RU2542000C1 - Procedure for increase of producing ability of wells (versions) - Google Patents

Abstract

FIELD: oil and gas industry.

SUBSTANCE: according to the method the first and second banks are injected through a hydrocarbon- or water-based displacement fluid to the designed area of the well. At that the availability of a residual saturation area is determined in productive formations with loose - loosely cemented porous and/or fractured reservoirs. The availability of an ultimate water saturation area, an undersaturated transition interval with a film water area and an intensive flow of water diffuse layers and a subarea of high oil content is determined. The availability of ultimate oil saturation is determined. The availability or unavailability of shale barriers at boundaries of the ultimate water saturation area and the transition interval is considered. The water saturated area is cut from the ultimate oil saturation area and an oil inflow is ensured to the productive formation from the subarea of high oil content. Injection is made to the design area of a producer and/or injector. At that the displacement fluid in injected in a quantity of 0.1 up to 500% of the first bank volume. The second bank is injected in a quantity of 0.1-250% of the first bank volume. Polymer resin is used as the first bank. Polymer hardener is used as the second bank. Upon injection the well is transferred to the hydrocarbon inflow mode.

EFFECT: increased efficiency of the method.

24 cl, 47 ex, 1 dwg

Description

The invention relates to the oil and gas industry, and in particular, to methods for increasing well productivity by increasing well production.

A known method of isolating water in the bottom-hole zone of a producing well, comprising injecting polymer resin and hardener or oil-cement mixtures into the formation, the waterproofing material being placed in a well-defined annular space around the wellbore. And the volumes of the waterproofing composition and the squeezing fluid are determined based on the current values of the injectivity of the well, the shutter speed of the well at rest, and the well is put into the inflow of hydrocarbons (RF Patent No. 2232229, E21B 33/13, published on June 10, 2008).

The disadvantages of this technical solution is that the increase in well productivity is associated with isolation of the bottomhole zone, which is carried out taking into account the determination of the injection volume of the components, while the injection volume is determined depending on the current values of the injectivity of the well and the radius of equipotentials, but during the operation of the well, the injectivity change, which complicates the process of determining the volume of injection of components, in addition, the injection into the reservoir of components is carried out in a strictly defined annular space around the wellbore and without taking into account the zonal structure of the gas-oil deposit.

A known method of isolating water inflow zones in a well, comprising sequentially injecting polymer resin into a water inflow zone through a water-based release fluid, injecting a hardener of a polymer composition (RF Patent No. 2237797, E21B 33/128, publ. 10.10.2004).

The disadvantages of this technical solution is that the increase in well productivity is associated with the isolation of water inflow zones, which is carried out without taking into account the zonal structure of the gas-oil deposit in height and the nature of the violation, which requires additional opening of the reservoir, and this leads to the formation of additional cracks connecting the water reservoirs to the productive reservoir, and reduces the thickness of the reservoir.

The closest technical solution is a method of increasing the productivity of wells, including injecting the first and second rims into the formation, injection is carried out through a separation liquid on a hydrocarbon or water basis into the area of the reservoir or above the perforation interval and the well is successively transferred to the hydrocarbon inflow mode, while the injection the separation fluid is carried out in an amount of from 0.1 to 50% of the volume of the first rim, and the injection of the second rim is carried out in an amount of from 10 to 150% of of the first rim, the first rim is additionally equipped with a pore former in an amount of 0.1% to 15% of the volume of the first rim, polymer resins are used as the first rim and polymer hardeners are used as the second rim, which additionally injects a component containing a viscoelastic pack hydrocarbon or water base in an amount of from 70% to 1000% of the volume of the first rim, which additionally injects a component containing cement mortar in an amount of from 30 to 400% of the volume of the first second rim (RF patent №2492317, E21B 43/22, publ. 09/10/2013, prototype).

The disadvantages of this technical solution is that the increase in well productivity is associated with the isolation of water inflow zones, which is carried out without taking into account the subzone of loosely coupled water in the transition zone, since, cutting off this subzone from the reservoir, the annulus flow is cut off, and without this additive, reservoir water having high density, enters the perforation interval from below or from above and prevents the flow of lighter oil from the reservoir and, accordingly, reduces the flow of oil from the product ivnogo layer as a whole, besides water shutoff zones is carried out without considering the presence or absence of clay webs at the boundaries of the limit of saturation zone and transition zone.

The proposed method for increasing the productivity of wells will eliminate the above disadvantages, in addition, it can increase the productivity of the well by injecting polymer compositions into production and / or injection wells, which thicken the reservoir, while taking into account the subzones of loosely bound water in the transition zone and the presence or absence of clay bridges at the boundaries of the marginal water saturation zone and the transition zone, cutting off the water saturation zone from the marginal oil saturation zone and thereby receiving an influx of additional additional oil from the transition zone and attaching it to the reservoir, the method of increasing the productivity of the wells involves injecting the first and second rims through a separation liquid on a hydrocarbon or water basis into the calculated area of the producing and / or injection wells, while into the producing and injection wells the injection is carried out simultaneously, the release fluid is pumped in an amount from 0.1 to 500% of the volume of the first rim, the second rims are pumped in an amount of from 0.1 to 250% of the volume of the first rim and, as the first rim, use a polymer resin, as the second rim use a polymer hardener, after injection, transfer the well to the hydrocarbon flow mode, use a liquid or powdery polymer hardener of acidic or neutral composition as a polymer hardener, and dry cement is injected and / or a hydrocarbon-based cement mortar in an amount of from 0.1 to 2000% of the volume of the first rim through a water-based release fluid, which is additional the hydrocarbon-based cement mortar is injected in an amount from 0.1 to 2000% of the volume of the first rim through a water-based separation fluid, the well is kept at rest for a predetermined time interval after the second rim is injected, the separation fluid is additionally equipped with a blowing agent in the calculated quantity, the first rim is additionally equipped with a blowing agent taken in the calculated amount, the second rim is additionally equipped with a blowing agent taken in p in an estimated amount, powdered or liquid products are used as a blowing agent, and an alkaline liquid or powdery polymer hardener is used as a polymer hardener.

A method of increasing well productivity involves injecting a viscoelastic pack, first and second rims through a separation fluid into the calculated area of the producing and / or injection wells, while simultaneously injecting into the producing and injection wells, from 0.1 to 5000% are injected into the viscoelastic pack from the volume of the first rim, the second rims are pumped in an amount from 0.1 to 250% of the volume of the first rim, the release fluid is pumped in an amount from 0.1 to 500% of the volume of the first rim and cement or a cement mortar is pumped in an amount from 0.1 to 2000% of the volume of the first rim, a polymer resin is used as the first rim, a polymer hardener is used as the second rim, and water-based or hydrocarbon-based cement mortar is used as the cement mortar, after injection carry out the transfer of the well into the mode of hydrocarbon inflow, additionally carry out the shutter speed of the well at rest for a predetermined time interval after injection of a water-based release fluid, the first hole the bag is additionally equipped with a blowing agent taken in the calculated amount, the second rim is additionally equipped with a blowing agent taken in the calculated amount, an additional separation fluid is injected in an amount from 0.1 to 500% of the volume of the first rim after injection of a viscoelastic pack, the separation fluid is additionally equipped with a blowing agent in calculated amount, as a blowing agent, powdered or liquid products are used.

