerable distance between wells primary and secondary agents are pumped simultaneously. At small distance between wells said agents are pumped in series.EFFECT: technical result is increase in methane extracting rate from hydrates and methane hydrate into free gas conversion degree.1 cl, 8 ex, 6 tbl

ethod of increasing oil recovery of fractured, well permeable, average-permeable porous beds and beds with artificially created cracks after hydraulic fracturing-fhf // 2605218
FIELD: oil and gas industry.SUBSTANCE: disclosed is a method of increasing oil recovery of fractured, well-penetrable, medium-penetrable porous beds and beds with artificially created cracks after hydraulic fracturing of the bed involving pumping of water solution, suspended in which is a mixture of modified bentonite clay powder - MBCP with an additive and partially hydrolyzed polyacrylamide - PHPAA, while suspended in the water solution is a mixture containing as an additive quartz sand at a ratio of MBCP to quartz sand from 10:1 to 4:1 with the amount of 5-10 MP, 1-10 MP of dry sodium silicate, 0.01-0.30 MP of PHPAA and 0.1-0.60 MP of a fixing agent-technical calcium chloride.EFFECT: higher efficiency of processing, pumping of a bigger amount of the composition into a more remote formation zone.1 cl, 2 tbl

ethod of increasing oil recovery by chemical treatment // 2604627
FIELD: chemistry.SUBSTANCE: invention relates to chemistry of oil and concerns use of non-organic reagents for oil industry, in particular, for acid and salt treatment of oil-containing formation, represented by heterogeneous permeability carbonate or terrigenous reservoirs. Described is a method of increasing oil recovery by chemical treatment, including pumping into reservoirs salt solutions of sodium and magnesium, wherein said solution is acidified solution of sodium chloride and magnesium chloride in ratio 1:0.10÷0.15 with total content of salts 60-200 g/l, and alternation of pH of pumped solution selected from range 1.0-5.5.EFFECT: technical result is higher oil recovery of formations.1 cl, 2 tbl, 4 ex

ethod of development of flooded oil formation // 2603321
FIELD: oil industry.SUBSTANCE: invention relates to oil and gas industry. Method of development of flooded oil formation involves pumping into the oil formation through an injector a 10 % aqueous solution of a mixture of sodium salts of lignosulphonic acids, a composition of 10 % aqueous solution of alkaline drain of caprolactam production, a multicomponent mixture containing synthetic anionic, nonionic surfactants, oxyethylated alco-ethers of phosphoric acid, a hydrocarbon solvent and an aliphatic or aromatic alcohol, with the following ratio of components, wt%: the said aqueous solution of alkaline drain of caprolactam production 99.3-99.7; the said multicomponent mixture 0.25-0.45; aliphatic or aromatic alcohol 0.05-0.25.EFFECT: technical result is increased oil recovery of flooded oil formation due to separation of residual oil.1 cl, 3 dwg

ethod of inhibiting formation of hydrates in hydrocarbon-containing raw material // 2601649
FIELD: technological processes.SUBSTANCE: invention relates to methods of inhibiting formation of gas hydrates in different hydrocarbon-containing liquids and gases containing water and hydrate-forming agents, and can be used in processes of extraction, processing and transportation of hydrocarbon raw material to prevent formation of gas hydrates. Hydrocarbon-containing raw materials, including water and hydrate-forming components is treated with an inhibitor, in form of a composition containing a kinetic inhibitor, thermodynamic inhibitor and synergetic additive selected from a group comprising quaternary ammonium salts, ethylene glycol esters of general formula R1OCH2CH2OR2, where R1 is a hydrogen atom or alkyl radical, R2 is an alkyl radical, oxyethylated fatty alcohols, oxypropylated fatty alcohols, polyethylene oxide, polypropylene oxide, copolymers of ethylene oxide and propylene oxide or a mixture of said substances in following ratio of components, wt%: kinetic hydrate inhibitor 2.0-8.0; thermodynamic hydrate formation inhibitor 84.0-96.0; synergetic additive - balance, up to 100.EFFECT: technical result is higher inhibiting capacity of described method compared to existing method.1 cl, 4 ex

