RU2726693C1 - Method for increasing efficiency of hydrocarbon production from oil-kerogen-containing formations and technological complex for its implementation - Google Patents

Abstract

FIELD: oil and gas industry.SUBSTANCE: group of inventions relates to oil and gas industry and can be used to increase efficiency of hydrocarbon production from petroleum-hydrogen containing formations of shale formations without using hydraulic fracturing of formation, as well as for extraction of natural bitumen, heavy and high-viscosity oil. High-tech oil production method includes thermochemical effects on productive stratum with working agents. They are prepared on the day surface and injected in the specified sequence into the near-borehole zone of the productive formation along the column of heat-insulated tubing string. Then high-tech oil is extracted from productive formation in well flowing mode and delivered to day surface along column of heat-insulated tubing string. Extraction process is carried out cyclically. Each cycle includes several stages. First stage of each cycle is the stage of injection into productive stratum of working agent of action. At the last stage high-tech oil is withdrawn from productive formation. At the stage of oil extraction of each cycle in-situ pressure is controlled. As soon as this pressure drops to preset value, selection is stopped.EFFECT: increased oil recovery of petroleum-hydrogen-containing formations due to formation of their high permeability.2 cl, 4 dwg, 1 tbl

Description

The group of inventions relates to the oil and gas industry and can be used to improve the efficiency of hydrocarbon production from oil-kerogen-containing formations of shale formations without the use of hydraulic fracturing, as well as for the production of natural bitumen, heavy and high-viscosity oils.

It has been established that the largest strategically significant hydrocarbon reserves of Russia are concentrated in the Bazhenov and Domanik formations. The works on their development were started by Russian oil companies several years ago. They consisted mainly in the adaptation of North American mining "shale" technologies and did not bring significant positive results.

Experts know that North American shale production technologies are perfected (1) technologies for drilling long-bore horizontal wells with a length of their horizontal section, often more than 3000 meters, followed by (2) multi-stage hydraulic fracturing (MSHF) in such wells - up to 50 stages on an area of 3000 meters.

The relative success of their application, for example, in the USA on the Bakken / Three Forks, Eagle Ford, Permian Basin, or in Argentina on the Vaca Muerta (Dead Cow) shale play is due to the fact that, at a relatively low _Corg (organic carbon: S ₁ (oil of tight rocks) + S ₂ (kerogen)) in their oil-kerogen-containing formations (on average, up to 4 percent), their thickness reaches significant values - from 80 to 200 meters or more.

This made it possible to create a significant drained volume from one well after multistage hydraulic fracturing, equal, on average, to 40 million m ³ . At 4% _Corg content, such a reservoir volume drained from one well contains approximately 3.5 million tons of _Corg , of which approximately 880 thousand tons (25%) is mobile light tight oil (LDP) (Tight Oil) (S ₁ ), which is also called "low-permeability oil" (TOC) and is often called, not quite correctly, "shale oil".

With the average oil recovery factor (ORF) of North American shale technologies currently equal to 8%, the estimated cumulative production (Estimated Ultimate Recovery (EUR)) from one well NPP is 70.4 thousand tons, or from 500 to 600 thousand barrels ( 550 thousand barrels, on average, for calculation).

With an oil price of US $ 70 per barrel and a production cost of R&D, for example, at the Bakken / Three Forks in North Dakota, equal to US $ 57.8 per barrel [1], the projected income per well is US $ 6.7 million. USA. These calculations are based on the facts of "shale" oil production in the United States and are confirmed by practice, when when the price of oil rises above $ 60 per barrel, the North American "shale" economy is reviving. [2].

The Bazhenov Formation differs from the North American oil-bearing shale plays in that its beds are rich in organic carbon ( _Corg - up to 23%), they are more plastic, and their thickness, on average, is about 20 meters. Moreover, in its strata NPP is about 18 times less than kerogen. (Fig. 1). [3].

Thus, on Bazhen it is possible to form a drained reservoir volume from one well, approximately 10 times less than in the North American oil-bearing shale deposits, and the oil recovery factor in the Bazhenov formation, according to experts, does not exceed 6 percent on average.

As a result, simple calculations to those skilled understood that at a sufficiently high 10% Content C _org in drained from one bazhenovskoj wellbore reservoir volume (4 million. ^M3) contained about 1320 thousand. Tonnes C _org, of which 132 thousand. Tonnes ( 10%) are NPP (S ₁ ). With oil recovery factor = 6%, approximately 8 thousand tons of oil production is extracted to the day surface of the well, which, in general, corresponds to the practice of oil production at the Bazhenov formation.

According to the estimated data of industry experts, in order for the production of the NPP from the Bazhenov formation to become profitable, the cumulative production of the NPP for the entire period of the well operation must be more than 30 thousand tons. According to most experts, this is possible only in isolated cases when developing "sweet spots" (according to S ₁ ).

Thus, the insufficient thickness / thickness of the layers of the Bazhenov (and Domanik) formation, combined with their high heterogeneity and plasticity, is the main reason, predicted by experts, of the unprofitableness of the Bazhenov production projects if they are aimed at extracting only oil of low-permeability rocks from its layers. ...

From the above it follows that the economically effective development of the Bazhenov (and Domanikovaya) formation, due to its qualitative difference from the North American oil-bearing shale plays, is possible only when an additional hydrocarbon resource is involved in the active development - stationary kerogen and stationary and / or low-mobile bituminous oil, which involves the use of thermal technologies - technologies based on the impact on the reservoir with high-temperature working agents of influence (RAV).

Such a technology, the use of which may be quite successful in the Bazhenov and Domanik formations, should, at least, additionally involve kerogen and bituminous oil in the active development, ensure an increase in the permeability of the productive formations of the formations, as well as their re-energy - an increase in the internal energy of the formation, its in-situ pressure. subject to a decrease in the degree of molecular blocking of fluid-conducting channels and the withdrawal of hydrocarbons through the formation zones with increased permeability, including due to carbonization of residual heavy intra-formation hydrocarbons in the near-wellbore volume of the formation.

At present, thermal technologies are widely used in the production of hydrocarbons. Various methods of thermal stimulation of the formation are known from the prior art, for example:

- using electric heating elements (SHELL In-Situ Conversion Process (ICP));

- due to the organization of chemical exothermic reactions in the formation with the injection of various reactants into it - binary mixtures (RF patent 2401941, IPC Е21В 43/22, 2009);

- electromagnetic or radio frequency heating of the formation (Schlumberger and Phoenix-Wyoming, Inc.);

- due to the organization of in-situ oxidation / combustion of a certain part of in-situ hydrocarbons (RITEK JSC and Zarubezhneft JSC) (RF patent No. 2403383, IPC Е21В 43/24, 2010, RF patent No. 2418944, IPC Е21В 43/24, 2011 g.);

- due to the introduction of enthalpy into the formation by forced injection of high-temperature high-pressure RAV in the form of supercritical water saturated with carbon dioxide in a supercritical state (RF patent No. 2576267, IPC Е21В 43/24, 2015).

If we take into account the low (nanoscale) porosity (about 6-8%) and low permeability of the formations of the Bazhenov and Domanik formations (on average, 0.1 mD), as well as the significant depth of their occurrence (up to about 3500 meters), then there are only three real ways to heat their layers, namely:

- to organize in-situ combustion / oxidation of some part of in-situ hydrocarbons contained in their formations;

- to organize an exothermic chemical reaction in the formation by injecting various reactants into it that make up a binary mixture;

- to bring heat into the formation by forcibly injecting a high-temperature RAV into it under high pressure.

Such technologies are known in principle from the prior art.

So, for example, a typical representative of technologies based on in-situ oxidation / combustion of a certain part of in-situ hydrocarbons is a method (RF patent No. 2403383, IPC Е21В 43/24, 2010) for the development of an oil reservoir by drilling injection and production wells, injection into injection wells. wells of air, water, combustion gases separated from the production of production wells, and the selection of oil, combustion gases and associated petroleum gases from the production wells, while a coolant is previously pumped into the injection wells to warm the formation to a temperature of at least 65 ° C in the vicinity of the well with a radius 5-20 m, a portion of hot water is injected alternately with an oil solvent weighing 5-150 tons per 1 m of the productive interval, and a heated water-air mixture is injected, and the water-air ratio at a reservoir pressure less than 22.064 MPa is determined from a given ratio.

There is also a known method (RF patent No. 2418944, IPC E21B 43/24, 2011) for the development of oil-kerogen-containing fields, including the creation of a zone of in-situ oxidizing and thermodynamic processes in the formation, for which an oxygen-containing water-air mixture is pumped into the formation through an injection well, and thermohydrodynamic processes are controlled the value of the water-air ratio of the oxygen-containing mixture from the condition of heating the formation zone to a temperature not lower than 250 ° C, for which the optimal value of the water-air ratio is determined by the analytical expression. In this case, the value of the water-air ratio of the pumped oxygen-containing mixture is cyclically increased and decreased around the set optimum value with the level of decrease of the said value below 0.001 m ³ / nm ³ .

The above methods are based on the use of thermal gas impact on a productive formation and are characterized by the following general disadvantages that reduce the effectiveness of their application in the Bazhenov and Domanik formations.

