Method for control of flooding area of oil formations

FIELD: oil and gas industry.

SUBSTANCE: method for control of flooding area of oil formations includes oil extraction through production wells and pumping of margins of working agent and silicate in water phase with varying concentration of components trough injection wells. At that watering out of produced oil, capacity of injection wells, allowable pumping pressure and minimal pumping pressure are additionally checked. Pumping is started from injection wells of high capacity, connected hydrodynamicly to highly watered out production wells. At least one injection well is stopped till formation pressure is decreased by 6-24% from formation pressure in area of injection well. Pumping of working agent is started from composition of high-viscosity in quantity not less than 0.5 m3 per 1 m of productive formation with high capacity under pumping pressure exceeding minimal pumping pressure not more than by 20%, at which well accepts. Then margins of water solution of alkaline silicate and polymer are pumped in succession or jointly. Solution of alkaline silicate is used in quantity 0.1-15.0 wt %, and polymer is used in quantity 0.001-3.0 wt %, the other part of solution is water.

EFFECT: increasing oil recovery from formations.

4 cl, 3 ex

 

The invention relates to the oil industry, in particular to methods of regulating front of flooding of oil reservoirs, and may find application in the development of oil fields in progressive the water content of the produced fluid.

The problem is the most complete extraction of oil from the subsoil was and remains one of the key problems in the oil industry. For better coverage of the reservoir water flooding in thickness and area, and hence to increase oil recovery it is necessary to increase the resistance to movement of water in the washed high-permeability zones in an oil reservoir and thereby to direct the water from flooding in unreached preemptive more low-permeability oil-bearing interlayers. This will lead to the alignment of heterogeneity in permeability, excluding the development of irrigated high-permeability zone, used previously by injection wells displacement and the change of hydrodynamic flows in the reservoir. This result can be achieved by injection of the compositions limiting filtering through the zone of water injection in water-saturated (or completely washed out), previously involved in the development of oil reservoirs. Currently, the most common and widely used method of enhanced oil recovery in the development of oil, mostorod the deposits is flooding, the use of which contributes to the flooding of the produced oil. To limit filtering in flooded areas on the background flooding is used EOR methods using viscoelastic compositions, gels, polymer-based, alkaline-polymer composition, of silicate compositions and others.

A known method of regulating the oil reservoirs (U.S. patent No. 4332297, IPC EV 43/22, publ. 1982) through selective control of fluid flow through the zone of reservoir with high permeability by pumping an aqueous solution of the polymer, with subsequent injection of an aqueous solution of alkali metal silicate. The disadvantage of this method is low efficiency, especially at the later stages, as in a porous medium solutions are not mixed and do not constitute in whole or associates, nor any sediment that does not create effective resistance to the flow of water during subsequent flooding. In the production remains low.

A known method of regulating the waterflood front oil reservoirs (RF patent No. 2146002, IPC EV 43/22, 43/32, publ. 2000). Periodically through the injection well restored in the bottomhole zone of the formation pressure is injected aqueous solutions of alkali metal silicate and polymer, which before download mixed with saline water having salinity 5-180 g/L. The mixture is pumped rims, the transition from one rim to another exercise with increased pressure injection of 0.5 MPa or more, in each subsequent fringe reduce the amount of water-soluble polymer and silicate of alkaline metal, while the overall reduction of water-soluble polymer is in the range from 0.1 to 0.001 wt.%, the amount of alkali metal silicate in the range from 10 to 0.1 wt.%, salt water is the remainder to 100 wt.%. As the water-soluble polymer used polyacrylamide or cellulose ethers. However, the method is not efficient enough for high-permeability flushed zones, as by deposition from aqueous solutions of sodium silicate in the presence of saline water are formed of amorphous silicates of sodium, which is in the form of a colloidal system is pumped into the well and popping up in high-permeability zones, but the strength of such tubes is low, and they are quickly washed out during subsequent flooding, which leads to short-term efficiency of the method.