ethod for selective bottomhole zone processing of inhomogeneous stratified productive formation // 2600800
FIELD: oil industry.SUBSTANCE: invention relates to oil production. Method for selective BZP of inhomogeneous stratified productive formation includes the following steps when: geophysical survey in the well is performed; the decision is taken upon the necessity of selective BZP to be performed; in case of positive decision on necessity of selective BZP the number of intervals to be processed (interlayers) is determined; an assembly of at least two packers on a pipe string is lowered into the processed interval; the required interval to be processed and containing an interlayer is isolated by means of two adjacent packers; selective BZP of the required interval is performed; the dual-packers assembly is moved to process the next interval; the processing is stopped when all required intervals to be processed are done; herewith at the stage of making the decision upon the necessity of selective BZP to be performed the maximum tolerable pressure on productive strata is to be determined, between two adjacent packers a filter is installed with a circulation valve, and below the lower of the two adjacent packers a perforated connection pipe and a plug are mounted, so that two processing intervals are done simultaneously.EFFECT: technical result is the increase of efficiency and success of performing the bottomhole zone processing.6 cl, 7 dwg

Composites for controlled release of well treatment agents // 2600116
FIELD: mining.SUBSTANCE: invention relates to treatment of wells using reagents. Well treatment composite comprising a well treatment agent and calcined porous metal, where porosity and permeability of calcined porous metal oxide is such that well treatment agent is adsorbed into interstitial spaces of porous metal oxide, and further: area of surface of calcined porous metal oxide ranges from about 1 m2/g to about 10 m2/g, particle diameter 0.13 mm and pore volume of said metal oxide from 0.01 to 0.10 cm3/g. In another version well treatment composite, introduced into an underground formation, contains a well treatment reagent and calcined porous metal oxide, where porosity and permeability of said oxide is such that said reagent is absorbed in interstitial spaces of porous aluminium oxide, and reagent is capable of being absorbed at constant rate for a long period of time in formation fluid medium contained in an underground formation. Proppant containing said last composite, where no more than 15 % of proppant is crushed at closure stress of 10,000 pounds per square inch (68.95 MPa), when composite contains 10 wt% of well treatment reagent. Method for treatment of underground formation, permeated with well shaft involves pumping to borehole well treatment fluid containing said composite. Method for stimulation of underground formation involves pumping into formation a well treatment fluid containing said composite. Method for treatment of underground formation involves introduction into underground formation or well bore, penetrating through underground formation, said composite. Method of inhibiting or controlling speed of release of well treatment agent in underground formation or in well bore by introducing into formation or well bore said composite, which after a single treatment has duration of at least six months. Method of limiting inflow of sand in well bore, penetrating through underground formation, involving: introduction into well bore suspension of said composite and fluid carrier, placing composite near underground formation to form a permeable fluid medium seal, which can reduce or almost prevent passage of formation particles from an underground formation into well bore with simultaneous free passage of formation fluids from underground formation into well bore. Invention is developed in depending points of the formula.EFFECT: high efficiency of processing.27 cl, 9 ex, 5 tbl, 6 dwg

Additives for improving hydrocarbon recovery // 2599999
FIELD: chemistry.SUBSTANCE: group of inventions relates to thermal methods of recovering hydrocarbons from subterranean formations. Method for recovering hydrocarbons from subterranean formations comprises the following steps: (i) contacting the hydrocarbon from the subterranean formation with steam; (ii) contacting the hydrocarbon from the subterranean formation with one or more fluorinated hydrocarbons selected from: trifluoroethanol, trifluoropropanol, trifluorobutanol, allylhexafluoroisopropanol, hexafluoroisopropanol, triflaoroacetic acid, methyl trifluoroacetate, ethyl trifluoroacetate, isopropyl trifluoroacetate, trifluoroacetaldehydemethyl hemiacetal, trifluoroacetaldehyde ethyl hemiacetal, trifluoroacetic anhydride, trifluoroacetone, fiuorotoluene, and any combination or mixture thereof; and (iii) recovering the hydrocarbon from the subterranean formation.EFFECT: technical result is increasing the production with the same steam input, improving the heat efficiency as well as reducing the oil-water interfacial tension.14 cl, 2 dwg, 5 tbl, 4 ex