A method of increasing well productivity includes injecting the first and second rims through a separation fluid, a viscoelastic pack into the calculated area of the producing and / or injection wells, while simultaneously injecting into the producing and injection wells, the second rims are pumped in an amount of 0.1 to 250% from the volume of the first rim, viscoelastic packs are pumped in an amount of from 0.1 to 5000% of the volume of the first rim, dry cement and / or cement or polymer-cement mortar is pumped in an amount of from 0.1 to 2000% by volume the first rim, using a polymer resin as the first rim, using a polymer hardener as the second rim, using a water-based or hydrocarbon-based cement mortar as a cement mortar, and after injecting, the well is transferred to the hydrocarbon flow mode, as a hardener a polymer hardener is a liquid or powdery polymer hardener of an acidic or neutral composition; a liquid or powdery hardener is used as a polymer hardener a polymeric hardener of an alkaline composition, additionally holding the well at rest for a predetermined time interval after injection of the second rim, the first rim is additionally equipped with a blowing agent taken in the calculated amount, the second rim is additionally equipped with a blowing agent taken in the calculated amount, powder or liquid products are used as the blowing agent .

In the proposed method for increasing the productivity of wells, for example, NGL, gasoline, acetone, solvent, substandard gasoline, Sinol-M and gas condensate are used, oil-based oil and emulsifier, fresh water, process water.

Formaldehyde resins, such as urea-formaldehyde (urea-formaldehyde, urea) resin, for example Rezoyl-K phenol-formaldehyde, for example Rezoyl-F, phenol-resorcinol-formaldehyde, for example FRF-50P, are used as polymer resins. or FRF-50RM, melamine-formaldehyde resin, phenol-aniline-formaldehyde resin, aniline-formaldehyde resin, thiourea-formaldehyde resin, sulfamide-formaldehyde resin, and other formaldehyde resins, as meeting standards, for example, GOST 16388-70, 16704-71, TU 13-3 69-77, TU 6-10-1192, and those that do not meet the standards, that is, the newly developed brand of formaldehyde resin.

Resins (polycondensation products) phenol-resorcinol-formaldehyde brands FRF-50R or FRF-50RM are produced according to TU-6-05-1638-78. FRF-50P or FRF-50RM are porous or monolithic resins. Resoil-K resins are produced according to TU 2221-637-55778270-2004, amendment 1 of 08.25.2010. Resoil-F brand resins are produced according to TU 2221-669-55778270-2004, rev. No 1 on December 10, 2010

As a polymer hardener, a liquid or powder hardener of an alkaline, acidic or neutral composition is used.

For example, for high-temperature formations from +80 to + 150 ° C, neutral powdery hardeners are usually used, which are added to the resin or hardener and mixed on the surface. In rare cases, a liquid hardener is used; for reservoir temperatures from + 50 ° C to + 80 ° C, mostly alkaline liquid or powder hardeners are used. Since the use of acid hardeners for these formation temperatures can lead to the destruction of the cement ring. The resin and hardener in this reservoir temperature range are mainly used separately, through the separation pack in series. In rare cases, the resin and hardener are mixed on the surface;

for reservoir temperatures from + 30 ° C to + 50 ° C, both acidic and alkaline hardeners are used. To obtain a monolithic resin they are mixed on the surface, and to obtain a porous material they are used sequentially through a separation pack;

for reservoir temperatures below + 30 ° C, it is recommended to use acid hardeners, consisting of a mixture of organic acids. To obtain a monolithic resin, they are mixed on the surface, and to obtain a porous material, they are used sequentially through a separation pack. At low reservoir temperatures, acid solutions do not interact with the cement ring and do not violate its integrity. The polymerization of the composition occurs due to changes in the pH of the medium.

The composition also takes into account the compatibility of hardeners with pore formers and host rocks.

As a liquid polymer hardener use, for example, the composition of the polymer hardener "GEOTERM".

As an alkaline liquid polymer hardener, for example, a solution of urotropine in formalin is used, manufactured according to TU 6-05-281-22-89 or TU 2257-001-50527705-2012.

As the acidic liquid polymer hardener, for example, a solution of organic acids is used, for example, produced according to TU 2257-001-50527705-2012.

As a neutral liquid polymer hardener, for example, a solution manufactured according to TU 2257-001-50527705-2012 is used.

As a powdery polymer hardener use, for example, "GEOTERM-101 to 122", manufactured according to TU 2257-001-50527705-2012.

As a porogen, powdered or liquid products are used, which are added depending on the selected type of component and the particular geological structure of the application, for example, carbon ammonium salt, sodium carbonates or bicarbonates, aluminum or magnesium powder.

The amount of blowing agent is set, including depending on the selected type of component, and the features of the geological structure of the application. The type of pore-forming agent is chosen, including the pressure of injection of the composition into the calculated area, taking into account its compatibility with polymer resin and hardener, since it is difficult to choose the type of pore-forming agent by granulometric composition and in many cases, especially in loose collectors, the selection of core material is insignificant (is less than 50%), and the sample taken modulo size will not be representative.

The polymer resin is further provided with a pore former in an estimated amount.

The polymer hardener is additionally equipped with a pore-forming agent in an estimated amount, while the amount of pore-forming agent in it is set depending on the selected type of polymer hardener.

The separation fluid is additionally provided with a pore former in an estimated amount, which further increases the productivity of the well by creating additional lateral filtration.

For example, at an injection pressure of up to 40 atm, the blowing agent is added to the resin or in the hardener, or in a separating liquid, at an injection pressure of 40 to 60 atm, the blowing agent is added to the resin, hardener or in the resin, a separating liquid, at an injection pressure of over 60 atm, the blowing agent is distributed evenly in resin, release fluid, hardener.

The components of the blowing agent, resin, hardener used in the calculated amount in the claimed Method are presented in the ready-made polymer compositions "GEOTERM" from 01 to 22, manufactured according to TU 2257-075-2616159797-2007 or TU 2257-001-50527705-2012, for example , the blowing agent is added at the factory, or to the resin - the composition "Geotherm-11", or to the hardener - the composition "Geotherm-22", or stirred on the surface before injection together with a polymer resin and hardener, for example the composition "Geotherm-04", "Geotherm-05", "Geotherm-08".

As dry cement, for example, brand G cement is used.

As a hydrocarbon-based cement mortar, for example, a dry cement solution with diesel fuel in an estimated amount, a dry cement solution with degassed, dehydrated oil in an estimated amount are used.