A known method of regulating the waterflood front oil reservoirs (RF patent No. 2290504, IPC EV 43/22, publ. 27.12.2006 year), including a stop at least one injection well and conducting technological exposure to recovery in a well bore zone of the current reservoir pressure is further filling rims bounding the filtering composition, when the pressure injection of not less than 1%, not exceeding the maximum allowable for each individual well, and the change in the concentration of the composition in each fringe, the composition is obtained by mixing the composition containing, in wt.%: the polymer is 0.005 to 2.0, sodium silicate is 0.1 to 10.0, the latex of 0.01 to 15.0, fresh water, rest, and saline water at a ratio of volumes, varying in the range of 1:1-1:30. Low technological efficiency is related to the fact that the formed precipitates are not high enough rheological and structural-mechanical properties.

The closest entity and the task at hand is a method of developing a petroleum reservoir (RF patent No. 2185505, IPC EV 43/22, publ. 20.07.2002, including the selection of oil through the production wells and the injection through injection wells operating agent and silicate in the aqueous phase. As a silicate is used, the particles of silicate gel, and as the aqueous phase a solution of a polymer in fresh or saline water. Silica-gel is used in an amount of 0.1-70,0%and the polymer is used in an amount of 0.01 to 2.0%. The injection of a suspension of silica gel in an aqueous solution of the polymer starts with the minimum concentrations of silicate-gel with low-pressure injection with a gradual increase in the concentration of silicate gel and pressure injection to reach the pressure of injection, previewsbeastie the discharge pressure of the working agent 0.5-3.0 MPa. After that, maintain a constant pressure when the reduction component concentration in the suspension. The disadvantage of this method is the high dependence of the filtration properties of the injected suspension from the flocculation ability of the polymer, facilitating the integration of the particles silicate gel and complicating injection in heterogeneous reservoir. In addition, the known method is not effective enough due to the lack of regulation of the injection process, premature overlap the previously unused preemptive saturated zones.

The technical objective of the proposal is to increase the oil recovery from the reservoir by limiting filter in flooded areas and connections in the development of oil-saturated layers previously untapped displacement, as well as the conservation of oil-saturated zone, the previously unused or slaboshchelocnam displacement from the restrictive filtering structures.

The technical problem is solved by a method of regulating the waterflood front oil formations, including oil extraction through production wells and injection through injection wells rims working agent and silicate in the aqueous phase with changing concentration of the components.

What is new is the fact that additionally verify the water content of the produced oil, the injectivity of injection wells, the stage is stime pressure injection, the minimum injection pressure, the injection start with viscoplastic injection wells, hydrodynamically connected with water-saturated production wells, stop at least one injection well to reduce reservoir pressure at 6-24% of the reservoir pressure in the area of the injection well, the injection start working agent with high viscosity compositions in an amount not less than 0.5 m31 m of the productive formation with high permeability in the injection pressure in excess of not more than 20% of the minimum pressure injection, which takes the well is then pumped sequentially or jointly rim of an aqueous solution of alkali metal silicate and the polymer used for the solution of alkali metal silicate in an amount of 0.1 to 15.0 wt.%, while the polymer is used in amounts of 0.001 to 3.0 wt.%, water the rest, starting with the lowest concentrations, with a gradual increase in the concentration, increasing the injection pressure to a pressure not exceeding 95% of the allowable pressure injection, when the ratio of the volume of pumping high viscosity of the composition and solution of alkali metal silicate and polymer is from 1:2 to 1:20 and subsequent processing bottom-hole zones, previously untapped or clubsdiscount preemptive.

Also new is the fact that as the viscosity of the composition is used formulations based on polymer concentration, wt.%: 0.5 to 3, or a composition based on a polymer with an appropriate binder.

Also new is the fact that as the polymer used polyacrylamide, or a cellulose ether, or a biopolymer, or polyoxyethylene.

Also new is the fact that you are doing the acid or organic solvents, or surfactants processing with subsequent resumption of flooding.

Analysis of patent and scientific literature has allowed to draw a conclusion about the absence of technical solutions containing the essential features of the claimed method that performs a similar task, therefore, the proposed method meets the criteria of "novelty" and "inventive step".