ethod for developing heterogenous ultraviscous oil reservoir // 2599994
FIELD: oil and gas industry.SUBSTANCE: invention can be used in developing heterogenous ultraviscous oil formations. Method comprises selecting section of formation with number of permeable intervals of more than 1 unit fraction. In central part of formation a horizontal steam well is drilled. At a distance of 1-5 m from formation bottom or water-oil contact a production horizontal well is drilled. Said wells are conditionally horizontal. Said wells are arranged so that contact area of each conditionally horizontal-shaft with oil saturated bed is not less than 0.5 of total surface of said horizontal shaft. Method includes calculation of thermal hydrodynamic model of propagation of boundaries of steam chamber after 10-15 years of steam pumping at maximum intake capacity of steam well. At a conditional point obtained in plan view at intersection of boundary of design steam chamber and a plane drawn perpendicular to horizontal shaft of steam well through its centre, main shaft of vertical well is drilled. Said well is then drilled with a smaller diameter not less than 3 side horizontal shafts of descending shape with coverage of design steam chamber not less than 70 % in both plan and profile. Well fan-like shape is obtained. Each of its shafts is provided with possibility of disconnection after flooding. Horizontal and fan wells are developed after drilling by injection of solvent in amount of 1-5 m3 per 1 m length of conditionally horizontal bores. For implementation of technology of steam assisted gravity drainage, steam is pumped into injection wells and product is extracted through production wells.EFFECT: increasing oil recovery factor of heterogeneous oil formations.1 cl, 2 ex, 2 dwg

Well operation method // 2599653
FIELD: oil and gas industry.SUBSTANCE: invention relates to oil industry and can be used in operation of well for extraction of viscous oil emulsion. Method of well operation includes equipment of well tubing string (TS) with bottom-hole pump, filter, cable and capillary pipeline. Electric current is supplied via cable and a solvent and asphaltene-resin-paraffin deposits - ARPD, via capillary pipeline. Method comprises simultaneous recovery of products via tubing string by sucker rod pump. At wellhead in tubing string from below upwards is arranged: plug, heater, filter, bottom-hole pump. Cable is connected with heater, and on external surface of tubing string is secured by clamps cable to heater and capillary pipeline from wellhead to depth of above sucker rod pump with input into inner cavity of tubing string. Tubing string is placed in well so that heater is located from middle of formation to its bottom. For 24 hours before starting drive of sucker rod pump, heater is put into operation. Operating temperature of heater is not higher than 40 °C. After 24 hours is performed step-by-step operation of well bottom-hole pump drive starting with minimum number of swings and maximum stroke and with periodical stepped increase of temperature of heater at 20 °C, starting with temperature of 50 to 90 °C, and solvent supply with pump dosaging device via capillary pipeline with stepped reduction of solvent feeding at 5 l/h, starting from supply of 15-5 l/h, at each stage of operation under condition of achieving maximum volume of product.EFFECT: higher efficiency of heating bottom-hole zone.1 cl, 1 dwg, 1 tbl

Nonionic surfactants for enhanced crude oil recovery // 2598957
FIELD: chemistry.SUBSTANCE: present disclosure relates to using a nonionic surfactant that is soluble in carbon dioxide for enhanced crude oil recovery. Method for recovering crude oil from a subterranean formation comprising injecting a nonionic surfactant in carbon dioxide into the subterranean formation, where the nonionic surfactant is prepared by an alkoxylation reaction with a double metal cyanide catalyst of a first epoxide, a second epoxide different than the first epoxide, and a branched aliphatic alcohol having 3 to 9 carbon atoms and recovering crude oil from the subterranean formation. Emulsion comprising carbon dioxide a diluent and the nonionic surfactant. Invention is developed in depending points of the formula.EFFECT: technical result is increase in oil production.10 cl, 4 dwg, 2 tbl, 2 ex

ethod for oil production from underground oil deposits // 2598672
FIELD: oil industry.SUBSTANCE: invention relates to oil production, particularly to a method of oil extraction from underground oil deposits. Method assumes penetration of at least one injection well and at least one production well. One or more displacement media are forced in at least one injection well, and oil is extracted through at least one production well. Zones of oil deposit with high permeability in the area between at least one injection well and at least one production well are locked out, for this purpose at least one F1 aqueous composition of and at least one F2 aqueous composition is forced through at least one injection well in deposit in each case individually and in series. Compositions after pumping get mixed with each other in the formation in the zone of mixing and form viscous gels. Continued injection of one or several displacement in injection well. Composition F1 includes water and urotropine. Composition F2 includes water and urea. F1 and/or F2 contain at least one compound M selected from compounds of metals and compounds of semimetals, compound M is gel-forming on addition of alkali. Compounds of metals and compounds of semimetals are selected from the group of salts Fe (II) and Fe (III), vanadium salts, zirconium salts, aluminium salts (III), and silicon colloidal compounds. In zone of mixing, urotropine concentration is at least 1 wt%, urea concentration is at least 5.75 wt%, and concentration of at least one compound M is at least 5 wt% relative to the sum of water, urotropine, urea and at least one compound M located in the zone of mixing.EFFECT: technical result is higher oil yield.13 cl, 2 tbl, 3 dwg

