RU2460874C1 - Development method of non-homogeneous oil formation - Google Patents

Abstract

FIELD: oil and gas industry.

SUBSTANCE: method for development of heterogeneous oil stratum includes sequential pumping of two components into strata interacting between themselves and oil extraction, sequential pumping of two components into strata is done, at least, into one well in the ratio 1:1, note that the first component pumped is water solution of aluminium sulphate - Al₂(SO₄)₃, and the second component pumped is heavy resin of pyrolysis, these components in the course of interaction in formation form plugging viscous emulsion, as the said water solution there used is 10-40% solution. Invention is developed in dependent claims.

EFFECT: increase of oil production efficiency from transition zones of oil strata from formations mixed with water and formation water due to reduction of water permeability and increase of oil permeability.

4 cl, 3 tbl, 5 ex

Description

The invention relates to the oil and gas industry, in particular to the development of oil reserves from transition zones of oil deposits, namely, to increase oil recovery from transition zones of oil deposits.

A known method of developing a waterlogged oil reservoir, including pumping a working agent through injection wells, taking oil through production wells (RF Patent No. 2387814, ЕВВ 43/20, 22, published on 04/27/2010).

The disadvantage of this technical solution is the low oil displacing properties, since the solution is prepared in fresh water, and fresh water destroys the reservoir, which leads to the removal of sand into the wellbore, the formation of sand plugs and thereby significantly reduce the productivity of the well, the compositions used during the operation of the well do not erode and remain in the formation, clogging it, and each subsequent injection of the insulating composition leads to a significant decrease in the thickness of the productive formation and thereby to substantial ennomu reduce well productivity up but its complete stop.

The closest technical solution is a method of developing a heterogeneous oil reservoir, including the sequential injection of two components into the reservoir, oil extraction (RF Patent No. 2401939, ЕВВ 43/22, publ. 20.10.2010, prototype).

The disadvantages of this technical solution are the low oil-displacing properties, the complexity of preparing the composition used and the difficulty, and sometimes the impossibility of determining the polycondensation time of the system along the strike of the formation, the compositions used during the operation of the well do not erode and remain in the formation, clogging it, and each subsequent injection of the insulation composition leads to a significant decrease in the thickness of the reservoir and thereby to a significant decrease in well productivity up to its complete SETTING.

The proposed method for developing a heterogeneous oil reservoir will eliminate the above disadvantages, in addition, it will increase the efficiency of oil production from transition zones of heterogeneous oil reservoirs (oil reservoirs, from mixed reservoirs with oil and produced water) by reducing water permeability and increasing oil permeability, by eliminating behind-the-casing and in-situ flows of oil deposits, increasing the hydrophobization of the formation rock surface in order to connect stagnant and weak areas of the reservoir, isolating water inflows into oil wells, for this the method of developing a heterogeneous oil reservoir involves the sequential injection of two components interacting with each other, the selection of oil, while the sequential injection of two components into the reservoir is carried out at least in one well in 1: 1 ratio, the first being injected with an aqueous solution of aluminum sulfate, and the second is injected with a heavy pyrolysis resin, which, when interacting with each other in the formation, form a plugging elm emulsion, and the sequential injection into the reservoir of two components is carried out at least in one injection well, and the selection of oil is carried out from at least one producing well, and the sequential injection into the reservoir of two components is carried out at least in one production well, and at least one injection well, and after a predetermined time interval, oil is taken from at least one production well, and as an aqueous solution of aluminum sulfate Al ₂ (SO ₄ ) ₃ and use a 10-40% aqueous solution of aluminum sulfate Al ₂ (SO ₄ ) ₃ .

It is known that during the exploitation of oil fields in Western Siberia wells often reveal oil-saturated zones of deposits (formations). At the opening of these deposits, two-phase inflows are obtained with the outrunning movement of water from the reservoir. Traditional methods of oil production are ineffective and often do not give positive results.