For the preparation of compounds using the following reagents:

- alkaline agents such as alkali metal silicate - glass liquid sodium (GOST 13078-81), hydroxide of alkali metals and others;

- polymers, such as polyacrylamide (PAA) - domestic on THE other 6-16-2531-81, THE 6-01-1049-81, THE 14-6-121-75, imported with molecular weight (3-15)·106for example, PAA brand DP9-8177 and others;

the cellulose ethers, such as acetylcellulose (TEV) grade Alfacell on THE 2231-013-32957739-01 CJSC polycell", polycell SC-1 600 brand and imported; sodium carboxymethylcellulose (CMC), for example, on THE 2231-002-50277563-2000, THE 2231-017-32957739-02, THE 2231-057-0750803-2002 and others;

the biopolymer, for example xanthan gum is a polymer of import or domestic production at THE 2458-002-50635131-2003;

- polyoxyethylene;

- staplers, such as chromium acetate, bichromate sodium, potassium borates, and others;

Surfactant (neonol AF-12, AF-10 and others), organic oil solvents, compositions based on inorganic and organic acids and others;

- water with a salinity of from 0.15 to 300 g/L.

The method consists in the following.

The volume of injection rims and the number of fringes viscosity of the composition and solution of alkali metal silicate and polymer depend on the physico-chemical and geological parameters (features) of the reservoir, the volume of injection rims can range from several tens to several hundred cubic meters. Additionally verify the water content of the produced oil, the injectivity of injection wells, the allowable injection pressure, the minimum pressure injection. Download start with viscoplastic injection wells, hydrodynamically connected with water-saturated production wells. Stop at least one injection well to reduce reservoir pressure at 6-24% of the reservoir pressure in the area of injection wells with a maximum underpressure zones selection of all high water-cut wells. The injection start working agent with high viscosity is oppozitsii not less than 0.5 m 31 m of the productive formation with high permeability in the injection pressure in excess of not more than 20% of the minimum pressure injection, which takes the well. Limits the filtering in high-permeability zones of the reservoir. When this saturated zone, previously untapped or clubsdiscount preemptive remain clean from the high viscosity of the composition. Then pumped sequentially or jointly rim solution of alkali metal silicate and the polymer used for the solution of alkali metal silicate in an amount of 0.1 to 15.0 wt.%, while the polymer is used in amounts of 0.001 to 3.0 wt.%, starting with the lowest concentrations, with a gradual increase in the concentration, increasing the injection pressure to a pressure not exceeding 95% of the allowable pressure injection, when the ratio of the volume of pumping high viscosity of the composition and solution of alkali metal silicate and polymer is from 1:2 to 1:20. As a high-viscosity compositions using formulations based on polymer concentration, wt.%: 0.5 to 3, or a composition based on a polymer with an appropriate crosslinker. As the polymer used polyacrylamide, or a cellulose ether, or a biopolymer, or polyoxyethylene. There is additional strengthening of the blocking screen high viscosity of the composition, and provides the possibility of increasing giving the value to the maximum possible, you need to work, not previously running intervals saturated zones. Then spend processing bottom-hole zones previously slaboshchelocnam or untapped displacement by the acid or organic solvents, or surfactants processing bottom-hole zones with subsequent resumption of flooding. According to the proposal, primarily from developing exclude high-permeability zone by injection of high-viscosity or gelling rims with subsequent injection with changing concentration of the components in limiting filtering the fringes of a solution of silicate of alkaline metal and polymer and processing the previously unused or slaboshchelocnam flooding zones. The method provides increased oil recovery from the reservoir by limiting filter in flooded areas and connections in the development of oil-saturated layers previously untapped displacement, as well as the conservation of oil-saturated zone, the previously unused or slaboshchelocnam displacement from the restrictive filtering structures.

Specific example

Example 1. The field developed oil reservoirs with the following characteristics: the depth of 1600-1800 m, thickness 2,0-6,0 m, reservoir pressure of 14.0-9,0 MPa, reservoir temperature 36°C, the porosity of 12.0-24.0%of the permeability of 100-1200 MDS, the density of oil in the surface conditions of 0.8 g/cm3. Development is 20 injection and 50 producing wells.