ethod of oil reservoir extraction (versions) // 2598095
FIELD: oil industry.SUBSTANCE: invention relates to oil industry, to methods of oil reservoir extraction, in particular. Method of oil reservoir extraction includes successive water solution of alkali with SAS and water solution of polymer pumping into reservoir through fringe injector well with subsequent flooding and oil extraction through production wells, water-soluble oxyethylated alkylphenol (WOA) is used as SAS, polymer is polyacrylamide (PAA), initial intake capacity of injection well at pumping pressure is measured at first, maximum allowable production string pressure is calculated, volume ratio of pumping fringes depending on initial intake capacity of injection well is measured, mineralization of pumped water is additionally specified and if its value is 0.15-45 g/l, first fringe is pumped in until pumping pressure is increased by 15-30 % of initial pumping pressure, mixture of aqueous solution of alkali with WOA and PAA is used as first fringe containing following proportions, wt %: alkali - 0.1-3.0, WOA - 0.05-0.3, PAA - 0.05-0.8, water with mineralization from 0.15 up to 45 g/l - the rest, second fringe is pumped in until pumping pressure is increased by 30-70 % of the initial pumping pressure to maximum allowable production string pressure, mixture of aqueous solution of PAA and PAA is used as second fringe containing following proportions, wt %: PAA - 0.05-0.8, WOA - 0.05-0.3, water with mineralization from 0.15 up to 45 g/l - the rest, volume ratio of fringes is 1:1 with intake capacity of 100-250 m3/day and (1-2):1 with intake capacity of 250-400 m3/day, and before pumping of mentioned fringes water solution of PAA with concentration of 0.05 to 0.5 wt % is pumped in volume equal to the first fringe volume or pumped amount of water with mineralization from 0.15 up to 45 g/l in amount of 10-20 m3. In another version of this method with mineralization of 45-300 g/l first fringe is pumped until pumping pressure is increased by 15-30% of the initial pumping pressure, mixture of aqueous solution of alkali with WOA is used as first fringe with their component ratio, wt %: alkali - 0.1-3.0, WOA-0.001-0.15, water with mineralization 45-300 g/l - the rest. mixture of aqueous solution of PAA and WOA is used as second fringe with their component ratio, wt %: PAA - 0.05-0.8, WOA - 0.05-0.3, water with mineralization 45-300 g/l - the rest, second fringe is pumped in until pumping pressure is increased by 30-70% of the initial pumping pressure to maximum allowable production string pressure, volume ratio of fringes is 1:(1-2) with intake capacity of 100-250 m3/day and 1:(1-3) with intake capacity of 250-400 m3/day, and before pumping of mentioned fringes water solution of PAA with concentration of 0.05 to 0.5 wt % is pumped in volume equal to the first fringe volume or pumped amount of water with mineralization from 45 up to 300 g/l in amount of 10-20 m3.EFFECT: technical result is increase of efficiency of oil displacement from reservoir, reduced loss of SAS and alkali.2 cl, 2 tbl, 2 ex