The proposed method for the development of a heterogeneous oil reservoir comprehensively affects the well zones of production and injection wells.

The sequential injection into the reservoir of two components is carried out at least in one well, namely, at least one injection and at least one production well, or at least one injection well, of necessity, having previously determined the hydrodynamic connection between the injection and production wells, and oil production without produced water is carried out from at least one production well.

After determining the hydrodynamic connection between the wells, a selection of sections and wells is carried out, on which two components and the oil production should be sequentially injected into the reservoir. At the same time, the overall productivity of the site and the well must be taken into account.

The injection of two components into the reservoir is carried out in a ratio of 1: 1, while the first is injected into the reservoir an aqueous solution of aluminum sulfate Al ₂ (SO ₄ ) ₃ , and the second is injected with a heavy pyrolysis resin (hereinafter referred to as TSP), in the process interactions, a highly viscous clogging emulsion is formed.

The obtained highly viscous clogging emulsion passes oil through itself and additionally “draws out” - it is washed from the reservoir, and it blocks the produced water, that is, it temporarily isolates the channels and pores in the FZZZ containing produced water, which drastically reduces the permeability of the produced water to zero .

In addition, the highly viscous plugging emulsion self-destructs for a certain time, that is, it is disposed of, and thereby does not pollute the reservoir.

Also, due to the washing properties of the obtained highly viscous plugging emulsion, they provide enhanced oil recovery from MPS by aligning the injectivity profile of injection wells with a simultaneous increase in oil displacement from MPS of producing wells.

TSP - fraction boiling at temperatures from 180-190 to 350-360 ° C, is a product of the pyrolysis of gases, gasolines, gas oils. The heavy pyrolysis resin consists of condensed bi-, tri-, tetracyclic aromatic hydrocarbons, contains up to 20% highly aromatic resins and asphaltenes. The resins and asphaltenes contained in the PMT are not analogues of petroleum resins and asphaltenes, but are essentially polycyclic aromatic hydrocarbons. Substituents of aromatic structures contain significant amounts of alkene bonds, which determines the high reactivity of the components. Externally, TSP is a homogeneous flowing liquid of a dark green color (green oil). The average density of 1040-1080 kg / m ³ . TSP has a low freezing temperature (-45 ° C).

As an aqueous solution of Al ₂ (SO ₄ ) ₃ , a 10-40% aqueous solution of Al ₂ (SO ₄ ) _{3 is used} .

The interaction of an aqueous solution of Al ₂ (SO ₄ ) ₃ with TSP along the strike of the formation allows processing of the productive formation at a considerable distance from the wellhead (from 10 to 100 m, depending on the task, injection volume, formation thickness, porosity, etc. .).

The proposed method for the development of a heterogeneous oil reservoir is as follows.

Before carrying out work, tubing is lowered into at least one well.

Two components are sequentially pumped through the tubing, lowered to the middle of the perforation interval, into the PSZ of at least one well, one of them is a 10-40% aqueous solution of aluminum sulfate Al ₂ (SO ₄ ) ₃ , and the second component is TSP , which, when interacting with each other, form clogging channels, pores in the PNZZ are a highly viscous emulsion.

Components Al ₂ (SO ₄ ) ₃ and TSP are injected in a 1: 1 ratio, but in a given volume, which is determined depending on the effective thickness of the reservoir, geological structure and stratification of the reservoir, as well as on the features of the development system of the reservoir and the distance between the injection and producing wells.

Components Al ₂ (SO ₄ ) ₃ and TSP are successively brought to the tubing shoe, close the annulus and push Al ₂ (SO ₄ ) _{3 first} , then TSP into the reservoir.

The injected Al ₂ (SO ₄ ) ₃ and TSP components into the well formation, when interacting with each other, form a highly viscous plugging emulsion, which prevents the penetration of formation water into the wellbore, but facilitates the unhindered penetration of oil without formation water, and also includes previously unused development for oil interlayers of the reservoir by treating the washed out - washed with reservoir waters or injected squeezing technological fluids of the zone of the reservoir.