Additionally verify the water content of the produced oil, the injectivity of injection wells, the allowable injection pressure, the minimum pressure injection. Choose vysokopiaristye injection well, the hydrodynamically associated with water-saturated production wells, reservoir Sandstone with a porosity of 20%. The total injection wells 700 m3/day of water with a density of 1.05 g/cm3(mineralization 74 g/l) at a pressure of 8.5 MPa. Collector wells is represented by two layers, in which two seams with a total perforated with a capacity of 6.0 m (interlayer take: the first 0.5 m does not accept the second to 2.0 m accepts 0.5 m to 30 m3/day, third - 2.0 m accepts 2.0 m - takes 500 m3/day, fourth of 1.5 m - takes-1.0 m - 170 m3/day). The minimum pressure at which accepts bore 2.5 MPa. Allowable injection pressure of 11.0 MPa. Pressure in the area of the injection wells of 15.5 MPa. Stop the well to reduce reservoir pressure by 17% (to 13.0 MPa) from the reservoir pressure in the area of the injection wells. Injection well has an impact on three producing wells, the work is either stable with production watercut 95-98 wt.% on the same layers, that and injection. Pressure in the area of producing wells 12,0-14,0 MPa. The volume of the rim of a high-viscosity composition (ingredients: xanthan gum concentration of 0.5%, crosslinker (chromium acetate) 0,1%, water the rest) is calculated on the maximum power of the receiving interval of the injection well (500 m3/day-2.0 m) displacement at a distance of 6.0 m and the thickness of the rim of 1.5 m, which will be 15 m3(V=π(R21)-R22)Ln=3,14×(36-20,25)×1,5×0,2=14,84 m3not less than 0.5 m31 m of the productive formation with high permeability in the injection pressure in excess of 20% of the minimum pressure injection, which takes the well. The time of gelation of the composition, 72 h B high viscosity of the composition is pumped at a pressure not higher than 3.0 MPa to ignore maloprimetnaya layers with displacement in the reservoir. Then pumped sequentially rim of an aqueous solution of alkali metal silicate and polymer (total fringe of an aqueous solution of alkali metal silicate and the polymer is 60 m3with a lower viscosity, starting with the lowest concentrations, with a gradual increase in the concentration up to the pressure of injection, do not exceed 95% of the allowable pressure of 10.5 MPa). (Consistently pumped rim of an aqueous solution of alkali metal silicate 30 m3since con is entrala 0.1 wt.%, the injection pressure increases to 4.7 MPa, with a gradual increase in the concentration up to 0.3 wt.% with increasing pressure injection up to 6.9 MPa and the rim of the polymer in the amount of 30 m3starting with a concentration of 0.001 wt.%, the injection pressure is increased to 7.5 MPa, with a gradual increase of the polymer concentration of 0.1 wt.%, the injection pressure is increased to 10.5 MPa). The ratio of the volume of pumping high viscosity of the composition and solution of alkali metal silicate and the polymer is 1:4. Part to push into the reservoir water. After 5 days (at least) resumes flooding. Studies have shown that all the layers were taken evenly from 100 to 150 m3/day with a total pickup 470 m3/day at a pressure of 12 MPa. The method allowed us to increase the injection pressure, the result was connected previously untapped displacement of the layers, so that subsequent treatment of bottom-hole zone is not recommended.

Example 2. For well treatment method selects one injection well, the reservoir - seal off the Sandstone with a porosity of 14%. Additionally verify the water content of the produced oil, the injectivity of injection wells, the allowable injection pressure, the minimum pressure injection. Choose vysokopiaristye injection well, the hydrodynamically associated with water-saturated extracting the wells. The total injection hole 320 m3/day of water with a density of 1.15 g/ cm3at a pressure of 10 MPa. The collector well consists of a single layer, in which three interlayer, with a total perforated with a capacity of 4.0 m (interlayer take: first - 1.5 m - takes 20 m3/day, the second to 2.0 m accepts 2 m - 300 m3/day, the third 0.5 m does not accept the 2 m). The minimum pressure at which accepts bore, 4.5 MPa. Allowable injection pressure of 12.0 MPa. Pressure in the area of injection wells 18,5 MPa, well stopped to reduce reservoir pressure of 9.2% (up to 16.8 MPa). Injection well affects 2 producing wells, working steadily with production watercut 97-99 wt.% on the same layer, and injection. Pressure in the area of the wells of 15.5 MPa. The volume of the gel-forming composition (composition: PAA 0.5%, chromium acetate 0.05%, the water the rest) is calculated on the maximum power of the receiving interval of the injection well (300 m3/day - 2 m) displacement at a distance of 7 m and the thickness of the rim 2.0 m, which will be 25 m3(V=π(R21-R22)ln=3,14×(49-25)×2,0×0,14=21,10 m3in the amount of not less than 0.5 m31 m of the productive formation with high permeability in the injection pressure exceeding the 11% minimum injection pressure at which p is inimal well. The time of gelation 48 hours Gelling fringe is pumped at a pressure of not higher than 5.0 MPa to ignore maloprimetnaya layers with displacement in the reservoir. The composition is then pumped (in the amount of 150 m3with lower viscosity of the solution of alkali metal silicate (0.3 wt.%) with polymer (0.01 wt.%) with the changing concentration of components: solution of alkali metal silicate 5.0 wt.% with the polymer of 0.3 wt.% prior to pressure injection, not to exceed 95% of the allowable pressure of 11.5 MPa). The ratio of the volume of pumping high viscosity of the composition and solution of alkali metal silicate and polymer corresponds to 1:6. Part to push into the reservoir water. After 5 days (at least) resumes flooding. Studies have shown that the maximum acceleration of the host formation decreased to 30 m3/day, and began to take the broken seams: 100 and 150 m3/day with a total pickup 280 m3/day at a pressure of 10 MPa. The method allowed us to increase the injection pressure, resulting in the work connected previously untapped crowding out of productive layers, so that subsequent treatment of bottom-hole zone is not recommended.