1. The need to burn a part of valuable in-situ hydrocarbons. When implementing these methods, for heating the productive formation, oxidation / combustion of a certain part of the high-cost NPP contained in it is carried out, for the extraction of which, in fact, the production process itself is organized. So, to heat 1 m ^{3 of the} formation to a temperature of 400 ° C, energy is required equal, on average, to about 1000 MJ. It is known that the heat of combustion of average viscosity oil is approximately 45 thousand kJ / kg. Therefore, to heat 1 m ^{3 of the} formation to a temperature of 400 ° C, it is necessary to oxidize / burn 22.22 kg of in-situ oil. It is also known that as a result of the thermal effect on the formations of the Bazhenov and Domanik formations from 1 m ³ it is possible to extract from 50 to 80 kg of both low-permeability oil and synthetic oil generated from kerogen. Thus, as a result of using known methods, the volume of total recoverable oil is reduced by 44-27.5%, respectively, from 50 to 27.7 kg / m ³ and from 80 to 57.7 kg / m ³ . If kerogen is used for in-situ heating of a productive formation, the oxidation kinetics of which is much higher than the kinetics of oil oxidation in low-permeability rocks, then in order to achieve the required process temperature in the reservoir, according to the authors of the thermal gas treatment technology themselves, it is necessary to “burn” from 30 to 50% kerogen contained in the formation.

2. The presence of coke formation. The formation temperature in the zone of in situ oxidation reactions can reach 650 ° C and more. With long-term maintenance of such a temperature in the anhydrous formation, the process of active coke formation takes place. Coke clogs fluid channels, which leads to a decrease in the efficiency of known methods.

3. Low predictability and controllability. In reservoir conditions, it is difficult to predict what the temperature in the zone of oxidative reactions and, in fact, where it occurs at a given time is. Online controls do not yet exist. This complicates the process of making a decision about when to start pumping warm water or a water-air mixture to form supercritical water in the reservoir, followed by the formation of local foci of in-situ pseudo-supercritical medium. Taking into account the high heterogeneity of the Bazhenov formation and the undefined zonal concentrations of tight oil, bituminous oil and kerogen in them, an accurate calculation of the temperature in the formation, an understanding of exactly where high-temperature oxidative reactions take place in the formation, and the determination of the start of water injection into the productive formation. or water-air mixture and stopping the injection is practically impossible. The result of low predictability and low controllability of the known methods is that at certain points in time, the formation or its individual regions can either overheat or, on the contrary, underheat, which, in general, leads to a decrease in the efficiency of the known methods and the possibility of damage to injection and production wells for due to the breakthrough of high-temperature fluid in them, mainly through interlayers (packs) with relatively high permeability, called "bazhen-bakken" (the term was proposed by Academician AE Kontorovich).

4. Oil production is carried out through a zone of unaltered low natural permeability. In the known methods, at least two wells are used - injection and production. It is known from the state of the art that the permeability of the formation increases as a result of thermal action. But this effect is not used in known methods, since tight oil is displaced from the injection well towards the production well through the reservoir zone with unchanged low natural permeability.

5. Using two or more wells. In the known methods, several wells are used - one injection and at least one producing. This leads to an increase in capital investments and, accordingly, to an increase in the cost of hydrocarbon production. According to experts, the development of layers of the Bazhenov formation using cyclic stimulation and only one well seems to be a more efficient method as of 2015-2016. JSC "RITEK" is studying the possibility of using just one well for the implementation of cyclic thermal gas stimulation of the productive formation.

6. Use of hydrocarbon solvents. The use of hydrocarbon solvents, especially such as diesel fuel, oil distillate or a wide range of light aromatic hydrocarbons, increases the cost of oil production and leads to a decrease in the economic efficiency of the methods, since some of the hydrocarbon solvents delivered from the day surface of the well to the productive formation (up to 50% ) becomes unrecoverable and remains in the reservoir.

7. The main goal is to oust NPP. In the technology of thermogas stimulation, the main task is the in-situ generation of agents (CO ₂ , carbon monoxide, light hydrocarbon fractions, nitrogen and water vapor), displacing tight oil from the reservoir into the producing well. The generation of synthetic oil from kerogen in the thermal gas treatment technology is a secondary task. The conceptual approach used, in which less attention is paid to in-situ generation of synthetic oil from kerogen than to displacement of oil from oil reservoirs by NPP, reduces the degree of efficiency of the known methods, since the main hydrocarbon potential of the Bazhenov (and Domanik) formation is concentrated in kerogen (403.3 billion tons ) and not in tight oil (22 billion tons).

8. Nitrogen injection. If air or air with an increased oxygen content is used as an oxidizer, a significant amount of nitrogen is injected into the reservoir, the presence of which in the reservoir decreases the degree of solubility of carbon dioxide in oil and, thus, nitrogen negatively affects the process of reducing the density and viscosity of oil.

A typical representative of technologies based on thermochemical action on a productive formation in order to increase its flow rate by organizing an exothermic chemical reaction in the formation by injecting various reactants into it is the method (RF patent 2401941, IPC Е21В 43/22, 2009) of thermochemical treatment oil reservoir due to the organization of chemical exothermic reactions in it with the use of reactive substances - the so-called "binary mixtures", including the separate injection into the reservoir of the components of the combustible-oxidizing composition (WOC) and the combustion initiator (IG) through two coaxially located relative to each other pumping - compressor pipes (tubing), while the lower cut of the outer tubing is lowered below the lower cut of the inner tubing at a distance sufficient to ensure the contact time of the GOS and IG in the reaction volume. GOS is supplied to the treated area of the oil reservoir through the annular space between the outer and inner tubing, IG is fed through the inner tubing, while the GOS is used as an aqueous solution with a pH of 4-7, including, wt. %: nitrate 5-25, carbamide-ammonium mixture (UAN) -32 - the rest, and as IG - an aqueous solution with a pH of 12-14, including, wt. %: alkali metal nitrite 15-45, water - the rest, or alkali metal borohydride 15-45, alkali 3-45, water - the rest, and the mass of IG containing alkali metal nitrite is 1-80% of the mass of GOS, the mass of IG containing borohydride of an alkali metal is 1-30% by weight of GOS.

This method is based on thermochemical action on the formation. The main disadvantage of this method is the high market value of the components used in the binary mixture, which significantly limits the scope of its application. Due to the high cost of the components of the binary mixture, the known method can be used exclusively in formations with high porosity (more than 15%) and, most importantly, with high permeability. It is also very important that when implementing the known method, the cooling period of the heated part of the formation in the near-wellbore space is several months, and the heat of the heated part of the formation - the enclosing rock should be sufficient so that during this time the heat from the cooling down passes through the heated zone to the well and is heated. near-wellbore rock 4-5 portions of oil, each of which is equal to the mass of oil initially present in the heated volume of the formation. That is, for example, if the heated near-wellbore volume of the formation (V = 15000 m ³ ) with its porosity equal to 20% initially contained approximately 3000 tons of oil, then at ORF = 25% on the day surface, according to the authors' calculations, using the known method can be extracted up to 3750 tons of oil (750 tons (1 portion; oil recovery factor = 25%), 5 portions = 3750 tons of oil). Indeed, this is correct when applied to highly permeable formations containing high-viscosity or heavy oil. But the known method cannot be effective in oil-bearing shale fields with very low permeability and relatively low total porosity. When producing hydrocarbons from oil-bearing shale reservoirs, it is necessary to rely only on the volume of hydrocarbons contained in the heated volume of the formation, since the degree of intensity of the actual "recharge" of hydrocarbons from the periphery of low-permeability formations is very low and does not exceed a few percent of the volume of hydrocarbons originally contained in heated reservoir volume (in-situ retort).

Undoubtedly, the most promising technologies that provide enhanced oil recovery include technologies based on forced injection of high-temperature RAV into the reservoir under high pressure.

For example, there is a known method for the production of hydrocarbons using a supercritical fluid and a system for implementing the method (see published application US No. 2014/0224491, 2014, "System and Process for Recovering Hydrocarbons Using a Supercritical Fluids"), according to which they are carried out in a surface steam generating device obtaining a supercritical "first aqueous fluid" (supercritical water) with its subsequent injection into the formation to heat in situ hydrocarbons, withdrawing heated hydrocarbons to the day surface of the well and using a "second water fluid" (supercritical water) for additional partial upgrading already partially refined hydrocarbons taken from the reservoir in one of the surface devices to improve their quality in order to facilitate the process of delivery of hydrocarbons taken from the reservoir to the refinery for their final processing. At the same time, this method can also be used to influence oil-bearing shale deposits (Shale Oil, English) (see p. 4, [0035] p. 5.).

The disadvantage of the known solution is that both the "first aqueous fluid" and the "second aqueous fluid" used for its implementation have an extremely simple compositional composition and are water in a supercritical state. The "first aqueous fluid" used does not contain any other components that could increase the degree of conversion of heavy hydrocarbons into lighter hydrocarbons or, for example, contribute to a decrease in their viscosity and density, as well as increase the mobility / mobility of hydrocarbons in the formation or additionally increase the permeability of the formation ... The efficiency of the "first aqueous fluid" used in the method would be higher if the composition of the "first aqueous fluid" included such additional components as hydrogen (oxidizing agent), carbon dioxide, carbon monoxide, methane and nanoscale catalysts for the conversion of hydrocarbons, for example, in molecular or ionic form.

It is also very important that the system implementing the method does not use a product pipeline (tubing) with an insulating coating (TIP), which would reduce heat transport losses during the delivery of a high-temperature working agent - the "first aqueous fluid" from the day surface of the well to its bottom.

There is a known method (application WO 2015/059026, 2015) for the production of hydrocarbons in hydrothermal conditions, according to which two horizontal wells are used, hot water is injected into one of the wells under pressure, including water in a supercritical state. Further, after preheating the formation, hydraulic fracturing is performed to form a system of fractures connecting the injection and production wells (Figure 2, item 6). In the heated formation, the reactions of hydrothermal liquefaction of hydrocarbons, including kerogen, are carried out. The hydrocarbons liquefied in the formation are recovered to the day surface of the well. In-situ liquefaction of hydrocarbons using high-temperature subcritical or supercritical water allows the production of hydrocarbons that cannot be recovered from the formation in any other way.