As a water-based cement mortar, for example, an aqueous cement mortar with a density of 1.75-1.8 t / m ^{3 is used} .

As a polymer-cement solution, for example, resin solutions with a hardener and cement with a density of 1.45-1.5 t / m ^{3 are used} .

The injection volumes of the first rim, blowing agent, as well as the choice and necessity of injecting components, such as dry cement, cement slurry, depend primarily on the transfer of the well to other production facilities when the previous production facility has exhausted its oil and gas reserves, as well as on the position of the oil and water contact (BHC) and gas-oil contact (SOC), taking into account the presence or absence of clay bridges at the boundaries of the zone of maximum water saturation and the transition zone; the permeability of the reservoir, closely related to the oil saturation coefficient, permeability and the saturation coefficient associated with it, divide the boundary of transition zone B and subdivide it into two subzones: B1 and B2.

It is known that in natural reservoir rocks there is strongly bonded (adsorbed), loosely bonded (water of diffuse layers) and free water. This division is true for artesian basins in the presence of a homogeneous fluid in the reservoir - formation water. In oil and gas-oil deposits, the distribution of water by their height is more complicated.

In nature, there are no clear boundaries between reservoir fluids, and free gas, mobile in the usual sense, oil and free water are separated in the deposits according to the gravitational-capillary principle. The law of variation of water saturation of rocks by the height of oil and gas deposits is the same: water saturation naturally increases as one approaches a completely water-saturated rock (the “free water mirror”).

The higher the contrast of the porometric characteristics of the contacting layers in the reservoir and the higher the heterogeneity (dissection) of its structure, the more complex the nature of the change in the residual water saturation along the height of the reservoir. The nature of the distribution of water saturation over the height of a real reservoir is obtained by plotting the changes in k _in or k _ng depending on the absolute depth of the beds (or vertical removal from the VNK mark) for all wells in the field. The height of each zone depends on the geological features of the structure and formation conditions of the reservoir and reservoir properties of the rocks.

Of the features of the adopted development system in the proposed method also take into account the presence of breakthroughs of injected water into the wellbore of the producing well. The ability to eliminate injected water during the work to increase the productivity of wells, including RIR, in the injection well, as well as the feasibility of carrying out work to increase the productivity of wells, including PUP, simultaneously in the production and in the injection well, while in the production well, including with the aim of eliminating breakthroughs, and in the injection, including with the aim of leveling the injectivity profile of the injected water. The proposed method of increasing the productivity of wells allows for similar work.

The drawing shows a graph of changes in the gradient of oil saturation along the section of the oil deposits of the Fedorovskoye field, where zones: A - water saturated, B - residual oil saturation, C - undersaturated transition, while B1 - the zone of loose-bound water with an intensive flow of diffuse layers of water, B2 - subzone of high content oil, and zone G - marginal oil saturation.

A method of increasing well productivity is as follows.

It determines the injection volumes and sequence, the cyclical injection of components depending on the transfer of the well to another production site, the position of the oil-water contact (WOC) and the gas-oil contact (GOC), taking into account the presence or absence of clay bridges at the boundaries of the zone of maximum water saturation and transition zone and permeability of the formation.

The initial volume of the polymer composition, taking into account the thickness of the interval of the reservoir, is determined, for example, equal to less than two thicknesses of the interval of the reservoir.

In recent years, another type of collector has been distinguished, which in one case is called loose, in the other case, weakly cemented reservoirs. By the volume of injection of repair-insulating compositions, they cannot be attributed to pore collectors. This erroneous approach was used at one time in the Barsukovsky field of the Purovsky oil and gas region, where the injected large volumes of repair-insulating compositions led to the formation of multiple behind-the-casing flows, which are still struggling with. The proposed method takes into account the features of loose reservoirs, by pumping the composition in the process of increasing the productivity of wells with estimated volumes, sometimes in two, three stages.

When transferring a well to another production facility, the volumes of injected compositions are determined, for example, equal to the volume of the thickness of the production string, the additional volume of the production string 5-15 m higher than the upper holes of the perforation interval plus the volume of pore space by 0.3 m ^{3 of the} volume of the annular space of the perforation interval.

For example, before carrying out work to increase the productivity of wells, the tubing shoe is set 10-15 m higher than the upper holes of the perforation interval and is pumped sequentially into the tubing, for example, a viscoelastic bundle (WCS) in a volume of 0.5-1.5 m ³ , then resin into volume of 0.5-1.5 m ³ with the addition of a blowing agent, plus a release fluid in a volume of 0.1-0.5 m ³ with the addition of a blowing agent, then a hardener in a volume of 0.5-1.5 m ³ with the addition of a blowing agent, followed by fresh water and cement or oil-cement (polymer-cement) solution in a volume of 1-3 m ³ and completes this The position is fresh water again.

Water-based release fluid is used in wells if saline is present in the well. The above composition is adjusted to the tubing shoe or to equal pressures: injection pressure at the wellhead and pressure of the pressure test casing (e / k).

After the equality of pressures: injection pressure at the wellhead and pressure of pressure testing of electric power or pushing the entire volume of the composition to the tubing shoe, wash the remainder of the composition, raise the tubing to a safe height of 100-150 m and seal the wellhead under injection pressure for 24 hours. or earlier, based on the results of setting surface samples, a polymer-cement "glass" is pressed, drilled and again pressed, and if the results of the crimping are positive, then the work performed is considered successful. Such work is carried out when transferring wells to the operation of underlying objects, when transferring wells to overlying objects and drilling a polymer-cement glass is not provided.

Work to increase well productivity, for example, providing, including increasing the annular space, provides that after injection of the second rim of the wellhead, the wellhead is sealed for a period of several hours to a day in order to create lateral filtration in the most permeable zones of the formation. And the well is mastered or cement, oil-cement or polymer-cement mortar is pumped into the well. If necessary, repeat the operation.

The presence of clay bridges at the border of the zones significantly reduces the volumes of injected components and in general they range from 1 to 3 m ³ . The absence of clay bridges, on the contrary, significantly increases the volumes of injected components, especially for the initial viscoelastic bundle, which in this case can be up to hundreds of m ³ , have a complex chemical-physical composition and vary both in density and viscosity depending on thickness transition zone.

For example, the volume of the composition is calculated from the calculation of the thickness of the cut-off (separation) bridge at the border B1 and B2 with a thickness of 1.5 m and the radius of the depression funnel equal to two thicknesses of the reservoir in the pore reservoirs; one thickness of fractured-pore reservoirs and 0.5 thickness in fractured reservoirs.

By permeability and saturation coefficient, the boundary of transition zone B is divided and it is divided into two subzones: B1-residual oil saturation and B2 — the zone of undersaturation of the pore volume of the reservoir with oil. It is practically impossible to get anhydrous oil flow from subzone B1, and from an subzone B2 when installing a dividing bridge at their border, when certain conditions and treatments are created, it is possible to obtain inflows of anhydrous oil.