Example 3. Choose an injection well, the reservoir Sandstone and siltstone with a porosity of 20%and 12%. The total injection capacity of the well 500 m3/day of water with a density of 1.00 g/cm3at a pressure of 5.5 MPa. Collector wells is represented by two layers with a total perforated with a capacity of 5.6 (Sandstone 3 m, air m 2.6 m). The reservoir is represented by siltstone, and will not accept. The minimum pressure at which accepts well, 6,0 MPa. Allowable injection pressure of 15.0 MPa. Pressure in the area of injection wells to 18.0 MPa, well stopped to reduce reservoir pressure by 6.6% (to 17.0 MPa). Injection well is influenced by four producing wells, working steadily with production watercut 90-95 wt.% on the same layers, and injection. Pressure in the area of producing wells 15,0-16,0 MPa. The amount of high-viscosity composition (composition: CMC 3.0%, and water the rest) is calculated on the maximum power of the receiving interval of the injection well (500 m3/day-2 m) displacement at a distance of 6 m and the thickness of the rim of 1.5 m, which will be 15 m3(V=π(R21-R22)ln=3,14×(36-20,25)×1,5×0,2=14,84 m3in the amount of not less than 0.5 m31 m of the productive formation with high permeability. The viscosity of the composition is 280 MPa·S. high Viscosity b is pumped at a pressure corresponding to the minimum pressure at which accepts a layer of not more than 6,0 MPa to ignore the second non-hosting layer. The composition is then pumped (in the amount of 300 m3with more than the low viscosity: a solution of silicate of alkaline metal (1.5 to 15.0 wt.%) with polymer (0.01 to 0.6 wt.%) with the changing concentration of the components together prior to pressure injection, not exceeding 95% of the allowable pressure (14 MPa). The ratio of the volume of pumping high viscosity of the composition and solution of alkali metal silicate and polymer corresponds to 1:20. The composition to promote the formation of water from flooding. Studies have shown that accepts the processed layer on the entire thickness of 250 m3/day and the second layer takes 50 m3/day at a pressure of 10 MPa. Recommended treatment of bottom-hole zone of the second layer by the injection of 0.1% surfactant solution brand Neonol AF-12. Processing allowed us to increase the permeability of the second layer up to 120 m3/day, and Sandstone up to 270 m3/day at a pressure of 10 MPa.