To optimize the consumption of TSP and Al ₂ (SO ₄ ) _{3, the} work on the proposed method on the oil deposits can be carried out simultaneously (synchronously) by affecting the bottom-hole zone of both injection and production wells from the very beginning.

With the sequential injection of FDZ in wells, temporary isolation of the reservoir water inflow occurs. With an increase in the content of produced water in the production of a well, the work on sequential injection of the claimed components is repeated many times.

And what is important in this case, unlike other methods, there is no decrease in the effective thickness of the formation.

By monitoring the content of produced water in the production of the well, determine the need and frequency of sequential injection of the claimed components.

In injection wells, when the front of the sequential injection of Al ₂ (SO ₄ ) ₃ and TSP is advancing, the injectivity profile is aligned, because first of all, highly permeable layers of the oil reservoir are filled. At the same time, the resulting emulsion-like mass, which does not harden, but in the process of injection, as it penetrates deeper into the reservoir, it is destroyed, i.e. it is utilized, but the effective thickness of the reservoir is maintained.

By monitoring the injection of water by removing the injectivity profiles, determine the need and frequency of repetition of the operation for the sequential injection of the claimed components.

In laboratory conditions, a series of experiments was carried out with preliminary injection of a 10-40% aqueous solution of Al ₂ (SO ₄ ) ₃ into the sample. The effect of hydrophobization of the interstitial surface of the reservoir in the transition zone of the formation — the PZP — was achieved by increasing the viscoelastic properties of a highly viscous gel — an emulsion formed by the interaction of TSP and an aqueous solution of Al ₂ (SO ₄ ) ₃ .

Laboratory tests were carried out on the installation UIPK-1M in conditions as close as possible to reservoir conditions.

In the course of the experiments, rock samples with different filtration-capacitive properties of various deposits of Western Siberia were used. The experiments were carried out in the following sequence: the core was extracted and its absolute permeability was determined.

After the core was saturated with produced water in the volume of two pore spaces, a solution of 20 g / l sodium chloride NaCl was used as produced water. The core was placed in the UIPK-1M installation and the relative permeability of the formation water was determined.

Then, during the tests, an aqueous solution of Al ₂ (SO ₄ ) _{3 was} sequentially pumped into the sample, for example, a 20% aqueous solution of Al ₂ (SO ₄ ) ₃ , and then TSP in a ratio of 1: 1 in a given volume, the core was kept under pressure for two hours at a temperature of + 70 ° C and determined the relative permeability of the formation water.

The test results are shown in table 1.

Tests have shown that the sequential injection of an aqueous solution of Al ₂ (SO ₄ ) ₃ and TSP into the reagent samples significantly reduced the permeability in the formation water of the reservoir, for example,

for samples with formation water permeability of the order of 100 μm ² × 10 ^{-3, the} permeability in formation water as a result of the influence of TSP and 20% aqueous solution of Al ₂ (SO ₄ ) ₃ decreased by 75%,

and for samples of the order of 4.5 μm × 10 ^-3 - by 90%.

Next, experiments were conducted on samples with formation water permeability of 15 μm ² x 10 ^-3 , which showed that the use of an aqueous solution of Al ₂ (SO ₄ ) ₃ and TSP on low-permeability samples of formation water is twice as effective.

The results are shown in table 2.

The next step was laboratory studies to determine the displacement ability of oil. For this, two identical samples were taken and studies were carried out according to the following procedure.

To completely saturate the core samples with oil and evenly distribute in the pore space, the oil was filtered in the amount of two pore volumes and kept UIPK-1M for 5 hours until the sample was completely saturated. This technology allows you to maximize bring laboratory simulation to the real process of oil saturation and guarantees the reliability of the results.