Into an injection and / or production well, having a depth of 100 to 5000 m, through a tubing or flexible pipe, additionally equipped with a different type of packer or jet pump, launched into the settlement area simultaneously or sequentially pump the first rim in the calculated quantity and the second rim in the amount of 0.1 to 250% of the volume of the first rim through the separation fluid in an amount of from 0.1 to 500% of the volume of the first rim or a separation liquid in the amount of 0.1 to 500% of the volume of the first rim with a blowing agent in the calculated amount and then they are pushed in a predetermined area, for example the area of the bottom portion of the producing formation of the production well.

According to the testimony of the well, the well is additionally kept at rest - the well is left to undergo a polycondensation reaction in the calculated area of the well, then the well is transferred to the hydrocarbon flow mode, that is, it is developed, washed and put into operation.

For example, in a sequential injection, a separation liquid, for example, NGL, or gasoline, or acetone, or a solvent, or substandard gasoline, is pumped in an amount from 0.1 to 500% of the volume of the first rim or a separation liquid with a blowing agent in an estimated amount, for example , 10% of the volume of the first rim.

Then, in a calculated amount, the first rim in the form of a formaldehyde resin is pumped, for example, FRF-50R, FRF-50RM polymer resin, GEOTERM polymer resin or the first rim with a blowing agent, for example, FRF-50R polymer resin with carbonate, FRF-50RM with bicarbon sodium, in a calculated amount, for example, a blowing agent is introduced into the first rim in an amount of 20% of the volume of the first rim.

Behind the first rim, a separation liquid is injected in an amount of from 0.1 to 500% of the volume of the first rim, for example, NGL, or a separation liquid with a blowing agent, with a separation fluid in an amount of from 0.1 to 500% and a blowing agent in an estimated amount, for example , 10% of the volume of the first rim.

After that, the second rim is pumped in an amount from 0.1 to 250% of the volume of the first rim, for example, an alkaline hardener solution, a polymer hardener "GEOTERM-101".

After the second rim, a separation liquid is pumped in an amount of from 0.1 to 500% of the volume of the first rim, for example, gasoline, or a separation liquid with a blowing agent, while the separation fluid is in an amount of from 0.1 to 500% and a blowing agent in an estimated amount, for example , 12% of the volume of the first rim.

For example, while components are being pumped in, the release liquid is first pumped in the calculated amount in an amount of 0.1 to 500% of the volume of the first rim, for example, acetone, the composition is pumped in the calculated quantity: the first rim, the second rim, and the second rim is taken in an amount of from 0.1 to 250% of the volume of the first rim.

After that, a separation fluid is pumped in an amount of from 0.1 to 500% of the volume of the first rim or a separation fluid with a blowing agent, with a separation fluid in an amount of from 0.1 to 500% and a blowing agent in an estimated amount, for example, 25% of the volume of the first fringes.

Further, according to the testimony of the well, dry cement and / or cement mortar are additionally pumped in an amount of from 0.1 to 2000% of the volume of the first rim through a water-based separation liquid in an amount of 0.1 to 500% of the volume of the first rim in the calculated area and sequentially .

The annulus is closed and the composition is forced into the calculated area of the well, while the last injection of the component, for example, the separation fluid, is brought to the calculated area, for example, the area of the bottom of the productive formation of the producing well.

According to the testimony of the well, the well is kept at rest, then the well is transferred to the hydrocarbon flow mode, that is, it is developed, washed and put into operation.

When components are sequentially injected directly into the transitional subzone B1 of the well or simultaneously into the well of the producing well and into the well of the injection well, initially occurs: the water saturation zone A is cut off from the oil saturated zone G, and then the subzone B1 is cut off from the subzone B2.

If, for example, the oil production rate decreases and the production of produced water and gas in the producing well decreases, the work on the injection of the claimed components is repeated many times.

Into an injection and / or production well, having a depth of 100 to 5000 m, through a tubing or flexible pipe, additionally equipped with a packer of various types or a jet pump, lowered into the calculation area simultaneously or sequentially pump a viscoelastic pack in an amount of from 0.1 to 5000% of the volume of the first rim, the first rim in the calculated amount and the second rim in an amount of from 0.1 to 250% of the volume of the first rim through a dividing liquid in an amount of from 0.1 to 500% of the volume of the first rim and cement or polymer cement the thief in an amount of from 0.1 to 2000% by volume of the first rim, and then forced them in a predetermined area, e.g., area of the bottom portion of the productive formation of the production well.

According to the testimony of the well, the well is additionally aged at rest for a predetermined time interval after injection of a water-based release fluid.

Then, the well is transferred to the hydrocarbon inflow mode in the producing well and the fluid is injected into the injection well.

Into an injection and / or production well, having a depth of 100 to 5000 m, through a tubing or flexible pipe, additionally equipped with a different type of packer or jet pump, launched into the settlement area simultaneously or sequentially pump the first rim in the calculated quantity and the second rim in the amount of 0.1 to 250% of the volume of the first rim, then a viscoelastic pack in an amount of from 0.1 to 5000% of the volume of the first rim and dry cement and / or cement or polymer-cement mortar in an amount of from 0.1 to 2000% of the volume of the first rim and then push them into the settlement area, for example, the area of the transition zone B1 injection wells.

According to the testimony of the well, the well is additionally aged at rest for a predetermined time interval after injection of a water-based release fluid.

Then, the well is transferred to the hydrocarbon inflow mode in the producing well and the fluid is injected into the injection well.

The proposed Method was tested in the field at the wells of the Russian Federation, including the wells of the Tyumen region:

Example No. 1

At the well that opened the fractured-porous reservoir in the interval 1800-1810 m, work was carried out to increase oil recovery by preventing the flow of produced water from the bottom of the reservoir — the transition zone into the wellbore. Prior to oil recovery enhancement, the well had the following parameters:

Oil production rate - 1.6 tons / day; water cut - 98%.

They were pumped into the wellbore into the transition zone (B1) at the injection pressure Rnach. = 20 atm and Rkon. = 40 atm at the same time: Geotherm-002n polymer resin in an amount of 1 m ³ , BFLH in an amount of 0.1 m ³ (10% of the volume of the first rim), Geotherm-102n polymer hardener in an amount of 0.1 m ³ ( 10% of the volume of the first rim).

After carrying out work to increase oil recovery, the well had the following parameters:

oil flow rate - 8.6 tons / day; water cut - 18%.

The injection of components directly into the transition zone (B1) made it possible to cut off the water saturation zone (A) from the marginal oil saturation zone (G) and thereby increase oil recovery by 7 tons / day due to additional oil inflows from the transition zone (B2) and its addition (B2) to the reservoir.

Example No. 2

At the well that opened the porous reservoir in the range of 1820-1832 m, work was carried out to increase oil recovery by preventing the flow of formation water from the bottom of the formation into the wellbore of the producing well. Prior to oil recovery enhancement, the well had the following parameters:

Oil production - 2.4 tons / day; water cut - 97%.