1. The method of regulation of the waterflood front oil formations, including oil extraction through production wells and injection through injection wells rims working agent and silicate in the aqueous phase with changing concentration of the components, characterized in that it further clarify the water content of the produced oil, the injectivity of injection wells, the allowable injection pressure, the minimum injection pressure, the injection start with viscoplastic injection wells, hydrodynamically connected with water-saturated production wells, stop at least one injection well to reduce reservoir pressure at 6-24% of the reservoir pressure in Nago area is Yateley well, the injection start working agent with high viscosity compositions in an amount not less than 0.5 m31 m of the productive formation with high permeability in the injection pressure in excess of not more than 20% of the minimum pressure injection, which takes the well is then pumped sequentially or jointly rim of an aqueous solution of alkali metal silicate and the polymer used for the solution of alkali metal silicate in an amount of 0.1 to 15.0 wt.%, while the polymer is used in amounts of 0.001 to 3.0 wt.%, water - the rest, starting with the lowest concentrations, with a gradual increase in the concentration, increasing the injection pressure to a pressure not exceeding 95% of the allowable pressure injection, when the ratio of the volume of pumping high viscosity of the composition and solution of alkali metal silicate and polymer is from 1:2 to 1:20 and subsequent processing bottom-hole zones, previously untapped or clubsdiscount preemptive.

2. The method according to claim 1, characterized in that as the viscosity of the composition use composition based on polymer concentration, wt.%: 0.5 to 3, or a composition based on a polymer with an appropriate binder.

3. The method according to claim 2, characterized in that the polymer used as polyacrylamide, or a cellulose ether, or a biopolymer, or polyoxyethylene.

4. The method according to claim 1, characterized in that the wasp is estlat acid treatment of bottom-hole zones with subsequent resumption of flooding, or organic solvents, or surfactants.



 

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16 cl, 15 ex, 15 dwg

FIELD: process engineering.

SUBSTANCE: invention relates to underground processing of formations. Proposed method comprises preparing fluid for processing formation containing water and copolymer reducing friction consisting of acrylamide in amount of 80 wt % to 90 wt % and acrylic acid in amount of 10 wt % to 20 wt %, and feeding it into underground formation. It comprises also preparing copolymer oil emulsion containing water, fluid non-miscible with water and aforesaid copolymer, combining emulsion with additional water for producing water fluid for formation processing, inverting emulsion so that said copolymer is released into water fluid to be forced into underground formation. proposed method comprises preparing copolymer oil emulsion containing water, fluid non-miscible with water containing mix of paraffin hydrocarbons and naphthenic hydrocarbons, emulsifier containing diethanolamide of fat acids of tall oil, monooleat of sorbite polyoxyethylene and sorbite monooleat, above specified copolymer and ammonium salt, 4-metoxyphenol and etoxylated alcohol C12-C16, combining said emulsion with additional water, inverting said emulsion so that copolymer reducing friction is forced into formation.

EFFECT: higher efficiency of reducing friction.

23 cl, 1 ex, 3 tbl

FIELD: chemistry.

SUBSTANCE: liquid composition contains the following: suspension on oil basis, which includes base oil, organophilic clay, polar activating agent, wetting agent, and composition improving the operability in winter conditions, which contains one or many composite monoesters of polyols and/or composite diesters of polyols. Composition is meant for hydraulic fracturing of underground formation, removal of combined wafer from productive underground formation. Hydraulic fracturing method of underground formation involves pumping to the formation under the pressure which is enough for fracturing, liquid for fracturing, which contains propping agent and suspension on oil base, which includes base oil, organophilic clay, polar activating agent, wetting agent and the above composition, or according to the other version - fracturing liquid containing the above suspension, and pumping to the formation subjected to fracturing under pressure which is enough for protection of cracks against joining of carrying liquid with propping agent. Production method involves circulation and/or pumping to production well of the liquid including the above suspension.

EFFECT: improving operability in winter conditions.

25 cl, 18 tbl, 3 ex, 4 dwg

FIELD: oil and gas industry.

SUBSTANCE: methods involving the use of composition for slow increase in adhesive ability, which includes water agent for increasing the adhesive ability and activating agent of slow separation of the acid which is used for stabilisation of particles and minimisation of particle migration inside underground formation. Invention has been developed in dependent claims.

EFFECT: improvement of operating flexibility and controllability of operations and mechanical elasticity of stabilised masses.

20 cl, 1 ex

FIELD: oil-and-gas production.

SUBSTANCE: proposed method comprises injection of water solution of biopolymer-silicate composition via injection well into bench and extracting oil via production well. Note that silicate reagent-to-biopolymer ratio equals 1-0.25. Note here that injection is performed by pattern method from multiple-well pump station into group of injection wells at a time in cycles, 3-4 yearly, amount of said solution making 10 vol. % of threshold volume during first year of threshold volume, 15 vol. % during second year, and 20 vol. % of bench water-saturate section during third year.