In the studies, a NaCl sodium chloride solution with a salinity of 20 g / L was used as a displacing agent, which corresponds to the salinity of the pore solution.

Oil displacement by formation water was carried out by pumping the latter into the reservoir model. The flow rate of the supplied water was determined from the need to maintain the speed of advancement of the oil-water front, which takes place in real conditions and installation capabilities.

After the oil displacement was completed, the reservoir model was cooled for 5 hours and maintained at room temperature of 22 ° C for 4 hours. Immediately after unloading the core holder, the samples were examined for residual oil content. The residual oil saturation of the samples was determined by the rotor method.

For one of the models, the experiment was carried out according to the described method, and for the second, after displacement was completed, a 20% aqueous solution of Al ₂ (SO ₄ ) ₃ and TSP were pumped sequentially to the level of residual oil saturation in a predetermined volume equal to 30% of the pore volume of the reservoir in a ratio of 1: 1, after which the water filtration was again switched on, and the oil displacement process continued until the pressure drop stabilized, which indicated the cessation of oil displacement.

The results of these experiments are presented in table 3, from the results of laboratory tests it can be seen that oil displacement - oil production increased to 15%.

The laboratory results presented in tables 1, 2, and 3 showed that the sequential injection of an aqueous solution of aluminum sulfate and heavy pyrolysis resin into at least one well in a ratio of 1: 1 improves the efficiency of oil production from transition zones of heterogeneous oil deposits ( oil reservoirs, from mixed reservoirs with oil and produced water) by reducing water permeability and increasing oil permeability and by eliminating behind-the-casing and in-situ flows of oil deposits.

The proposed method for developing a heterogeneous oil reservoir was tested in field conditions (in the wells of the Tyumen region).

Example 1. Komsomolskoye field.

A gas-oil deposit is being developed located in the transition zone with the following characteristics:

the reservoir-sludge reservoir is located at a depth of 2166-2181 m, the initial reservoir pressure is 23.4 MPa, the reservoir temperature is 69 ° C, the thickness of the reservoir from 10 to 15 m, the permeability from 198 to 250 μm ² × 10 ^-3 , oil saturation - 61-72%, oil density - 0.85 g / cm ³ , porosity 21.8.

The deposit has been developed since 1988.

The current water cut in the reservoir is 51%.

Treatment at 7 production wells and 2 injection wells is carried out by sequential injection of an aqueous solution of A1 ₂ (SO ₄ ) ₃ and TSP in a ratio of 1: 1. To do this, stop the production well, the average water cut for 7 wells 76%. The average flow rate for 7 producing wells is 46.6 m ³ / day. A productive layer located in the transition zone (in the zone of undersaturation) was opened by a well. Through the tubing, lowered into the production well to the upper holes of the perforation interval, a 20% aqueous solution of Al ₂ (SO ₄ ) _{3 is} pumped into the volume of 2 m ³ / m of the productive formation using direct circulation method, i.e. 30 m ³ , at an injection pressure of 8.0 MPa with a flow rate of 10 m ³ / h, bring a 20% aqueous solution of Al ₂ (SO ₄ ) ₃ to the tubing shoe and push the solution into the formation. After 3 hours, in order for the productive formation to be saturated with an aqueous solution of Al ₂ (SO ₄ ) ₃ , TSP is pressed in the volume of 2 m ³ / m of the productive formation, i.e. 30 m ³ , at an injection pressure of 10 MPa with a flow rate of 10 m ³ / h into the reservoir, and at the same time, Al ₂ (SO ₄ ) ₃ and TSP are sequentially injected in a ratio of 1: 1 in 2 injection wells.

A day later, they begin to select oil from production wells.

As a result of the work, the average water cut for 7 producing wells decreased to 57.8%. The average fluid flow rate in producing wells decreased to 40.6 m ³ / day. The average daily oil production rate increased from 11.2 to 17.1 tons / day.

The average increase in oil production per 1 production well was 5.9 tons / day.