The first disadvantage of the known method is the use of not one, but two wells, one of which is injection, and the other is producing. This approach increases capital costs, which, in general, reduces the efficiency of using the known method.

The second disadvantage of the known method is the deliberate creation of mega-hydraulic fractures / mega-fluid channels between two wells (Figure 2, item 6). Without any doubt, over time, such fractures connecting both wells are transformed into main fluid channels, through which the high-temperature RAV pumped through the injection well will quickly, without having time to transfer the required part of the heat to the formation, be pumped from the injection well to the production well. In such a situation, very soon water will enter the production well with a temperature higher than the design one, which means an increase in heat losses. Conductive heat transfer will become dominant, and the efficiency of convective heat transfer and thermal impact on the formation will decrease, which results in a decrease in the degree of efficiency of using the known method.

The third disadvantage of the known method is that the dominance of conductive heat transfer over convective heat does not allow for rapid heating of the productive formation and, accordingly, rapid and, most importantly, in sufficient quantity in-situ generation of synthetic hydrocarbons from bituminous oil and kerogen. This means that in the course of its operation, the production well will receive a fluid with less and less hydrocarbons and more and more water, the temperature of which exceeds the design one. The hydrocarbon potential of the near-fractured zones will be rapidly depleted, and the development of the hydrocarbon potential of more distant zones of the productive formation will be carried out with a significant lag and excessive consumption of thermal energy. This also reduces the efficiency of the known method.

The closest in technical essence and the achieved technical result to the claimed group of inventions is a method for the production of hydrocarbons from oil-kerogen-containing formations (RF patent No. 2 671 880, class E21B 43/247, 2018), including the preparation of RAV, injecting them through the pipeline into the productive formation for the purpose of high-temperature thermochemical impact on the productive formation, followed by the selection of hydrocarbons in the flowing mode of the well and their delivery to the day surface through the product pipeline. Before the high-temperature thermochemical treatment on the productive formation, the restoration of natural fracturing and natural fluid-conducting channels in the bottomhole zone of the productive formation is carried out, and before the extraction of hydrocarbons from it, a thermo-catalytic effect on the productive formation is carried out to upgrade hydrocarbons, followed by the implementation of a hydrogen-thermo-catalytic action on the productive formation using a catalytic nanoproppant to increase the degree of completeness of the molecular modification of low-permeability oil, bituminous oil and kerogen into more valuable hydrocarbons and anchoring the fluid-conducting channels of the productive formation. In the near-wellbore volume of the productive formation, a "catalytic belt / filter" is formed and, due to the process of hydrothermal carbonization of hydrocarbons, a nanoporous carbon coating is formed on the inner surface of the nanofluid-conducting channels, after which modified and partially refined hydrocarbons are withdrawn through the product pipeline to the day surface, and in the process of delivery of hydrocarbons to the day surface is additionally partially refined by passing it through a flow reactor formed by the space in the product pipeline between the tubing string and a coaxially placed sleeveless pipe therein.

The technological complex designed for the implementation of the above method includes a surface generator of ultra-supercritical water, a product pipeline made in the form of a tubing string with a TYPE, located in the well to its bottom, and the generator has the ability to connect with an outlet to the tubing string. The technological complex is equipped with a mixer, a water treatment plant connected with the output to the generator input, as well as an oxidation reactor, an organic compounds reforming reactor and an organic compound enrichment unit connected by the output to the first input of the organic compounds reforming reactor, to the second input of which a generator can be connected, and the outlet of the reforming reactor has the ability to be connected to the tubing string, a generator is connected to the inlet of the oxidation reactor, and the outlet of the oxidation reactor can be connected to the tubing string, while in the tubing string a sleeveless pipe is coaxially located with a gap, to which a cold water tank can be connected, or a tank for an oxidizer, and the mixer has the ability to connect inlet to the generator, and outlet to the tubing string.

As a result of the analysis of the known method, it should be noted that during its implementation, 10 types of RAV are used to influence the oil-kerogen-containing formation, and some of them are used to increase the permeability of the formation, which is one of the most important factors that ensure the effectiveness of the known method, the use of which provides an oil recovery factor of up to 45 -50%.

The foregoing confirms the effectiveness of this method in comparison with the above.

However, when implementing the known method, when using RAV No. I.B, immediately after its injection into the formation, in the near-wellbore volume of the formation (radius up to 1 meter), multiple nanolocal exothermic oxidation reactions of some part of the in-situ hydrocarbons are immediately initiated and, thus, the use This RAV for increasing the permeability of the formation in the known method is limited to the near-wellbore volume having a radius of up to 1 meter. It is also very important that when a high-temperature RAV passes through a tubing string with a TYPE during their delivery to a productive formation under high pressure, the total length of the tubing string, as a result of their heating, is significantly lengthened.

So, for example, when injecting a high-temperature RAV into a productive formation along a tubing string made of INCONEL 740N alloy, when they are heated, on average (evenly along the entire length of the tubing), to a temperature of 520 ° C, a section of the tubing string, 3000 meters long, linearly increases by 21.84 meters, and when a less high-temperature oil-water emulsion with a temperature of 280 ° C is withdrawn from a productive formation (on average, along the entire length of the tubing), the same section, 3000 meters long, increases linearly by 11.34 meters or linearly decreases by 10.5 meters relative to its linear size when pumping RAV (21.84 m - 11.34 m = 10.5 m).

Thus, with the thermochemical effect of a high-temperature RAV on the reservoir and the subsequent withdrawal from the reservoir of an oil-water emulsion, which (compared to the RAV temperature) has a significantly lower temperature, the tubing placed inside the casing cyclically change its length.

Such thermal linear deformations of the tubing lead to periodic reciprocating movement of the packer together with the tubing string along the inner surface of the casing pipes, which very often leads to a breach of the tightness of the separation of the sub-packer and above-packer zones of the well and to the loss of a part of the expensive RAV due to its overflow from the sub-packer zone of the well. into the under-packer zone, and, as a result, to a decrease in pressure in the under-packer zone of the well.

The above circumstances reduce the efficiency of the use of thermochemical technologies in the development of oil-bearing shale formations (Bazhenov and / or Domanikovaya formations) and the development of heavy hydrocarbon deposits, in particular, deep-seated.

The technical result of the present group of inventions is to increase oil recovery of productive kerogen-containing formations due to the formation of a highly permeable in-situ retort in the near-wellbore zone of the formation, and gradual, as oil is withdrawn from this near-wellbore zone, its volume increases, as well as due to periodic restoration of the permeability of the near-wellbore zone of the formation and carrying out in-situ generation of high-tech oil in it by injecting RAV into the productive formation, as well as by ensuring the tightness of the separation of the under-packer and above-packer zones of the well and compensating for thermobaric changes in the length of the tubing string in the process of injecting RAV and withdrawing hydrocarbons.

The specified technical result is ensured by the fact that in the method of extracting high-tech oil (hydrocarbons) from an oil-kerogen-containing formation, including thermochemical effects on the productive formation by working agents prepared on the day surface and injected in a predetermined sequence into the near-wellbore zone of the productive formation along a string of insulated tubing, with the subsequent selection of a water-oil emulsion from it in the mode of flowing a well, consisting mainly of water, liquid and gaseous hydrocarbons, including synthetic, and other gases, its delivery to the day surface along a string of insulated tubing, the new is that the process production is carried out cyclically, each of the cycles includes several stages, the first stage of each cycle is the stage of injecting a working agent into the productive formation, and the last is the selection of an oil-water emulsion from the productive formation, and at the stage of oil withdrawal of each cycle, the in-situ pressure is monitored and, as soon as it drops to a predetermined value, the withdrawal is stopped, while during the first cycle, at its first stage, a near-wellbore zone with increased permeability is formed in the reservoir by injecting a working agent into the reservoir exposure in the form of water having a temperature above 593 ° C at a pressure of 23 to 50 MPa and this working agent generates the action of synthetic hydrocarbons in the near-wellbore zone, followed by the stage of sampling the water-oil emulsion and delivering it to the day surface, after which the second cycle is carried out, at the first stage of which, in the near-wellbore zone of the productive formation, the main fluid-conducting channels are formed due to the implementation of in-situ thermal explosions, which are carried out by injecting a working agent in the form of water into the near-wellbore zone with a temperature above 593 ° C and a pressure from 23 to 50 MPa, on saturated with Fenton's reagent, after which, at the second stage, before withdrawing the water-oil emulsion and delivering it to the day surface, synthetic hydrocarbons are generated in the near-wellbore zone by injecting a working agent in the form of water into the near-wellbore zone, with a temperature of 380 to 593 ° C at a pressure of 23 to 50 MPa, and at the first stage of the third cycle, the permeability of the near-wellbore zone of the productive formation is restored, for which a working agent is injected into it, consisting of water, with a temperature of 374 to 593 ° C at a pressure of 23 to 50 MPa, saturated with Fenton's reagent, which consists of hydrogen peroxide and a catalyst in the form of iron ions II or III (Fe ₂ +; Fe ₃ +), after which, at the second stage, the resins and asphaltenes contained in the reservoir are dissolved by injecting a working agent of action into its near-wellbore zone, consisting of water with a temperature of 374 ° C and up to 593 ° C at a pressure of 23 to 50 MPa saturated with an organic solvent, after which, at the third stage, additional fluid-conducting channels are formed in the near-wellbore zone of the productive formation by injecting into the near-wellbore zone of the working agent of action, in the form of water, with a temperature above 593 ° C at P from 23 to 50 MPa, saturated with hydrogen peroxide and inhibitor of hydrogen peroxide, or working agent of action, in the form of water, temperature from 374 to 593 ° C at P from 23 to 50 MPa, saturated with hydrogen peroxide and inhibitor of hydrogen peroxide, after which, at the fourth stage of this cycle, synthetic hydrocarbons are generated in the productive formation by injection into the near-wellbore zone of the working agent of action, consisting of water, t with a temperature of 374 to 593 ° C at a pressure of 23 to 50 MPa, with subsequent withdrawal at the fifth stage of the generated oil-water emulsion from the productive formation and delivering it to the day surface, after which, at the first stage of the fourth cycle, the permeability of the productive formation is restored due to thermochemical action a working agent injected into the near-wellbore zone in the form of water with a temperature above 593 ° C at a pressure of 23 to 50 MPa), saturated with hydrogen peroxide, or a working agent in the form of water, a temperature of 374 to 593 ° C at a pressure of 23 to 50 MPa saturated with hydrogen peroxide, after which, at the second stage, synthetic hydrocarbons are generated due to the thermochemical effect of a working agent injected into the near-wellbore zone, consisting of water, with a temperature of 374 to 593 ° C at a pressure of 23 to 50 MPa, followed by the third stage of the fourth cycle of water-oil emulsion and its delivery to the the surface, after which, at the first stage of the fifth cycle, the permeability of the near-wellbore zone of the productive formation is restored due to the thermochemical effect of a working agent injected into the near-wellbore zone of the action in the form of water having a temperature above 593 ° C and up to 650 ° C at a pressure of 23 to 50 MPa, after which, at the second stage, the tars and asphaltenes of the productive formation are dissolved due to the thermochemical action of the working agent injected into the near-wellbore zone of the action, consisting of water, with a temperature of 374 to 593 ° C at a pressure of 23 to 50 MPa, saturated with an organic solvent, the concentration of which is is from 1 to 500 kg / m ^{3 of} water in a normal state and ethanol (C ₂ H ₅ OH) in a concentration of 0.1 to 50 kg / m ^{3 of} water in a normal state, followed by the selection at the third stage of this cycle of an oil-water emulsion and delivery her on the day surface.