They were pumped into the wellbore into the transition zone (B1) at the injection pressure Rnach. = 40 atm and Rkon. = 50 atm sequentially: Geotherm-001 polymer resin in an amount of 1 m ³ with the addition of carbon ammonium salt, while the carbon ammonium salt was taken in an amount of 100 kg (10% of the volume of the first rim), then gasoline in an amount of 5 m ³ (500% of the volume of the first rim), after a solution of urotropin in formalin with carbon ammonium salt in an amount of 2.6 m ³ , while the solution of urotropin in formalin was taken in an amount of 2.5 m ³ (250% of the volume of the first rim), and then fresh water in 0.5 m ³ (50% by volume of the first rim) and dry cement in diesel fuel density of 1.8 t / m ³ an amount of 2 m ³ (200% of the volume of the first rim).

After carrying out work to increase oil recovery, the well had the following parameters:

oil production rate - 12.3 tons / day; water cut - 10%.

The injection of components directly into the transition zone (B1) made it possible to cut off the water saturation zone (A) from the marginal oil saturation zone (G) and thereby increase oil recovery by 9.9 t / day due to additional oil inflows from the transition zone (B2) and its addition ( B2) to the reservoir.

Example No. 3

At the well that opened the porous reservoir in the range of 2820-2832 m, work was done to increase oil recovery by preventing the injection of injected water from the bottom most permeable part of the reservoir into the wellbore, having previously determined the presence of breakthroughs in the injected water into the wellbore.

Prior to oil recovery enhancement, the well had the following parameters: oil production rate - 2.8 tons / day; water cut - 95%.

They were pumped into the wellbore into the transition zone (B1) at the injection pressure Rnach. = 40 atm and Rkon. = 50 atm in series: Geotherm-005 polymer resin in an amount of 1 m ³ , industrial water in an amount of 1.25 m ³ (125% of the volume of the first rim), Geotherm-105 polymer hardener and sodium carbonate in an amount of 2 m ³ (200% of the volume of the first rim), followed by fresh water in an amount of 0.2 m ³ (20% of the volume of the first rim) and a water-based cement mortar with a density of 1.8 t / m ³ in an amount of 1 m ³ (100% from the volume of the first rim).

After carrying out work to increase oil recovery, the well had the following parameters:

oil flow rate - 8.3 tons / day; water cut - 12%.

The injection of components allowed to increase oil recovery by 5.5 tons / day, to eliminate water breakthroughs in the most permeable bottom part of the reservoir.

Example No. 4

At the well that opened the porous reservoir in the range of 2840-2850 m, work was done to increase oil recovery by preventing the injection of injected water from the bottom most permeable part of the reservoir into the wellbore, having previously determined the presence of injected water breakthroughs into the wellbore.

Prior to oil recovery enhancement, the well had the following parameters: oil production rate - 3.7 tons / day; water cut - 97%.

Oil recovery enhancement work was decided to be carried out through an injection well.

Why they pumped it into the injection well bore into the transition zone B1 at the injection pressure Rnach. = 60 atm and Rkon. = 70 atm sequentially: acetone in an amount of 0.5 m ³ (50% of the volume of the first rim), then polymer resin "Geotherm-005" in an amount of 1 m ³ and sodium bicarbonate in an amount of 50 kg (5% of the volume of the first rim) , then industrial water and sodium bicarbonate in an amount of 2.5 m ³ (250% of the volume of the first rim), while sodium bicarbonate in an amount of 50 kg, then Geotherm-105 polymer hardener in an amount of 1.25 m ³ (125% of the volume of the first rim), followed by fresh water in an amount of 0.4 m ³ (40% of the volume of the first rim) and a water-based cement mortar with a density of 1, 8 t / m ³ in an amount of 1 m ³ (100% of the volume of the first rim).

After carrying out work to increase oil recovery, the well had the following parameters: oil production rate - 7.4 tons / day; water cut - 25%.

The injection of components allowed to increase oil recovery by 3.7 tons / day, to eliminate water breakthroughs in the most permeable bottom part of the reservoir.

Example No. 5

In the well that opened the fractured-porous reservoir in the range of 2848-2858 m, work was done to increase oil recovery by preventing the injection of injected water from the bottom most permeable part of the reservoir into the wellbore. For this, work was carried out simultaneously in production and injection wells.

Prior to oil recovery enhancement, the well had the following parameters: oil production rate - 4.1 tons / day; water cut - 98%. Oil recovery enhancement work was decided to be carried out through production and injection wells.

For this, they were pumped simultaneously into the wellbore into the transition zone (B1) at the injection pressure Rnach. = 70 atm and Rkon. = 80 atm and into the injection well bore, the following compositions are sequentially: industrial water in an amount of 0.5 m ³ (50% of the volume of the first rim), then a Geotherm-005 polymer resin in an amount of 1 m ³ and aluminum powder in an amount of 75 kg (7.5% of the volume of the first rim), solvent in an amount of 100 l (10% of the volume of the first rim), then polymer hardener "Geotherm-105" in an amount of 2.5 m ³ (250% of the volume of the first rim) followed by fresh water in an amount of 0.3 m ³ (30% of the volume of the first rim) and a water-based cement mortar with a density of 1.8 t / m ³ in an amount of 1 m ³ (100% of the volume of the first rim).

After carrying out work to increase oil recovery, the producing well had the following parameters: oil production rate - 10 tons / day; water content - 2%.

The injection of components simultaneously into the production and injection wells made it possible to increase oil recovery by 5.9 tons / day, eliminate water breakthroughs and redistribute the flows of injection water in the injection well (alignment of the injection profile).

Example No. 6

At the well that opened the porous reservoir in the range of 1785-1798 m, work was done to increase oil recovery by preventing the injection of injected water from the bottom most permeable part of the reservoir into the wellbore.

Prior to oil recovery enhancement, the well had the following parameters: oil production rate - 5.2 tons / day; water cut - 97%. Oil recovery enhancement work was decided to be carried out through production and injection wells. The work was carried out simultaneously.

Why at the same time into the well of the producing well into the transition zone (B1) at the injection pressure Rnach. = 70 atm and Rkon. = 100 atm and the following compositions are pumped into the injection well bore sequentially: fresh water in an amount of 0.5 m ³ (50% of the volume of the first rim), then Geotherm-004 polymer resin in an amount of 1 m ³ and magnesium powder in an amount of 100 kg (10% of the volume of the first rim), substandard gasoline in an amount of 5 m ³ (500% of the volume of the first rim), Geotherm-104 polymer hardener in an amount of 0.1 m ³ (10% of the volume of the first rim), water fresh water in an amount of 2.5 m ³ (250% of the first volume rim) and dry cement in degassed, dehydrated oil tighter Stu 1.7 t / m ³ in an amount of 0.1 m ³ (10% by volume of a first rim).