ethod for uniform extraction stratified reservoir // 2597596
FIELD: oil and gas industry.SUBSTANCE: invention can be used in developing heterogenous layered reservoirs. Method involves selection of producer and nearest injection well, which is reason of flooding of production well. Method includes pumping into well a composition for limiting water influx to eliminate water inrush zones. Water is pumped into injection well and product is extracted from production well. Composition for limiting water inflow is modified with water-water, concentration and ion composition of dissolved salts which is determined by laboratory research of reduction of permeability of core of given interlayer by not less than 10 times while pumping one porous volume of core at formation temperature and pumping rate of not less than 5 ml/min. Reduction of permeability is a result of precipitation of salts in bottomhole zone of production well during reaction of modified water with waste water of interlayer. Water cut of each interlayer is determined in production well. In injection and production well a string is lowered, having packers and said packers isolate interlayer with maximum water content from rest of interlayers. Modified water is pumped into isolated interlayer through injection well at a rate of 0.5-1.0 of maximum intake rate of interlayer. Bottom-hole pressure in production well is reduced to 0.9-1.0 of saturation pressure. Pumping is performed until water cut of interlayer is 0.8-1.2 of water cut of interlayer with minimum water cut. After that, through injection well in analysed interlayer aqueous solution of chlorine is pumped in amount of 20-100 m3 per 1 m effective thickness of interlayer. In first 10-50 m3 of injected modified water saline deposit inhibitors are added. Similar operation for successive pumping of modified water and aqueous chlorine solution is carried out on other interlayers except interlayer with minimum water cut. After that, wells are converted to normal operating mode. Said operations are repeated with periodicity of 0.5-2 year.EFFECT: high uniformity of recovery of oil reserves, increasing sweep efficiency and oil recovery of layered oil deposits.1 cl, 2 ex, 1 tbl, 1 dwg

ethod of developing oil deposits // 2597595
FIELD: oil and gas industry.SUBSTANCE: invention can be used in development of anticline deposits of oil of water-oil zones and terrigenous type. Method involves drilling of deposit with water-oil zones of system of production wells. Said wells in upper part of productive formation are perforated for product extraction. Development is carried out in deposits with an anticline structure presented by terrigenous type of reservoir, in pores of which there are fine clay particles and not less than 50 % of said particles relate to kaolinite clays. After flooding by more than 98 % of one or more wells of first row located closest to oil-water contact, modified water is injected, where modified water in which concentration of NaCl is not more than 5 g/l and its effect on reservoir reduces water relative permeability by at least 5 times. Pumping is performed for 3-10 days with rate of 0.1-0.8 of maximum intake of said wells. Thereafter, said wells of first row are stopped. In adjacent production wells of second row, upstream of structural marks, modified water is injected for 5-15 days with flow rate of not more than 0.1 of maximum intake of said wells. Then after 1-10 days production begins in wells of second row. Processes of pumping modified water are repeated consecutively in direction from minimum structural marks to maximum with flooding of corresponding wells.EFFECT: increasing oil recovery of oil deposits.1 cl, 2 ex, 1 dwg

ethod for balancing injection well water-intake capacity profile and restriction of water influx to production wells // 2597593
FIELD: oil industry.SUBSTANCE: invention relates to oil industry, in particular, to methods of limiting water influx in production wells and balancing injection well water-intake capacity profile. Using the presented method in oil industry will allow to eliminate limitations on the use of polymer gel-forming compositions at deposits with mineralized water, increase their efficiency. In method for balancing of injection well water-intake capacity profile and restriction of water influx to production wells, which involves pumping to the formation of an aqueous solution of polyacrylamide and a cross-linking agent, where the said solution is prepared on the formation water with subsequent introduction of sodium hydroxide up to pH 8.0, sodium bicarbonate in the amount of 2.48 wt%, additionally introduced chelating agent - disodium dihydrogen ethylenediaminetetraacetate in the amount of 0.1-5.0 wt%, then polyacrylamide in the amount of 0.2-3.5 wt%, chrome acetate in the amount of 0.47 wt%.EFFECT: technical result is the increase of technological effectiveness of using polymer compositions, and the formed gel in less susceptible to degradation.1 cl, 2 tbl

Composition for increasing oil displacement // 2597383
FIELD: oil industry.SUBSTANCE: invention relates to oil industry, in particular, to methods for development of flooded non-uniform reservoir using chemical reagents. Composition for increasing oil displacement, including gel-forming component based on nepheline and hydrochloric acid, contains as gelling component based on nepheline finely ground alumino-alkaline syenite concentrate with particle size of 10-50 mcm and hydrochloric acid 3-8 % in following ratio, wt%: said concentrate - 1.0-8.0 and said acid - balance.EFFECT: technical result is improved strength properties of injected gel-forming compound.1 cl, 1 tbl