In a technological complex, including a water treatment plant, the inlet of which has the ability to connect to a water source, a generator designed to produce water with a pressure of 23 MPa to 50 MPa and a temperature of 374 ° C to 593 ° C and above, a column of heat-insulated tubing placed in the casing of the well to its bottom and intended for injecting working agents into the productive formation of the well and removing from it with delivery to the day surface of the oil-water emulsion, as well as containers for storing the components intended for the preparation of working agents of influence, new is that the complex is equipped with a block for the preparation of working agents of exposure, a container for storing and dispensing prepared water, as well as a container for storing and dispensing prepared working agents of exposure, containers for storing feathers are used as containers for storing components intended for preparing working agents of exposure hydrogen oxide, for storing water saturated with a catalyst in the form of iron II ions (Fe ₂ +), for storing water saturated with a hydrogen inhibitor, for storing organic solvents, for storing ethanol, while a container for storing and dispensing prepared water is connected inlet to an outlet installations for water treatment, and the outlet - with the inlet of the water generator, the outlet of which is connected to the input of the unit for the preparation of working agents of influence, to the inputs of which the above containers for the components of working agents of influence are also connected, the output of the unit for preparation of working agents of influence is connected to the input of the container for storage and delivery of prepared working agents of action, the output of which has the ability to connect to the tubing string, in which there is a built-in compensator for thermobaric changes in the length of the tubing string, which has the possibility of hermetic contact with the inner surface of the casing for dividing the well into two seals volumes that are different from each other - above-packer and below-packer.

Used in the description of the claimed group of inventions, the terms mean the following.

High-tech oil (HTN). High-tech oil means an oil blend (Oil Blend), compositional consisting of:

- Molecularly modified and partially refined mobile NPP, obtained as a result of thermochemical impact on the reservoir, as well as initially located in the reservoir;

- desorbed molecularly modified and partially refined NPP, which, prior to thermochemical exposure, was in an adsorbed state on the inner surface of round and slotted pores of the formation (adsorbed NPP - up to 25% of the total NPP in the formation). The less permeable a productive formation is, the more specific it contains the adsorbed, retained surface of the fluid-conducting channels, NPP;

- molecularly modified and partially refined liquid and mobile oil products for bituminous oil conversion (thermo-bitumen + heavy / medium oils);

- generated within the reservoir from synthetic oil kerogen (Synthetic Oil).

Inhibitor. An inhibitor (Latin inhibere "to detain") is understood as the general name of substances that suppress or retard the course of physiological and physicochemical (mainly enzymatic) processes.

Catalyst. A catalyst is understood as a chemical that accelerates the reaction but is not consumed during the reaction.

Solvents. In the claimed group of inventions, organic solvents are used, mainly from the groups: (1) aromatic solvents (benzene, toluene, solvent, etc.); (2) chlorine-substituted hydrocarbons (chloroform (trichloromethane), carbon tetrachloride, etc.); (3) hydroaromatic solvents (tetralin, decalin, etc.).

Intensified heat explosions. Intensified thermal explosions are understood to be thermal explosions, which, due to the presence of catalysts, are carried out in a shorter time period than “conventional” thermal explosions are carried out under the same conditions. So, for example, if under the same conditions a "conventional" thermal explosion in the formation occurs in 30 seconds, then an intensified thermal explosion can occur in 20 or 10 seconds, depending on the type, quality and concentration of the catalyst. Intensified thermal explosions make it possible to increase the permeability of the near-wellbore volume of a productive formation to a greater extent than "conventional" thermal explosions.

Delayed / delayed thermal explosions. Delayed / delayed thermal explosions are understood to be thermal explosions that, due to the presence of inhibitors, are initiated later than “conventional” thermal explosions are initiated under the same conditions. So, for example, if under the same conditions a "conventional" thermal explosion is initiated in the formation after 60 seconds, then a delayed / delayed thermal explosion can be initiated in the formation after 600 seconds or after 1200 seconds, depending on the type and concentration of the used inhibitor. In contrast to “conventional” thermal explosions, delayed / delayed thermal explosions can be carried out in zones of the productive formation more distant from the well.

The volume of the in situ retort with maximum permeability. The volume of an in-situ retort with maximum permeability is understood as a part of the volume of an in-situ retort in which “conventional” thermal explosions and / or intensified thermal explosions and / or delayed / delayed in time thermal explosions were carried out, as a result of which permeability in this part of the in-situ volume the retort reaches its maximum value.

Contact area of the volume of the in-situ retort with maximum permeability with the rest of the volume of the in-situ retort. The area of contact of the volume of the in-situ retort with maximum permeability with the rest of the volume of the in-situ retort is understood as the area of the outer surface of the volume of the in-situ retort with the maximum permeability.

Compensator of thermobaric changes in tubing string length with TYPE. A compensator is a device that allows tubing with a TYPE to repeatedly change its length (lengthen and shorten) in the well, provided that the isolation of the well volume below the compensator from the well volume, above the compensator is maintained. For example, in one and the same well in a volume well below the compensator may be a fluid, for example having T = 480 ° C at P = 45 MPa and a density of 250.5 kg / m ^3, and in the volume well above the compensator can be a fluid, for example, having T = 120 ° C at P = 3 MPa and a density of 944.5 kg / m ³ . Thus, in addition to compensating for temperature and pressure changes in tubing length, the compensator also functions as a downhole high-temperature high-pressure packer.

“Leafiness” of the Bazhenov Formation. One of the features of the productive strata of the Bazhenov Formation is their natural "foliation", which manifests itself in the fact that layers of heavy hydrocarbons (bitumoids) are located between the layers of the rock, consisting mainly of a mixture of resins and asphaltenes, which perform the function of "cementing" the rock Bazhenov suite.

Selection of high-tech oil in the well flowing mode and compaction of the productive formation. It is very important that the removal of dissolution products consisting of a solvent, dissolved resins and asphaltenes, liquid mobile hydrocarbons, hydrocarbon and other gases (liquid mixture) from the bottomhole zone of a well of an oil-kerogen-containing formation is carried out in the mode of well blowing under pressure, the value of which is higher than the hydrostatic pressure ... This approach does not allow compaction of the reservoir. The kerogen-bearing productive strata of the Bazhenov formation, as a rule, are devoid of a "skeleton", their porosity and permeability are maintained only due to the fact that in the pore space of such a productive stratum there are intra-formation fluids, the expanding pressure of which always exceeds the level of hydrostatic pressure. Therefore, if the expanding pressure of intra-formation fluids in the reservoir falls below the level of hydrostatic pressure, then the process of compaction of such a reservoir begins, or, in other words, the process of "collapse" of both sub-horizontal and sub-vertical fluid channels, which leads to a decrease in the porosity and permeability of the reservoir. ...

When withdrawing a liquid mixture from such a productive formation, it is important to observe the above condition, and not to allow the drop of in-situ pressure below the hydrostatic pressure level and always maintain it at a level that is 2-3 MPa higher than the hydrostatic pressure level.

RAV. In the claimed group of inventions, RAV are used, delivered in a strictly defined sequence along the tubing string to the near-wellbore zone of the productive formation and exerting thermochemical effects on it. Compositionally, RABs consist of water having a temperature (T) above 593 ° C at a pressure (P) from 23 to 50 MPa (water in an ultra-supercritical state) or having a temperature from 374 ° C to 593 ° C at P from 23 to 50 MPa (supercritical water). Physically, RAV is a high-temperature steam-water mixture into which one or more components have been introduced for a regulated thermochemical effect on a productive formation,

Vertical or directionally-inclined "Yolka" type well.