Example 2. Tarasovskoye field.

The developed layer is confined to a structural-lithological type trap, has a clinoform structure and is composed of oblique sandy-siltstone deposits:

the reservoir is located at a depth of 2950-3015 m, the initial reservoir pressure is 28.2 MPa, reservoir temperature is 96 ° C, the thickness of the reservoir is from 0 to 32 m, the stratification coefficient is 4, the porosity is 20, and the permeability is from 10 to 100 microns ² × 10 ^-3 , oil saturation - 75%, oil density - 0.82 g / cm ³ .

The deposit has been developed since 1986.

The current water cut for deposits is up to 90%.

The water content of the reservoir is due to the injected water. At the initial stage of development of the deposit, the water cut was from 10 to 15%, at the moment, the water cut is up to 90%. In this regard, the sequential injection into the reservoir Al ₂ (SO ₄ ) ₃ and TSP in the ratio 1: 1 is carried out only for injection wells: at 7 injection wells, and oil is extracted at 9 producers. To do this, stop the injection well. A well with a heterogeneous terrigenous reservoir has been opened by a well. In the reservoir, 2 layers are distinguished, the average permeability of one layer is 16 μm ² × 10 ^-3 , and the other 100 μm ² × 10 ^-3 . The injection well is equipped with a tubing string. Through tubing, lowered into each injection well to the upper holes of the perforation interval, a 20% aqueous solution of Al ₂ (SO ₄ ) _{3 is} pumped into the volume of 2 m ³ / m of the productive formation using direct circulation method, i.e. 30 m ³ , at an injection pressure of 11.0 MPa with a flow rate of 10 m ³ / h, bring a 20% aqueous solution of Al ₂ (SO ₄ ) ₃ to the tubing shoe and push it into the reservoir. After 3 hours, in order for the formation to be saturated with a solution of Al ₃ (SO ₄ ) ₃ , TSP is pressed in the volume of 2 m ³ / m of the productive formation, i.e. 30 m ³ , at an injection pressure of 14.0 MPa with a flow rate of 10 m ³ / h into the reservoir, and simultaneously with the process of pushing the TSP into the reservoir through the injection well, oil is withdrawn from the producing well.

As a result of the work, the average water cut for 9 wells decreased from 89.4% to 72.2%. The average fluid flow rate in wells decreased from 68.4 to 51.3 tons / day. The average daily oil production rate increased from 7.2 to 14.3 tons / day. The average increase in oil production per well amounted to 7.1 tons / day.

Example 3

In order to increase oil recovery, injections were injected into injection well No. 6 of the Purovsky oil and gas region, for which 15 m ³ 20% aqueous solution of Al ₃ (SO ₄ ) ₃ was injected into the perforation interval and after 15 hours 15 m ³ Tsp.

With the created repression, the total throttle response is 250 m ³ / day. The injected water is generally taken at perforated intervals - about 93% of the total volume. Prior to injection of the insulation composition, the perforated interval (2875.6-2891 m) of the injected water was weakly taken up to 27%. Artificial slaughter - tight.

The result of alignment of the injectivity profile after treatment turned out to be an increase in oil production in producing wells to 35-40 thousand tons per year, the duration of the effect was 30 months.

Example 4

At production well No. 2 of the Purovsky oil and gas region in the range of 2495-2507 m, work is underway to increase the oil recovery of the reservoir. The treatment is carried out simultaneously on the injection well, having a hydrodynamic connection with the producing well, and the producing well by sequentially injecting an aqueous solution of Al ₂ (SO ₄ ) ₃ and TSP in a ratio of 1: 1.

A total of 16 m ^{3 of a} 30% aqueous solution of Al ₂ (SO ₄ ) ₃ and 16 m ^{3 of} heavy pyrolysis resin (TSP) were injected into both wells.

Prior to the work, the producing well worked with the following parameters:

Q _w = 30.5 m ³ / day;

Q _n = 16 t / day;

the water content was 46%.