After carrying out work to increase oil recovery, the producing well had the following parameters: oil production rate - 11 tons / day; water cut - 18%.

The injection of components simultaneously into the production and injection wells allowed us to increase oil recovery by 5.8 tons / day, eliminate water breakthroughs and redistribute the flows of injection water in the injection well (alignment of the injectivity profile).

Example No. 7

In the well that opened the fractured-porous reservoir in the range of 1760-1766 m, work was done to increase oil recovery by preventing the flow of produced water from the bottom of the formation (transition zone B1) into the wellbore of the producing well.

Prior to oil recovery enhancement, the well had the following parameters:

Oil production - 2.5 tons / day; water cut - 98%.

They were pumped into the wellbore into the transition zone (B1) at the injection pressure Rnach. = 20 atm and Rkon. = 40 atm at the same time: a viscoelastic pack in an amount of 0.1 m ³ (10% of the volume of the first rim), a polymer resin "Geotherm-001" in an amount of 1 m ³ and carbon ammonium salt in an amount of 100 kg (10% of the volume of the first rim) , fresh water in an amount of 0.1 m ³ (10% of the volume of the first rim), Geotherm-001 polymer hardener in an amount of 0.1 m ³ (10% of the volume of the first rim), a hydrocarbon-based cement mortar with a density of 1, 7 t / m ³ in an amount of 0.1 m ³ (10% of the volume of the first rim).

After carrying out work to increase oil recovery, the producing well had the following parameters:

Oil production - 8.7 tons / day; water cut - 20%.

The injection of components directly into the transition zone (B1) made it possible to cut off the water saturation zone (A) from the marginal oil saturation zone (G) and thereby increase oil recovery by 5.2 t / day due to the net oil inflows from the transition zone (B2) and its addition ( B2) to the reservoir.

Example No. 8

In the well that opened the fractured-porous reservoir in the range of 1760-1788 m, work was done to increase oil recovery by preventing the flow of produced water from the bottom of the reservoir (transition zone B1) into the wellbore of the producing well.

Prior to oil recovery enhancement, the well had the following parameters: oil production rate - 2.5 tons / day; water cut - 98%.

They were pumped into the wellbore into the transition zone (B1) at the injection pressure Rnach. = 10 atm and Rkon. = 100 atm at the same time: viscoelastic pack in an amount of 5 m ³ (500% of the volume of the first rim), polymer resin Geotherm-001 in an amount of 1 m ³ and sodium carbonate in an amount of 75 kg (7.5% of the volume of the first rim) , technical water in an amount of 5 m ³ (500% of the volume of the first rim), polymer hardener "Geotherm-101" and sodium carbonate in an amount of 2.5 m ³ (250% of the volume of the first rim), while the polymer hardener "Geotherm- 101 "taken in an amount of 75 kg, a resin solution with cement with a density of 1.45 t / m ³ in an amount of 20 m ³ (2000% of the volume of the first rim).

After carrying out work to increase oil recovery, the producing well had the following parameters: oil production rate - 14 tons / day; water cut - 10%.

The injection of components directly into the transition zone (B1) made it possible to cut off the water saturation zone (A) from the zone of maximum oil saturation (G) and thereby increase oil recovery by 11.5 t / day due to net oil inflows from the transition zone (B2) and its addition ( B2) to the reservoir.

Example No. 9

At the well that opened the fractured reservoir in the interval 1525-1555 m, work was done to increase oil recovery by preventing the injection of injected water from the bottom most permeable part of the reservoir into the wellbore.

Prior to oil recovery enhancement, the well had the following parameters: oil production rate - 5.2 tons / day; water cut - 94%.

They were pumped into the wellbore into the transition zone (B1) at the injection pressure Rnach. = 15 atm and Rkon. = 110 atm sequentially: a viscoelastic pack in an amount of 1.25 m ³ (125% of the volume of the first rim), then a Geotherm-001 polymer resin in an amount of 1 m ³ and sodium bicarbonate in an amount of 80 kg (8% of the volume of the first rim ), technical water in the amount of 1.25 m ³ (125% of the volume of the first rim), polymer hardener "Geotherm-101" and sodium bicarbonate in the amount of 2 m ³ (200% of the volume of the first rim), polymer-cement mortar with a density of 1.5 t / m in an amount of 10 m ³ (1000% of the volume of the first rim).

After carrying out work to increase oil recovery, the producing well had the following parameters: oil production rate - 11.5 tons / day; water cut - 25%.

The injection of components made it possible to increase oil recovery by 6.3 tons / day due to an increase in the productive part of the formation and additional oil inflows from the transition zone (B2) and its accession (B2) to the productive formation.

Example No. 10

At the well that opened the porous reservoir in the range of 2840-2850 m, work was done to increase oil recovery by preventing the injection of injected water from the bottom most permeable part of the reservoir into the wellbore.

Prior to oil recovery enhancement, the well had the following parameters: oil production rate - 3.7 tons / day; water cut - 97%. The work was decided to be carried out through the injection well.

They were pumped into the injection well bore into the transition zone (B1) at the injection pressure Rnach. = 20 atm and Rkon. = 90 atm sequentially: a viscoelastic pack in an amount of 2.5 m ³ (250% of the volume of the first rim), then a Geotherm-001 polymer resin in an amount of 1 m ³ and aluminum powder in an amount of 100 kg, fresh water in an amount of 2, 5 m ³ (250% of the volume of the first rim), polymer hardener "Geotherm-001" in an amount of 1.25 m ³ (125% of the volume of the first rim), a water-based cement mortar with a density of 1.8 t / m ³ in quantity 5 m ³ (500% of the volume of the first rim).

After carrying out work to increase oil recovery, the producing well had the following parameters:

Oil production rate - 7.5 tons / day; water cut - 20%.

The injection of components made it possible to increase oil recovery by 3.8 tons / day due to an increase in the productive part of the reservoir and additional oil inflows from the transition zone (B2) and its attachment (B2) to the reservoir.

Example No. 11

At the well that opened the porous reservoir in the range of 1787-1810 m, work was carried out to increase oil recovery by preventing the injection of injected water from the bottom most permeable part of the reservoir into the wellbore. Prior to oil recovery enhancement, the well had the following parameters:

Oil production - 8.1 t / day; water cut - 93%. Oil recovery enhancement work was decided to be carried out through production and injection wells. The work was carried out simultaneously.

Why at the same time into the well of the producing well into the transition zone (B1) at the injection pressure Rnach. = 15 atm and Rkon. = 120 atm and into the injection wellbore, the following compositions simultaneously: a viscoelastic pack in an amount of 0.1 m ³ (10% of the volume of the first rim), a Geotherm-001 polymer resin in an amount of 1 m ³ and magnesium powder in an amount of 100 kg (10% of the volume of the first rim), industrial water and magnesium powder in an amount of 0.1 m ³ (10% of the volume of the first rim), while the blowing agent is taken in an amount of 25 kg (2.5% of the volume of the first rim), polymer hardener "Geotherm-101" in an amount of 2.5 m ³ (250% of the first rim volume) solution of the resin with the hardener and tsemen ohm density of 1.5 t / m ³ in an amount of 20 m ³ (2000% of the volume of the first rim).