To implement the claimed group of inventions, a vertical or directionally-inclined "Yolka" type well is used, which consists of a main wellbore equipped with radial sub-horizontal open holes of small diameter (up to 60 mm) up to 100 meters long (not indicated). A diagram of such a well is shown in Fig. 2.

Reservoir zones. Reservoir zones (Fig. 3) or zones of an oil-kerogen-bearing formation (position 3) to which a vertical well (position 4) with sub-horizontal radial wells (position 5) is drilled is meant:

- reservoir zone No. 1 (position 1), this is the near-wellbore volume of the reservoir, the radius of which does not exceed 1 meter from the wellbore. The transformation of heavy hydrocarbons into aggressive inorganic carbon in this zone, as well as the oil recovery factor of hydrocarbons in liquid or gaseous form from this zone reaches its possible maximum;

- formation zone No. 2 (position 2), this is the near-wellbore volume of the formation, the radius of which is from 1 to 3 meters.

Naturally, these zones are conditional, in a real reservoir there is no clear division into these zones. This conditional division of the formation into zones contributes to a better understanding of the essence of the claimed group of inventions.

The essence of the claimed group of inventions is illustrated by graphic materials and a table on which:

- in Fig. 1 is a diagram characterizing the influence of kerogen on the volume of recoverable hydrocarbon resources of the Bazhenov formation;

- in Fig. 2 - diagram of a vertical well of the Yolka type;

- in Fig. 3 is a diagram of the formation zones of an oil-kerogen-containing productive formation;

- in Fig. 4 is a diagram of the technological complex used to implement the claimed method;

- table - an algorithm of cyclic thermochemical action of working agents on an oil-kerogen-containing reservoir during the implementation of the method.

To implement the claimed method, a technological complex (Fig. 4) can be used, including a water treatment module 6, to the input of which a service water supply line is connected, and the outlet is connected to the inlet of a container 7 for storing water prepared in module 6. The output of this container is connected to the input of the generator 8 for the preparation of supercritical or ultra-supercritical water (hereinafter referred to as the generator).

The technological complex is equipped with a block 9 for the preparation of RAV, to which, in parallel, through pipelines (not indicated by the positions), a container 10 for a 30-50% hydrogen peroxide solution, a container 12 for water saturated with a catalyst in the form of iron II ions (Fe ₂ +), a container 14 for water saturated with a hydrogen inhibitor (hydrogen peroxide), for example sodium phosphate, a container 22 for an organic solvent and a container 24 for ethanol.

When preparing RAV for supplying components from containers 10, 12, 14, 22 and 24 to unit 9, pumps built into the pipelines are used, respectively, 11, 13, 15, 23 and 25, the first of which (11) provides supply of RAV preparation to unit 9 hydrogen peroxide, the second (13) supplies the unit 9 with water saturated with a catalyst in the form of iron II ions (Fe ₂ +), the third (15) supplies the unit 9 with an aqueous solution saturated with a hydrogen inhibitor, the fourth (22) supplies block 9 of an organic solvent and the fifth (25) provides the supply of ethanol to the block 9.

The outlet of block 9 is connected to a storage tank 16 for maintaining a predetermined temperature and dispensing RAV 21 prepared in block 9. To maintain a predetermined temperature of a 16 RAV placed in a container, it is equipped with an adjustable heater (not shown). The RAV temperature is controlled by temperature sensors (not shown).

The outlet of the tank 16 is connected to the inlet of the tubing string 18 with a TYPE located in a vertical well (without radial boreholes) 17, into which a compensator 19 of thermobaric changes in the length of the tubing string with a TYPE is built, the outer surface of which constantly and tightly (without a gap) contacts the inner surface of the casing well pipes (not shown). The tubing string was lowered into the well to the oil-kerogen-containing productive formation 20.

It is very important to achieve the specified technical result and new in relation to the solution - the closest analogue, is the use in the technological complex of the compensator 19. The compensator is built into the tubing string, and it performs two functions: (1) compensates for thermobaric changes in the length of the tubing string with TYPE and (2) provides a tight separation of the well volume into above-packer and below-packer volumes located, respectively, above and below the compensator. The use of a tubing string with a TYPE, in which the expansion joint 19 is built, makes it possible to abandon the use of a complex downhole configuration "Pipe in pipe".

Naturally, such a compensator should work effectively under high temperature and pressure conditions that occur during well operation, as well as have high antifriction properties, since its outer surface is constantly in close contact with the well casing and cyclically moves relative to it when compensating for thermobaric linear deformations of the tubing string.

Such compensators are known from the prior art, see, for example, RF patent No. 2688807 "Compensator for thermobaric changes in the length of a tubing string".

It is also very important to introduce tanks 7 and 16 into the design of the technological complex. Their presence allows the technological "decoupling" of the water treatment module 6 and generator 8, ensuring the operation of each of them in the optimal mode with a constant reserve of prepared water in the tank 7, as well as ensuring inflow of a given amount of RAV into the pay zone.

The operation of the complex is carried out, preferably, in automatic mode, for which the complex is equipped with a control system (not shown).

Naturally, the complex is equipped with sensors for monitoring the temperature and pressure of the media generated by the technological complex, as well as with standard transport and shut-off and control valves (not shown), which ensure its operation in automatic mode.

Blocks and modules of the technological complex, the implementation of which is not disclosed in this application, are known and their constructive solution does not constitute the subject of patent protection.

The claimed method, using the above technological complex, is carried out as follows.

The technological complex, the implementation of which is disclosed above, ensures the preparation of RAV, their storage and delivery with specified parameters to the near-wellbore zone of the productive formation.

During the operation of the complex (implementation of the method), industrial water is supplied to the water treatment module 6, in which water is purified from impurities and mechanical impurities using standard mechanical filtration means and softened using reverse osmosis and ultrafiltration. Fine mechanical water purification - the removal of various undissolved suspensions from water is carried out by industrial multi-cartridge filters with rinsing titanium membranes. The fineness of cleaning is 0.1 microns, which prevents the formation of blockages and rapid wear of the steam generator parts, as well as the process of mudding the formation. It is easy to conclude that the water treatment module should also contain a block for iron removal and water demanganation - removal of iron and manganese from water both in dissolved and in oxidized form using industrial filters with iron removers. If necessary, additional methods are used to oxidize the metals dissolved in water: aeration, settling, dosing of reagents, which prevents the formation of sludge and blockages. Also a significant component of the water treatment module is the water degassing unit - the elimination of corrosive substances from water: oxygen and carbon dioxide using chemical water treatment, preliminary thermal deaeration (heating water at constant pressure) or using the vacuum degassing process (counterflow of water and steam).

Prepared water from the water treatment module 6 is fed into storage in a container 7 for prepared water, from which it is dosed, by a pump (not shown), can be fed to a generator 8, in which the process of generating ultra-supercritical water is carried out (T is more than 593 ° C at P more from 25 to 50 MPa) or supercritical water (T from 380 to 593 ° C at P from 23 to 50 MPa) due to its heating in the heat exchanger of the generator. As a generator can be used, in particular, a module known from the RF patent for a utility model "Module for generating an ultra-supercritical working agent" No. 189433 dated January 14, 2019.

The water prepared in the generator 8 is supplied to unit 9, into which the component (s) for the preparation of a specific RAV is supplied from the corresponding container (s).

Block 9 is a thick-walled pipe up to 10 meters long with inlet channels for injecting prepared water from generator 8 and components from containers 10, 12, 14, 22, 24 into block 9, and an outlet channel connected to the inlet of container 16 intended for storage and dispensing of the RAV 21 prepared in unit 9.

Let us give the composition of each RAV used to implement the method and the process of its preparation in block 9.

RAV No. 1

RAV No. 1 is water in an ultra-supercritical or supercritical state, which is obtained in the generator 8 from the prepared water supplied from the container 7. Prepared RAV # 1 from generator 8 is fed through block 9 to container 16. Shutoff valves of all other containers at the same time block the flow of their contents into block 9.

RAV No. 2

RAV No. 2 is water in a supercritical state, saturated with an organic solvent, the concentration of which is from 1 to 500 kg / m ^{3 of} water in a normal state. As an organic solvent, solvents from the group of aromatic solvents (benzene, toluene, solvent), or from the group of chlorine-substituted hydrocarbons (chloroform, carbon tetrachloride), or from the group of hydroaromatic solvents (tetralin, decalin) are used,

To prepare RAV # 2, the supercritical water obtained in the generator 8 is fed to block 9, into which an organic solvent is supplied from the container 22 by the pump 23, as a result of mixing these components, RAV # 2 is formed, having T from 380 to 593 ° C at P from 23 to 50 MPa, which is fed into container 16.

RAV No. 3

RAV No. 3 is water in an ultra-supercritical state, saturated with 30-50% aqueous solution of hydrogen peroxide (H ₂ O ₂ ) at a concentration of 1 to 500 kg / m of water in a normal state.

To prepare RAV No. 3, the water obtained in the generator 8 in the ultra-supercritical state is fed to block 9, into which the required amount of hydrogen peroxide is supplied from the vessel 10, resulting in the mixing of these components of the RAV No. 3, which at T is higher than 593 ° C at P from 23 to 50 MPa is fed into container 16.