After the work, the producing well worked with the following parameters:

Q _w = 26.5 m ³ / day;

Q _n = 26.1 t / day;

water cut was 1.8%.

Additional oil production amounted to 10.1 tons / day.

Example 5

At production wells No. 4 and 5 of the Purovsky oil and gas region in the range of 2881-2895 m and 2488-2490 m, work is underway to increase oil recovery in productive formations.

The treatment is carried out simultaneously on injection well No. 3, which has a hydrodynamic connection with production wells, and production wells by sequentially injecting an aqueous solution of Al ₂ (SO ₄ ) ₃ and TSP in a ratio of 1: 1.

A total of two production wells were sequentially injected with an aqueous solution of Al ₂ (SO ₄ ) ₃ and TSP in the ratio 1: 1 (16 m ^{3 of a} 30% aqueous solution of Al ₂ (SO ₄ ) ₃ and 16 m ^{3 of} heavy pyrolysis resin).

In injection well No. 3 of the Purovsky oil and gas region in the perforation interval 2875.6-2891.0 m, an aqueous solution of Al ₂ (SO ₄ ) ₃ and TSP were pumped sequentially in a ratio of 1: 1 (10 m ^{3 of a} 10% aqueous solution of Al ₂ (SO ₄ ) ₃ and 10 m ³ TSP).

Prior to launching injection well No. 3 into operation at production well No. 4, which has a hydrodynamic connection with injection well No. 3, the main operating parameters were determined, which were as follows:

Q _w = 54 m ³ / day;

Q _n = 14.38 t / day;

the water content was 73.73%.

After injection into the injection well No. 3 of an aqueous solution of Al ₂ (SO ₄ ) ₃ and TSP in the ratio 1: 1 and putting it into operation, production well No. 4 worked with the following parameters:

Q _W = 40.9 m ³ / day;

Q _n = 19.3 t / day;

the water content was 52.8%.

Additional oil production at production well No. 4 was 5 tons / day.

Prior to launching injection well No. 3 into operation at production well No. 5, which has a hydrodynamic connection with injection well No. 3, the main operation parameters were determined, which were as follows:

Q _w = 81.8 m ³ / day;

Q _n = 2.97 t / day;

the water content was 96.37%.

After pumping into the injection well No. 3 an aqueous solution of Al ₂ (SO ₄ ) ₃ and TSP in a ratio of 1: 1 and putting it into operation, production well No. 5 worked with the following parameters:

Q _w = 61.4 m ³ / day;

Q _n = 91.3 t / day;

the water content was 85.2%.

Additional oil production at production well No. 5 was 6.1 tons / day.

The proposed technical solution allows to increase the efficiency of oil production from transitional and heterogeneous oil deposits (oil reservoirs, from mixed reservoirs with oil and produced water) by increasing the reservoir properties (FES) of the reservoir, increasing the hydrophobization of the formation rock surface by connecting stagnant and poorly drained formation zones, isolating water inflow into oil wells, without clogging the reservoir and using available components.

Table 1 The results of determining water permeability during physical modeling of waterproofing works on core samples of a productive formation Sample No. Well number The interval of coring, m Plast Permeability, μm ² × 10 ^-3 Porosity,% Water retention method
% The initial permeability to water, microns ² × 10 ^-3 The final permeability to water, microns ² × 10 ^-3 Coeff. recovery% Note Model one 35 21.8 47.2 15.3 1.27 0,083 10% 262-93 1214 1732-1749 AB ₂ Al ₂ (SO ₄ ) ₃ Model 2 eighteen 23,4 42.3 10.6 0.931 0,088 Tsp 173-93 3318 1741-1754 AB ₂ Model 3 52 26.1 35.7 16,4 2,36 0.144 70 ° C 436-93 1034 1713-1725