After carrying out work to increase oil recovery, the producing well had the following parameters:

Oil production rate - 15.3 tons / day; water cut - 17%.

The injection of components simultaneously into the production and injection wells allowed increasing oil recovery by 7.2 tons / day due to an increase in the productive part of the formation and additional oil inflows from the transition zone (B2) and its connection (B2) to the productive formation.

Example No. 12

At the well that opened the porous reservoir in the interval 1751-1761 m, work was done to increase oil recovery by preventing the injection of injected water from the bottom most permeable part of the reservoir into the wellbore. Prior to oil recovery enhancement, the well had the following parameters:

Oil production - 5.3 tons / day; water cut - 91%. Oil recovery enhancement work was decided to be carried out through production and injection wells. The work was carried out simultaneously.

Why at the same time into the well of the producing well into the transition zone (B1) at the injection pressure Rnach. = 15 atm and Rkon. = 120 atm and into the injection well bore, the following compositions at the same time: viscoelastic pack in an amount of 5 m ³ (500% of the volume of the first rim), polymer resin “Geotherm-001” in an amount of 1 m ³ and carbon ammonium salt in an amount of 100 kg (10 % of the volume of the first rim), Sinol-M in an amount of 5 m ³ (500% of the volume of the first rim), polymer hardener Geotherm-101 in an amount of 0.1 m ³ (10% of the volume of the first rim), technical water in an amount of 2.5 m ³ (250% of the volume of the first rim), a hydrocarbon-based cement mortar with a density of 1.7 t / m ³ in an amount 0.1 m ³ (10% of the volume of the first rim).

After carrying out work to increase oil recovery, the producing well had the following parameters:

Oil production rate - 9.8 tons / day; water cut - 23%.

The injection of components simultaneously into the production and injection wells made it possible to increase oil recovery by 5.8 tons / day due to an increase in the productive part of the formation and additional oil inflows from the transition zone (B2) and its connection (B2) to the productive formation.

Example No. 13

In the well, which revealed a weakly cemented producing formation in the range of 2100-2110 m, work was done to increase oil recovery by preventing the flow of produced water from the bottom of the formation (transition zone B1) into the wellbore. Prior to oil recovery enhancement, the well had the following parameters:

Oil production - 2.6 tons / day; water cut - 91%.

They were pumped into the wellbore into the transition zone (B1) at the injection pressure Rnach. = 60 atm and Rkon. = 90 atm at the same time: Geotherm-002 polymer resin in an amount of 1 m ³ , Geotherm-102 polymer hardener in an amount of 0.1 m ³ (10% of the volume of the first rim), a viscoelastic pack in an amount of 0.1 m ³ (10% of the volume of the first rim), dry cement and cement mortar in an amount of 0.1 m ³ (10% of the volume of the first rim).

After carrying out work to increase oil recovery, the producing well had the following parameters:

Oil production rate - 8.9 tons / day; water cut - 21%.

The injection of components directly into the transition zone (B1) made it possible to cut off the water saturation zone (A) from the zone of maximum oil saturation (G) and thereby increase oil recovery by 6.3 t / day due to additional oil inflows from the transition zone (B2) and its addition ( B2) to the reservoir.

Example No. 14

In the well, which revealed a weakly cemented producing formation in the range of 2100-2110 m, work was done to increase oil recovery by preventing the flow of produced water from the bottom of the formation (transition zone B1) into the wellbore. Prior to oil recovery enhancement, the well had the following parameters:

Oil production - 4.6 tons / day; water cut - 98%.

They were pumped into the wellbore into the transition zone (B1) at the injection pressure Rnach. = 15 atm and Rkon. = 95 atm sequentially: Geotherm-008 polymer resin in an amount of 1 m ³ and carbon-ammonium salt in an amount of 50 kg (5% of the volume of the first rim), Geotherm-108 polymer hardener and carbon-ammonium salt in an amount of 2.5 m ³ (250% of the volume of the first rim), while carbon ammonium salt in an amount of 50 kg (5% of the volume of the first rim), a viscoelastic pack in an amount of 5 m ³ (500% of the volume of the first rim), dry cement and polymer-cement mortar in an amount of 20 m ³ (2000% of the volume of the first rim).

After carrying out work to increase oil recovery, the producing well had the following parameters:

Oil production rate - 9.2 t / day; water cut - 14%.

The injection of components directly into the transition zone (B1) made it possible to cut off the water saturation zone (A) from the marginal oil saturation zone (G) and thereby increase oil recovery by 4.6 tons / day due to additional oil inflows from the transition zone (B2) and its addition ( B2) to the reservoir.

Example No. 15

At the well that opened the porous reservoir in the range of 2730-2745 m, work was done to increase oil recovery by preventing the injection of injected water from the bottom most permeable part of the reservoir into the wellbore. Prior to oil recovery enhancement, the well had the following parameters:

Oil production - 5.7 tons / day; water cut - 92%. Oil recovery enhancement work was decided to be carried out through an injection well.

They were pumped into the injection well bore into the transition zone (B1) at the injection pressure Rnach. = 30 atm and Rkon. = 120 atm sequentially: a viscoelastic pack in an amount of 2.5 m ³ (250% of the volume of the first rim), then a Geotherm-005 polymer resin in an amount of 1 m ³ and sodium carbonate in an amount of 75 kg (7.5% of the volume the first rim), polymer hardener and pore former “Geotherm-105” in an amount of 2 m ³ (200% of the volume of the first rim), fresh water in an amount of 0.5 m ³ (50% of the volume of the first rim), dry cement with a polymer solution in an amount of 10 m ³ (1000% of the volume of the first rim).

After carrying out work to increase oil recovery, the producing well had the following parameters:

Oil production rate - 17 tons / day; water cut - 13%.

The injection of components increased oil recovery by 11.3 tons / day, which allowed redistributing the injected water flows (equalization of the injectivity profile) and connecting previously unreached “dead” zones of the productive part of the reservoir to the development.

Example No. 16

At the well that opened the porous reservoir in the range of 2640-2652 m, work was done to increase oil recovery by preventing the injection of injected water from the bottom most permeable part of the reservoir into the wellbore. Prior to oil recovery enhancement, the well had the following parameters:

Oil production rate - 7.5 tons / day; water cut - 90%. Oil recovery enhancement work was decided to be carried out through an injection well.