RAV No. 4

RAV No. 4 is water in a supercritical state, saturated with 30-50% aqueous solution of hydrogen peroxide (H ₂ O ₂ ) in a concentration of 1 to 500 kg / m ³ of normal water.

To prepare RAV No. 4, the supercritical water obtained in the generator 8 is fed to block 9, into which the required amount of hydrogen peroxide is supplied from the vessel 10, resulting in the mixing of these components of the RAV No. 4, which at T from 380 to 593 ° C and P from 23 to 50 MPa, served in container 16.

RAV No. 5

RAV No. 5 is water in an ultra-supercritical state, saturated with 30-50% aqueous solution of hydrogen peroxide in a concentration of 1 to 500 kg / m ³ of normal water and an inhibitor of hydrogen peroxide (for example, sodium phosphate thermally stable at high temperatures - Na ₃ Po ₄ ). The required concentration of each of the components is determined empirically for each separate formation.

To prepare RAV No. 5, the water obtained in the generator 8 in an ultra-supercritical state is fed to unit 9, into which 30-50% aqueous solution of hydrogen peroxide and an inhibitor of hydrogen peroxide are supplied from vessel 10 by pump 11 and from vessel 14 by pump 15 in the above proportions , receiving as a result of mixing these components in block 9 RAB No. 5, which at T above 593 ° C and P from 23 to 50 MPa, is fed into the tank 16.

RAV No. 6

RAV No. 6 is water in a supercritical state, saturated with 30-50% aqueous solution of hydrogen peroxide in a concentration of 1 to 500 kg / m ³ of normal water and an inhibitor of hydrogen peroxide (for example, sodium phosphate - Na ₃ Po ₄ ). The required concentration of each of the components is always determined empirically for each separate reservoir.

To prepare RAV No. 6, the supercritical water obtained in the generator 8 is fed to unit 9, into which simultaneously hydrogen peroxide and a hydrogen peroxide inhibitor are supplied from the tank 10 by the pump 11 and from the tank 14 by the pump 15 in the above proportions, resulting in mixing of these components in block 9 RAV No. 6, which at T from 380 to 593 ° C and P from 23 to 50 MPa, is fed into the container 16.

RAV No. 7

RAV No. 7 is water in an ultra-supercritical state, saturated with Fenton's reagent, which consists of 30-50%) an aqueous solution of hydrogen peroxide in a concentration of 1 to 500 kg / m3 of water in a normal state and a catalyst in the form of iron II or III ions ( Fe ₂ +; Fe ₃ +). The required concentration of each of the components is determined empirically for each separate formation.

To prepare RAV No. 7, the ultra-supercritical water obtained in the generator 8 is fed to unit 9, into which hydrogen peroxide is supplied from the tank 10 by the pump 11 and from the tank 12 by the pump 13 water is supplied, saturated with a catalyst in the form of iron II ions (Fe ₂ + ), receiving as a result of mixing these components RAV No. 7, which at T above 593 ° C and P from 23 to 50 MPa is fed into the container 16.

RAV No. 8

RAV No. 8 is water in a supercritical state saturated with Fenton's reagent, which consists of a 30-50% aqueous solution of hydrogen peroxide in a concentration of 1 to 500 kg / m ³ of normal water and a catalyst in the form of iron II or III (Fe ₂ +; Fe ₃ +). The required concentration of each of the components is always determined empirically for each separate reservoir.

To prepare RAV # 8, the supercritical water obtained in the generator 8 is fed to unit 9, into which hydrogen peroxide is supplied from the vessel 10 by the pump 11 and from the vessel 12 by the pump 13 water is supplied, saturated with a catalyst in the form of iron II ions (Fe ₂ +), receiving as a result of mixing these components RAV No. 8, which at T from 380 to 593 ° C and P from 23 to 50 MPa is fed into the container 16.

RAV No. 9

RAV No. 9 is water in a supercritical state, saturated with an organic solvent, the concentration of which is from 1 to 500 kg / m ^{3 of} water in a normal state and ethanol (C ₂ H ₅ OH) at a concentration of 0.1 to 50 kg / m ³ water in good condition.

As an organic solvent can be used, in particular: (1) from the group of aromatic solvents, for example, benzene (C ₆ H ₆ ) (T _cr = 288.9 ° C, P _cr = 4.83 MPa), toluene, solvent, (2) from the group of chlorine-substituted hydrocarbons (chloroform (trichloromethane), carbon tetrachloride, etc.), (3) from the group of hydroaromatic solvents (tetralin, decalin, etc.),

To prepare RAV # 9, the supercritical water obtained in the generator 8 is fed to block 9, into which an organic solvent is supplied from the container 22 by the pump 23 and ethanol is supplied from the container 24 by the pump 25, resulting in mixing all the components of the RAV # 9, which at T from 374 to 593 ° C and P from 23 to 50 MPa are fed into container 16.

In tank 16, each prepared RAV is stored with maintaining a predetermined temperature, after which a high pressure pump (not shown) is pumped through the tubing string through the tubing string 18 into the productive formation 20.

According to the claimed method, the thermochemical impact on the pay zone is carried out cyclically, in five cycles, while each cycle includes several stages, and the first stage of each cycle is injection into the bottomhole zone of the pay zone, determined by the PAB, and the last (final) stage of each cycle is the stage of selection of hydrocarbons (water-oil emulsion) from the reservoir and their delivery to the day surface.

Cycle number 1.

The initial thermochemical impact (stage 1) on the productive formation is carried out using a previously prepared RAV No. 1 (each used further RAV is prepared in advance and stored in tank 16), which is supplied from tank 16 by a high-pressure pump along the tubing string with TYPE to the near-wellbore zone of the productive reservoir (reservoir zone No. 1). A feature of RAV No. 1 is that it has a very low density, which is approximately 94.645 kg / m ³ , as well as a low viscosity, and, therefore, has an increased penetrating ability.

The decision to use RAV No. 1 in the form of ultra-supercritical water or in the form of supercritical water is made in each individual case and depends mainly on the specific reservoir properties (reservoir properties) of the productive formation (porosity, permeability, water saturation, oil saturation, content ( %) C _org , etc.). In case of unfavorable reservoir properties of the productive formation, RAV # 1 is used in the form of ultra-supercritical water, which has a lower density compared to RAV # 1 in the form of supercritical water.

RAV # 1 in the form of ultra-supercritical water is used, as a rule, for an intense but short-term thermochemical effect on a productive oil-kerogen-containing formation, while RAV # 1 in the form of supercritical water is used, on the contrary, for a long-term thermochemical effect on a productive oil-kerogen-containing formation ...

When RAV # 1 penetrates into the near-wellbore zone (reservoir zone # 1), a near-well in-situ high-temperature retort is formed in it, in which, in addition to the already existing natural oil of tight rocks, synthetic hydrocarbons are generated due to the following processes: (1) "dry" and hydropyrolysis of kerogen, as a result of which liquid hydrocarbons (synthetic oil) and synthetic gas (syngas) are generated from kerogen, consisting mainly of H ₂ , CH ₄ , CO ₂ and CO, as well as organic acids (up to 2% of kerogen masses); (2) thermal cracking, catalytic cracking (in the presence of natural in situ catalysts / rock) and hydrocracking (in the presence of H ₂ generated in the reservoir) hydrocarbons (including bituminous oil) - partial improvement of their quality; (3) carbonization, predominantly, of low-quality heavy hydrocarbons - their transformation into nanoporous inorganic carbon; (4) multiple autofluid fracturing associated with an increase in the volume of in-situ fluids (as a result of their thermal expansion and an increase in intergranular bursting pressure), partial gasification of liquid hydrocarbons, as well as in-situ molecular modification of kerogen and generation of synthetic oil and syngas from it (substances generated from kerogen) have a volume 30% larger than the kerogen itself). All this leads to an increase in the amount of high-tech oil that can be delivered to the surface, as well as to a significant increase in porosity and permeability of the near-wellbore zone of the formation and the formation and its re-energization (increase in intra-formation pressure).

After the in-situ pressure reaches 45 MPa (on the example of a formation at a depth of 3000 meters), injection of RAV # 1 into the near-wellbore zone of the formation is stopped and the selection of high-tech oil begins (stage 2) in the well flowing mode.

In the process of withdrawing the oil-water emulsion, the in-situ pressure is controlled and, as soon as it drops to 32-33 MPa, the withdrawal of the water-oil emulsion is stopped and the next thermochemical action (cycle No. 2) is carried out on the productive formation.

Cycle number 2.

To implement this cycle, RAV # 7 is injected into the near-wellbore zone of the formation (formation zone No. 1) from reservoir 16 (first stage).

The use of RAV # 7 after RAV # 1 and the selection of water-oil emulsion in the first cycle allows to initiate intensified in-situ thermal explosions in the reservoir zone No. 1 due to the presence of ionic iron catalysts, as a result of which the improved permeability of the reservoir of the reservoir zone No. 1 formed at the first stage is significantly increases due to the formation, as a result of thermal explosions, of main fluid-conducting channels of relatively large thickness (from 50 to 300 nm), which is necessary for the second stage - the subsequent injection into the formation zone No. 1 of RAV No. 1 in the form of supercritical water for the next thermochemical action. When such RAV enters the formation zone No. 1, due to the fluid-conducting channels formed in the formation zone No. 1, as well as due to its high fluidity and low viscosity, it penetrates outside the formation zone No. 1 into the formation zone No. 2, in which it carries out , similar to the above, continuous generation of high-tech oil. It is very important that RAV No. 1 in the form of supercritical water is the most "economical" RAV, therefore it is it that is preferably used for long-term thermochemical impact on the oil-kerogen-containing formation.