EFFECT: higher efficiency, lower costs.

1 tbl, 1 ex

FIELD: oil-and-gas production.

SUBSTANCE: proposed fluid to be used in oil fields comprises: 0.001 wt % to 0.5 wt % of surfactant reducing drag and at least one activator of drag reduction selected from the following group: polymer drag reduction activators selected from the group comprising low-molecular water-soluble polymers and copolymers containing at least one aromatic cycle, or their mixes with monomer drag reduction activator. Note here that said fluid allows drag reduction percentage making at least 20%. Proposed method of regulating clay swell in brine-free well shaft comprises: preparing above fluid suspending reduction agent and injecting it into well shaft. Method of processing in-situ in oil filed whereat said suspending reduction agent is prepared, injected into well shaft to reach drag reduction percentage equal to at least 20%. Invention is developed in dependent claims.

EFFECT: improved viscosity and power to suspend solid substances at low surfactant concentrations.

20 cl, 33 ex, 4 tbl, 36 dwg

FIELD: oil-and-gas production.

SUBSTANCE: proposed composition comprises surfactant, i.e. organic residue of ammonium sulphate production from waste sulphuric acid produced in sulphuric-acid alkylation of isoalkanes with olefins in amount of 2-10 wt %, water making the rest.

EFFECT: availability and low costs, high oil-sweeping property.

1 ex, 1 tbl

FIELD: gas and oil production.

SUBSTANCE: method involves loading of working medium under pressure through injection wells and oil extraction through production wells. First, sodium silicate solution in water at 1:2 - 1:5 respective ratio with 0.04-0.06% polyacrylamide added in the volume of 5-30 m3 is pumped into at least one injection well. Then 1-5 m3 of spacer fluid is pumped in sequence. Further, 5-30 m3 of 5% aqueous solution of calcium chloride is pumped with 0.003-0.007 vol.% salt deposition inhibitor "INSAN" added.

EFFECT: enhanced development efficiency by increased field coverage due to available power resource during field flooding.

3 cl, 1 ex

FIELD: mining.

SUBSTANCE: fluid for treatment of wells contains a water-based liquid, a crosslinking agent and a gel-forming agent, containing a crosslinked polymer and a non-crosslinked biopolymer, where a molecule of the latter consists only of glucose or has the main chain, comprising a glucose link and a linear or cyclic monosaccharide link of the specified type, and ratio of a biopolymer to a crosslinked polymer makes 0.05-1:1. The method for treatment of a part of an underground bed includes provision of the above-specified liquid and its injection into a well shaft that penetrates into an underground bed. The above-specified method, where the liquid for treatment comprises a crosslinked polymer and diutan with diutan ratio to crosslinked polymer equal to 0.05-1:1.

EFFECT: improved rheological properties and temperature stability of gel-forming agents.

21 cl, 3 ex, 3 tbl, 4 dwg

FIELD: oil and gas production.

SUBSTANCE: invention provides a method of developing oil pool allowing production of oil from water-rich oil reservoir under difficult geological-tectonic conditions in the last development stage. In the method, neutral salt of carbonic acid and acid solution are forced into formation through injecting well with water generated in gas-liquid fringe created in formation. After pumping of neutral salt of carbonic acid, acid solution is pumped by portions alternating with water pumping. Before pumping of acid solution portions beginning by at least second portion, selective insulation of high-permeable formation intervals is performed. Aforesaid neutral salt of carbonic acid utilized is sodium carbonate aqueous solution or aqueous suspension of calcium carbonate and aforesaid acid solution is aqueous hydrochloric acid solution. Selective insulation of high-permeable formation intervals involves use of freshly prepared controllable viscoelastic composition containing water-soluble acrylic polymer, cross-linking agent, thermal stabilizer, surfactant, and water. Summary concentration of acid solution is determined from concentration of neutral salt of carbonic acid on the base of stoichiometric proportions.

EFFECT: increased efficiency of maintaining formation pressure and thereby oil recovery of formation due to leveled displacement front and reduced probability of the rupture of formation rock backbone, and simplified control of phase state of gas-liquid fringe by changing pressure of pumped acid solution portions.

8 cl

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