ethod for development of oil deposit in carbonate reservoirs // 2597305
FIELD: oil and gas industry.SUBSTANCE: proposed method relates to oil industry, in particular to development of oil deposit in carbonate reservoirs without water-oil zones. Method for development of oil deposit in carbonate reservoirs, which involves construction of horizontal production and injection wells parallel to each other, arrangement of horizontal producing wells in lower part of productive formation, arrangement of injection horizontal wells in roof part of productive formation between production horizontal wells in horizontal projection, pumping displacement agent through injection wells and product extraction through production wells, before construction of wells, selecting section of deposit, which provides hydrodynamic connection between adjacent horizontal injection and production wells on entire thickness, during construction, selecting distance between adjacent horizontal shafts of producers and injectors directly proportional to permeability of rocks of section, wherein displacement agent is water with mineral content of not more than 4 g/l, which is pumped into productive formation with pressure higher than initial reservoir pressure of not more than 7 % of initial reservoir pressure, water pumping is stopped after reduction of intake capacity of horizontal injection wells to level, where low-mineralised water pumped into formation volume is higher than that of extracted formation fluid, then displacement agent used is 0.03-0.5 % aqueous solution of cellulose ester and 0.01-0.5 % aqueous solution of surfactant increasing in volume ratio of 1:1 to 1:5, and total volume of 30-50 % of initial oil content in formation, at pressure of pumping said aqueous solutions, 10-15 % higher than initial formation pressure, to recovery of initial reservoir pressure, after which cycles of injecting water with mineral content of not more than 4 g/l and aqueous solutions of polymers and surfactants is repeated.EFFECT: high efficiency of processing.1 cl, 1 ex, 2 dwg

Well treatment methods and systems // 2594915
FIELD: mining.SUBSTANCE: method for well treatment involving movement of solvent from first fluid source to first pump, movement of fluid from second wetting liquid source to second pump, feeding wetting liquid through polymer mixer using second pump, feeding polymer from polymer feed device in mixer polymer and merging into it wetting liquid and polymer to obtain a suspension containing insoluble polymer, combining suspension with solvent upstream of inlet into first pump and using first pump, suspension, combined with a solvent, in reservoir for gel, dissolving polymer to produce gel and use of gel in well treatment. Method for well treatment involving movement of solvent from first fluid source to first pump, displacement of fluid from second wetting liquid source to second pump, feeding wetting liquid through polymer mixer using second pump, feeding polymer from polymer feed device in mixer polymer and merging into it wetting liquid and polymer to obtain a suspension containing insoluble polymer, increased time of dissolution of polymer feed buffer agent in wetting liquid to combining wetting liquid and polymer suspension, combining with a solvent, using first pump, suspension, combined with a solvent, in reservoir for gel, dissolving the polymer to produce gel and use of gel in well treatment. Method for well treatment, including: using suction pump, feeding hydrating liquid from fluid source at suction line to suction pump and suction pump pressure line into a reservoir for gel using boost pump, feeding part hydrating liquid from suction line of suction pump as wetting liquid through inlet line looped circuit mixing to booster pump and therefrom via discharge line looped mixing circuit back to suction line of suction pump, supply of polymer from polymer feed device into mixer at discharge line looped circuit mixing and mixing it wetting liquid and polymer to obtain a suspension containing unhydrated polymer, for suspension at discharge line looped circuit mixing in hydrating liquid into suction line of suction pump, using a suction pump, feeding combined suspension and hydrating liquid in reservoir for gel using flow meter on pressure line of suction pump or on suction line of suction pump between discharge line looped circuit mixing and suction pump, determination of flow rate of combined suspension and hydrating liquid using process control device connected to control with polymer feed device and suction pump feed rate adjustment polymer based on flow rate or regulation of flow rate based on polymer feed rate, hydration of polymer to produce gel and use of gel in well treatment. Well treatment system comprising a reservoir for gel and polymer mixing subsystem, including first pump, suction line to first pump and pressure line from first pump, cross mixing circuit, including said second pump, an inlet line looped mixing circuit to second pump suction line of first pump and discharge looped mixing circuit from second pump back to suction line of first pump discharge line looped circuit mixing includes polymer mixer, polymer feed device, designed to supply polymer in polymer mixer, a flow meter on pressure line of first pump or on suction line of first pump between discharge line looped circuit mixing and first pump, process control device to control, binding polymer feed rate is provided by polymer feed device, with flow rate defined by flow meter. Invention is developed in subclaims.EFFECT: high efficiency of gel.21 cl, 2 dwg
 
2551125.
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