As soon as the in-situ pressure reaches 45 MPa, injection into the near-wellbore zone of the RAV No. 1 formation in the form of supercritical water is stopped and the selection of high-tech oil begins (stage 3) in the well flowing mode. As a result of the selection of high-tech oil, which is accompanied by some compaction of the formation, especially of the formation zone No. 1, the permeability of the formation of the formation zone No. 1 gradually decreases, as well as the intra-formation pressure of the productive formation decreases; its energy.

As soon as the in-situ pressure drops to 32-33 MPa, the selection of high-tech oil is stopped and the next thermochemical action (cycle No. 3) is performed on the near-wellbore zone of the productive formation.

Cycle number 3.

To implement this cycle, RAV # 8 (first stage) is injected into the near-wellbore zone of the formation, which ensures the restoration of the permeability of the near-wellbore zone of the formation, which decreased as a result of the selection of high-tech oil (or water-oil emulsion) in the previous cycle. Reconstruction of the formation permeability is carried out due to the generation of intensified thermal explosions in the presence of ionic catalysts.

After the formation permeability is restored using RAV # 8, RAV # 2 is injected into the productive formation (second stage), the use of which ensures effective dissolution of micro or nanoscale layers of the productive formation, consisting mainly of resins and asphaltenes, including their cracking, as a result why new, mainly sub-horizontal planar micro and nanoscale fluid-conducting channels-planes are formed in such a productive formation; at the same time, to a lesser extent, but also the formation of new subvertical micro and nanoscale fluid channels occurs, which, in general, leads to a significant increase in the permeability and porosity of the bottomhole zone of the well.

After the completion of the injection of the required amount of RAV No. 2 into the reservoir, it is "put" for 24-48 hours to be impregnated with the RAV No. 2 injected into it to achieve the most complete dissolution of resins and asphaltenes.

The use of organic solvents, mainly aromatic solvents for the implementation of the method, provides not only a more intense dissolution of organic compounds (bitumoids) in the pores, but also a decrease in the strength of donor-acceptor interactions between individual fragments of the polymer matrix of organic matter (OM), which contributes to softer the conditions of its thermal destruction [4]. This makes it possible to increase the degree of conversion of OM (kerogen and bitumoids) and expand the range of products obtained.

After the completion of the reservoir impregnation process with RAV # 2, RAV # 5 or RAV # 6 (third stage) are injected into the pay zone, which are used to implement delayed / delayed thermal explosions in the reservoir, as a result of which the formation permeability (reservoir zones # 1 and # 2) increases. The use of RAV # 5 or RAV # 6 depends on the natural reservoir properties. So, RAV # 5 is used, preferably, to influence more distant zones of the formation (formation zone # 2), while RAV # 6 is preferably used to implement delayed / delayed thermal explosions in the formation zone # 1 and only partially in the reservoir zone No. 2.

As a result of the interaction in the supercritical in situ medium of an organic solvent, for example, benzene with hydrogen peroxide, an exothermic reaction of explosive oxidation of benzene takes place, lasting from 10 to 20 seconds, as a result of which in micro and nanosized local areas of the productive formation the pressure briefly reaches 70-80 MPa, and the temperature is 1100-1200 ° C. In these micro and nanoscale local areas of the productive formation, resins and asphaltenes under the action of high pressure and temperature are transformed into nanoporous dead carbon, and the process itself is accompanied by the generation of syngas, which, having H ₂ in its composition, significantly improves the quality of in-situ liquid hydrocarbons - high-tech oil ...

After stabilizing the pressure in the reservoir, - its some decrease, in the near-wellbore zone (layers of reservoir zones No. 1 and No. 2) for the implementation of thermochemical treatment, RAV No. 1 (fourth stage) is injected in the form of supercritical water for continuous generation of high-tech oil from kerogen, and also for partial improvement of the quality of hydrocarbons coming as a result of the filtration process into the near-wellbore zone from the periphery of the productive formation through the fluid channels formed due to the implementation of delayed / delayed thermal explosions in time and through the planar sub-horizontal channels that appeared in the productive formation as a result of the use of RAV No. 2.

As soon as the in-situ pressure reaches 45 MPa, injection of RAV # 1 in the form of supercritical water is stopped and the extraction (fifth stage) of high-tech oil begins.

As soon as the in-situ pressure drops to 32-33 MPa, the selection of high-tech oil is stopped and the next (cycle No. 4) thermochemical treatment is carried out.

Cycle number 4.

To implement this cycle, RAV # 3 or RAV # 4 are injected into the near-wellbore zone of the formation (first stage). The use of RAV # 3 or RAV # 4 depends on the natural reservoir properties and is used to carry out standard thermal explosions, which restore the formation permeability in the near-wellbore zone, which was previously subjected to thermochemical treatment using RAV # 1, 2, 5, 6, 7 and 8 ...

In this case, RAV # 3 is used to carry out standard thermal explosions, mainly in reservoir zone # 2, and RAV # 4 is used mainly to carry out standard thermal explosions in reservoir zone # 1.

Further, RAV # 1 (second stage) in the form of supercritical water is injected into the near-wellbore zone of the formation, for the implementation of a long-term thermochemical effect on the formation and the generation of high-tech oil.

As soon as the in-situ pressure reaches 45 MPa, injection of RAV No. 1 in the form of supercritical water is stopped and the withdrawal (third stage) of high-tech oil begins.

As soon as the in-situ pressure drops to 32-33 MPa, the selection of high-tech oil is stopped and the next (cycle No. 5) thermochemical treatment is carried out.

Cycle number 5.

To implement this cycle, RAV # 1 (first stage) in the form of ultra-supercritical water is injected into the near-wellbore zone of the formation, which ensures recovery, as well as an increase in porosity and permeability in the formation of formation zone # 1, after which RAV # 9 is injected (second stage). The injected RAV # 9 is used at the final stages of the in-situ retort development for dissolving heavy hydrocarbons, resins and asphaltenes in the most remote zones of the productive formation, namely, in the formation zone # 2 and beyond. So, for example, when the RAV # 9 of the formation zone is reached outside the formation zone # 2, its temperature (temperature of the RAV # 9), which, when injected into the pay zone, was, for example, 450 ° C, may decrease below the critical value (for water), for example, up to 320 ° C. In this case, water, which was previously in a supercritical state, will go into a subcritical state and its density at the same pressure (for example, 40 MPa) will increase from 270.8 kg / m ³ to 730.97 kg / m ³ , which will allow in the formation zones of the transition of water from the supercritical state to the subcritical state quite effectively (due to the sharply reduced volume of RAV No. 9 and an increase in its density), it will continue to penetrate into the productive formation. At the same time, at the same time, the dissolving capacity of subcritical water will sharply decrease. But organic solvents included in RAV No. 9, for example, benzene and ethanol, will continue to be in a supercritical state for a long time (for benzene T _cr = 288.9 ° C and for ethanol T _cr = 240.75 ° C) and, thus, respectively , continue to effectively dissolve resins and asphaltenes in the formation zones farthest from the wellbore (outside the formation zones No. 1 and No. 2).

The presence of ethanol in RAV No. 9 in combination, for example, with benzene leads to (1) an increase in the yield of liquid products from organic matter contained in the formation, (2) an increase in the rate of their formation by an average of 15-35%, depending on the quality of the organic matter, as well as (3) leads to a decrease in the proportion of high-molecular substances in the composition of the liquid products generated in the reservoir, which, in general, results in an improvement in the quality of the selected high-tech oil and leads to a higher oil recovery factor, in general.

As soon as the in-situ pressure reaches 45 MPa, the injection of RAV is stopped and the selection (third stage) of high-tech oil begins.

As soon as the in-situ pressure drops to 32-33 MPa, the selection of high-tech oil is stopped.

The mining process is complete.

Further, the cyclic thermochemical action in the above sequence with alternating use of RAV No. 1-9 and the selection of high-tech oil is continued until a certain volume of an in-situ retort with maximum permeability is formed and then - until the in-situ retort is completely worked out, - the maximum possible amount of liquid (high-tech oil) and gaseous hydrocarbons.

In the process of injecting RAV into the formation, the compensator 19 compensates for the thermal elongation of the tubing with TYPE 18, and in the process of withdrawing the oil-water emulsion from the formation, the compensator 19 compensates for the thermal shortening of the tubing with the TIP. Thermal elongation of tubing with TYPE is a consequence of transportation of high-temperature RAV (T not lower than 380 ° C and, preferably, not lower than 450 ° C) through tubing with TYPE for subsequent injection into the oil-kerogen-containing formation. Shortening of tubing with TIP is a consequence of the withdrawal of water-oil emulsion from the oil-kerogen-containing formation with its subsequent transportation to the day surface of the well along the tubing with TYP, and at the same time the temperature of the oil-water emulsion taken from the oil-kerogen-containing formation can drop to 250 ° C.

At the same time, the expansion joint 19 ensures the tightness and isolation of the volume of the well located above the expansion joint 19 from the volume of the well located below the expansion joint 19.

One of the possible algorithms for the implementation of cyclic thermochemical impact on the oil-kerogen-containing reservoir is presented in the Table.