Model four 68 22.9 30.3 19.1 2,473 0.129 10 MPa 381-93 2720 1804-1815 AB ₆ Model 5 twenty% 284-93 1125 1743-1754 AB ₂ 102 24 34.6 45.9 7.73 0.168 Al ₂ (SO ₄ ) ₃ Model 6 Tsp 456-93 1075 1714-1723

45 25.7 37.7 15.8 1.77 0.11 Model 7 70 ° C 205-93 3327 1743-1754 AB ₂ 4,5 20.3 49.9 2.96 0.213 0,07 Model 8 10 MPa 195-93 3327 1743-1754 AB ₂ 17 21,2 41.3 9,4 0.895 0,095 Model 9 327-93 2507 1808-1816 AB ₆ 71 24.1 31.5 18.2 2,251 0.124 Model 10 1807-1816 AB ₆ 67 23.7 36,2 24.8 1,036 0,042 thirty% 335-93 2541 Al ₂ (SO ₄ ) ₃ Model eleven 1742-1754 AB ₂ 16 22.1 44.5 11,2 0.725 0,065 Tsp 182-93 3345 Model 12 1743-1754 AB ₂ 94 24.6 33.1 46.7 4.43 0,094 70 ° C 271-93 1139 Model 13 1716-1726

42 26.3 38.9 14.5 0.561 0,0389 10 MPa 448-93 1059

table 2 The effect of injection of TSP on the permeability of core samples when filling the pore space with a solution of NaCl and Al ₂ (SO ₄ ) ₃ No. Interval Porosity, Water Pron by Drop Consumption, Reagent sample selection % spos.,% gas, m pressure, Pa cm ³ / min 251 1743 22.1 43.2 fifteen 0.01 199 0.0472 NaCl 1754 0.03052 0.121 NaCl 1.3 0.0185 TPN 0.055318 0.0185 NaCl 0.147 0.0472 NaCl Impact permeability reduction 12.26 250 1743 21,2 43,2 fifteen 0.00545 0.0472 Al ₂ (SO ₄ ) ₃ 1754 0.01417 0.121 Al ₂ (SO ₄ ) ₃ 0.0327 0.307 Al ₂ (SO ₄ ) ₃ 1.2 0.0185 TPN 0.481 0.121 Al ₂ (SO ₄ ) ₃ 0.18 0.0472 Al ₂ (SO ₄ ) ₃ Impact permeability reduction 25.69

Table 3 The results of laboratory studies to determine the residual oil saturation after processing TSP Sample No. No. of wells Sampling interval Plast Permeability
capacity, m Poris
toast,% Water retention. able.% Initial oil.,% Residual oil.,% Coeff. crowding out
% Note 237-93 1125 1743-1754 AB ₃ + 2AB ₁ 16 21.9 43.8 56.2 27.8 0.5053381 TSP rims injection 238-93 3327 1743-1754 AB ₃ + 2AB ₁ 16 22 42.5 57.5 36.5 0.3652174 Conventional extrusion
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Claims (3)

1. A method of developing a heterogeneous oil reservoir, comprising sequential injection of two components interacting with each other, and oil selection, characterized in that the sequential injection of two components into the reservoir is carried out at least in one well in a ratio of 1: 1, with this first component is injected an aqueous solution of aluminum sulphate - Al ₂ (SO _{4) 3,} and the second component is pumped heavy pyrolysis resin, which in interaction with each other in a formation to form a sealing viscous emulsion as a solution of aluminum sulphate Al ₂ (SO _{4) 3} is used 10-40% aqueous solution of aluminum sulphate Al ₂ (SO _{4) 3.} 2. The method according to claim 1, characterized in that the sequential injection into the reservoir of two components is carried out at least in one injection well, and the selection of oil is carried out from at least one producing well. 3. The method according to claim 1, characterized in that the sequential injection into the reservoir of two components is carried out at least in one production well, and at least one injection well, and after a predetermined time interval, oil is sampled, from at least one production well.