New, in comparison with the solution - the closest analogue, in the claimed group of inventions is that in order to achieve the maximum degree of permeability in the largest possible volume of the in-situ retort, a wide range of technological methods is used, namely, for:

(1) the implementation of in-situ thermal explosions in the near-wellbore volume of the reservoir of the formation zone No. 1 are used by RAV No. 3 and No. 4;

(2) implementation of intensified in-situ explosions in the formation of formation zone No. 1 using RAV No. 7 and No. 8, saturated with a catalyst in the form of iron ions;

(3) implementation of delayed / delayed in time in-situ thermal explosions in remote zones of the formation of formation zone No. 2 using RAV No. 5 and No. 6, saturated with a hydrogen peroxide inhibitor, for example, sodium phosphate - Na ₃ Po ₄ ;

(4) implementation of dissolution of micro and nanoscale layers of a productive formation in reservoir zones No. 1 and partly No. 2, consisting mainly of resins and asphaltenes, RAV No. 2 is used, consisting of supercritical water and a solvent;

(5) implementation of dissolution of micro and nano-sized layers of the productive formation in remote formation zones No. 2 and No. 3, consisting mainly of resins and asphaltenes, RAV No. 9 is used.

(6) the implementation of an intensive, but short-term thermochemical treatment in productive formations, both with unfavorable and relatively normal reservoir properties, RAV No. 1 is used in the form of ultra-supercritical water;

(7) implementation of a long-term thermochemical effect on oil-kerogen-containing formations with any reservoir properties using RAV No. 1 in the form of water in a supercritical state.

The above use of RAV allows: (a) to maximize the zone of a productive formation (up to 10 meters) with high permeability; (b) increase the contact area of the in-situ retort with the volume of the productive formation not exposed to thermochemical action, and also (c) maximize directly the volume of the in-situ retort with the maximum permeability itself and, thus, maximize the oil recovery factor.

The above favorably distinguishes the claimed method from the solution - the closest analogue, in which the maximum increase in the permeability of the formation is possible in the redistribution of the near-wellbore volume, the radius of which does not exceed 1 meter.

So, for example, with a formation thickness of 30 meters, the area of contact with the formation of the outer surface of a vertical well (without thermal explosions and the use of an organic solvent and ethanol) with a diameter of 50 m is 28.26 m ² .

When implementing the technology disclosed in the solution - the closest analogue, the contact area of the outer surface of the volume of the in-situ retort with maximum permeability (V = 94.2 m ³ ) with the rest of the volume of the in-situ retort is 188.4 m ² , and when using the claimed group of inventions the area the contact of the outer surface of the volume of the in-situ retort with the maximum permeability (V = 9420 m ³ ) with the rest of the volume of the in-situ retort is already 1884 m ² .

The claimed group of inventions provides an increase in the efficiency of thermochemical impact on oil-kerogen-containing formations, which leads to a significant increase in oil recovery factor of all zones of the formation.

Sources of information

[1] PART II: North America Tight Oil - Economics and Fiscal Competitiveness. Play Economics and Supply Prices. RODGERS. Oil and Gas Consulting. April 4, 2013.

[2] ND Monthly Bakken * Oil Production Statistics. * Includes Bakken, Sanish, Three Forks, and Bakken / Three Forks Pools. August, 2018. https://www.dmr.nd.gov/oilgas/stats/historicalbakkenoilstats.pdf

[3] A.M. Brekhuntsov, I.I. Nesterov (2010), OJSC RN Yuganskneftegaz.

[4] Pavlusha Evgeny Sergeevich. THERMAL DISSOLUTION OF COMBUSTIBLE SHALES IN THE MEDIUM OF SUPERCRITICAL FLUIDS. ABSTRACT of the thesis for the degree of candidate of chemical sciences. Kemerovo - 2012.

Claims (2)

1. A method for increasing the efficiency of production of high-tech oil - hydrocarbons from an oil-kerogen-containing formation, including thermochemical effects on the productive formation by working agents prepared on the day surface and injected in a predetermined sequence into the near-wellbore zone of the productive formation along a string of insulated tubing, followed by withdrawal from it in the mode of flowing a well of an oil-water emulsion, consisting mainly of water, liquid and gaseous hydrocarbons, including synthetic, and other gases, by delivering it to the day surface along a column of insulated tubing, characterized in that the production process is carried out cyclically, each of cycles includes several stages, the first stage of each cycle is the stage of injecting a working agent into the productive formation, and the last is the selection of an oil-water emulsion from the productive formation, and at the stage of oil withdrawal of each cycle The in-situ pressure is monitored and, as soon as it drops to a predetermined value, production is stopped, while, during the first cycle, at its first stage, a near-wellbore zone with increased permeability is formed in the productive formation by injecting a working agent in the form of water into the productive formation, having a temperature above 593 ° C at a pressure of 23 to 50 MPa, and this working agent generates the action of synthetic hydrocarbons in the near-wellbore zone, followed by the stage of selecting the water-oil emulsion and delivering it to the day surface, after which a second cycle is carried out, at the first stage of which in the near-wellbore zone of the productive formation, main fluid-conducting channels are formed due to the implementation of in-situ thermal explosions, which are carried out by injecting into the near-wellbore zone of the working agent in the form of water with a temperature above 593 ° C and a pressure of 23 to 50 MPa, saturated with Fenton's reagent - a feather hydrogen oxide and a catalyst in the form of iron ions Fe ₂ + or Fe ₃ +, after which, at the second stage, before withdrawing the water-oil emulsion and delivering it to the day surface, synthetic hydrocarbons are generated in the near-wellbore zone by injecting a working agent in the form of water into the near-wellbore zone temperature from 380 to 593 ° C at a pressure of 23 to 50 MPa, and at the first stage of the third cycle, the permeability of the near-wellbore zone of the productive formation is restored, for which a working agent is injected into it, consisting of water with a temperature of 374 to 593 ° C at a pressure from 23 to 50 MPa, saturated with Fenton's reagent, after which, at the second stage, the resins and asphaltenes contained in the reservoir are dissolved by injecting a working agent of action into its near-wellbore zone, consisting of water, with a temperature of 374 ° C and up to 593 ° C at pressure from 23 to 50 MPa, saturated with an organic solvent, after which, in the third stage, in the near-wellbore zone of the productive formation, additional fluid-conducting channels are injected into the near-wellbore zone of the working agent in the form of water with a temperature above 593 ° C at P from 23 to 50 MPa, saturated with Fenton's reagent, or the working agent in the form of water with a temperature of 374 to 593 ° C at Р from 23 to 50 MPa, saturated with hydrogen peroxide and hydrogen peroxide inhibitor, after which, at the fourth stage of this cycle, synthetic hydrocarbons are generated in the productive formation by injecting a working agent of action into the near-wellbore zone, consisting of water, with a temperature of 374 to 593 ° C at a pressure from 23 to 50 MPa, followed by the selection at the fifth stage of the generated oil-water emulsion from the productive formation and its delivery to the day surface, after which, at the first stage of the fourth cycle, the permeability of the productive formation is restored due to the thermochemical effect of the working agent injected into the near-wellbore zone exposure in the form of water with a temperature above 593 ° C at a pressure of 23 to 50 MPa, saturated with hydrogen peroxide, or the working agent of exposure in the form of water with a temperature of 374 to 593 ° C at a pressure of 23 to 50 MPa, saturated with hydrogen peroxide, and then on at the second stage, synthetic hydrocarbons are generated due to the thermochemical effect of a working agent injected into the near-wellbore zone, consisting of water, with a temperature of 374 to 593 ° C at a pressure of 23 to 50 MPa, followed by withdrawal at the third stage of the fourth cycle of an oil-water emulsion and its delivery on the day surface, after which, at the first stage of the fifth cycle, the permeability of the near-wellbore zone of the productive formation is restored due to the thermochemical effect of the working agent injected into the near-wellbore zone of the action in the form of water having a temperature above 593 ° C and up to 650 ° C at a pressure of 23 to 50 MPa , after which, in the second stage, the resins and asphaltenes of the product are dissolved formation due to the thermochemical effect of the working agent injected into the near-wellbore zone, consisting of water with a temperature of 374 to 593 ° C at a pressure of 23 to 50 MPa, saturated with an organic solvent, the concentration of which is from 1 to 500 kg / m ^{3 of} water in normal state and ethanol -C ₂ H ₅ OH in a concentration of 0.1 to 50 kg / m ^{3 of} water in a normal state, followed by the selection at the third stage of this cycle of water-oil emulsion and its delivery to the day surface. 2. Technological complex for the production of hydrocarbons from oil-kerogen-containing formations, including a water treatment unit, the inlet of which can be connected to a water source, a generator designed to produce water with a pressure of 23 MPa to 50 MPa and a temperature of 374 ° C to 593 ° C and above , a string of heat-insulated tubing, placed in the casing of the well to its bottom and intended for injecting working agents into the productive formation of the well and removing from it with delivery to the day surface of high-tech oil, as well as tanks for storing components intended for preparing workers agents of exposure, characterized in that the complex is equipped with a block for the preparation of working agents of exposure, a container for storing and dispensing prepared water, as well as a container for storing and dispensing prepared working agents of exposure, as containers for storing components intended for preparing work agents of exposure, tanks were used for storing hydrogen peroxide, for storing water saturated with a catalyst in the form of iron ions - Fe ₂ +, for storing water saturated with a hydrogen inhibitor, for storing organic solvents, for storing ethanol, while a capacity for storing and dispensing prepared water is connected inlet to the outlet of the water treatment plant, and the outlet to the inlet of the water generator, the outlet of which is connected to the inlet of the unit for preparation of working agents of influence, to the inputs of which the above-mentioned containers for components of working agents of influence are also connected, the outlet of the unit for preparation of working agents of influence is connected to the inlet of the tank for storing and dispensing the prepared working agents of action, the outlet of which has the ability to connect to the tubing string, into which the compensator of thermobaric changes in the length of the tubing string is built in, which has the possibility of hermetic contact with the internal surface casing for dividing the well into two volumes sealed from each other - above-packer and below-packer.

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