They were pumped into the injection well bore into the transition zone (B1) at the injection pressure Rnach. = 40 atm and Rkon. = 90 atm at the same time: a viscoelastic pack in an amount of 2.5 m ³ (250% of the volume of the first rim), a polymer resin "Geotherm-005" in an amount of 1 m ³ and sodium bicarbonate in an amount of 75 kg (7.5% of the volume of the first rims), Geotherm-105 polymer hardener in the amount of 1.25 m ³ (125% of the volume of the first rim), a viscoelastic pack in the amount of 1.25 m ³ (125% of the volume of the first rim), resin solution with hardener and with cement with a density of 1.45 t / m ³ in an amount of 4 m ³ (400% of the volume of the first rim).

After carrying out work to increase oil recovery, the producing well had the following parameters:

Oil production rate - 15 tons / day; water cut - 27%.

The injection of components into the injection wellbore allowed us to increase oil recovery by 7.5 tons / day, redistribute the injected water flows (alignment of the injectivity profile) and connect previously unreached “dead” zones of the productive part of the formation to the development.

Example No. 17

At the well that opened the porous reservoir in the interval 1751-1761 m, work was done to increase oil recovery by preventing the injection of injected water from the bottom most permeable part of the reservoir into the wellbore. Prior to oil recovery enhancement, the well had the following parameters:

Oil production rate - 5.6 tons / day; water cut - 91%. Oil recovery enhancement work was decided to be carried out through production and injection wells. The work was carried out simultaneously.

Why at the same time into the well of the producing well into the transition zone (B1) at the injection pressure Rnach. = 40 atm and Rkon. = 70 atm and the following compositions were pumped into the injection well bore at the same time: viscoelastic pack in an amount of 5 m ³ (500% of the volume of the first rim), Geotherm-001 polymer resin in an amount of 1 m ³ and aluminum powder in an amount of 100 kg (10 % of the volume of the first rim), Geotherm-101 polymer hardener in an amount of 2.5 m ³ (250% of the volume of the first rim), a viscoelastic pack in an amount of 0.5 m ³ (50% of the volume of the first rim), cement mortar water-based in an amount of 0.1 m ³ (10% of the volume of the first rim).

After carrying out work to increase oil recovery, the producing well had the following parameters:

Oil production - 12.6 tons / day; water cut - 11%.

The injection of components simultaneously into the production and injection wells made it possible to increase oil recovery by 7.0 tons / day due to additional oil inflows from the transition zone (B2) and its connection (B2) to the reservoir.

Example No. 18

At the well that opened the porous reservoir in the interval 1521-1525 m, work was done to increase oil recovery by preventing the injection of injected water from the bottom most permeable part of the reservoir into the wellbore. Prior to oil recovery enhancement, the well had the following parameters:

Oil production - 6.4 tons / day; water cut - 99%. Oil recovery enhancement work was decided to be carried out through production and injection wells. The work was carried out simultaneously.

Why at the same time into the well of the producing well into the transition zone (B1) at the injection pressure Rnach. = 30 atm and Rkon. = 80 atm and the following compositions were pumped into the well bore at the same time:

As the first rim, Geotherm-011 polymer resin in an amount of 1 m ³ and magnesium powder in an amount of 100 kg (10% of the volume of the first rim) were used, Geotherm-111 polymer hardener in an amount of 0.01 m ³ (0, 1% of the volume of the first rim), a viscoelastic pack in an amount of 0.005 m ³ (0.05% of the volume of the first rim), water-based cement in an amount of 0.09 m ³ (0.9% of the volume of the first rim).

After carrying out work to increase oil recovery, the producing well had the following parameters: oil production rate - 11.8 tons / day; water cut - 12%.

The injection of components simultaneously into the production and injection wells made it possible to increase oil recovery by 5.4 tons / day due to additional oil inflows from the transition zone (B2) and its connection (B2) to the reservoir.

Example 19

At the well that opened the fractured-porous reservoir in the range of 1630-1640 m, work was carried out to increase oil recovery. Prior to the work on increasing productivity, the well had the following parameters: The injectivity was determined, which amounted to 400 m ³ at a pressure of P = 40 atm and the oil production rate was 0.9 tons / day; water cut - 99%.

It was decided to carry out work to increase well productivity through the perforation interval.

Why they pumped it into the wellbore at the injection pressure Rnach. = 60 atm and Rkon. = 120 atm in series: Geotherm-011 polymer resin in an amount of 0.8 m ³ , industrial water in an amount of 0.3 m ³ (38% of the first rim volume), Geotherm-111 polymer hardener in an amount of 0.4 m ³ (50% of the volume of the first rim), industrial water in an amount of 0.2 m ³ (25% of the volume of the first rim), water-based cement mortar in an amount of 1.6 m ³ (200% of the volume of the first rim).

With the abandonment of the cement-polymer cup 10 m above the upper holes of the perforation interval. The tubing was raised to a safe depth of 150 m. The well was left under pressure P = 80 atm for 24 hours. After a day, the cement-polymer bridge was drilled.

After carrying out work to increase productivity, the producing well had the following parameters:

Oil production rate - 5.6 tons / day; water cut - 30%.

Sequential injection of components into the bottom of the formation allowed to increase oil recovery by 4.7 tons / day and to eliminate breakthroughs of formation water from zone (B1).

Example 20

Hydraulic fracturing was carried out at the well that opened the porous reservoir in the interval 3155-3170 m, resulting in an inflow of clean produced water of 100 m ³ / day, from the interval 3101-3155 m. Annular circulation from the overlying reservoir. It was decided to carry out work to increase oil recovery through special openings, for which an interval of 3110-3113 m was shot.

Before carrying out work to increase productivity, the well had an oil production rate of 1.2 tons / day; water cut - 98%.

Oil recovery enhancement work was carried out in the producing well. For this, they pumped into the well at the same time: Geotherm-002 V polymer resin in an amount of 0.8 m ³ , Geotherm-102 V polymer hardener in an amount of 0.4 m ³ (50% of the volume of the first rim), which were mixed on wellhead.

Injection Pressure = 150 atm, Rkon. = 170 atm. The well was left to undergo a polycondensation reaction in the reservoir for 24 hours. After a day, the well was mastered.

After carrying out work to increase productivity, the producing well had the following parameters:

Oil production rate - 70 tons / day; water cut - 0%.

The injection of components into the special openings made it possible to increase oil recovery by 68.8 tons / day and to eliminate overflows from an overlying aquifer.

Example 21

At the well that opened the fractured-porous reservoir in the range of 1498-1501 m, work was carried out to increase oil recovery. Prior to the work on increasing productivity, the well had an oil production rate of 1.7 tons / day; water cut - 96%. Oil recovery enhancement work was carried out in the producing well. Why the composition was pumped into a production well at the same time: Geotherm-011 polymer resin in an amount of 0.8 m ³ , industrial water in an amount of 0.2 m ³ (25% of the volume of the first rim), Geotherm-111 polymer hardener in 0.4 m ³ (50% of the volume of the first rim), industrial water in the amount of 0.2 m ³ (25% of the volume of the first rim), water-based cement in an amount of 1.6 m ³ (200% of the volume first rims).

Injection Pressure = 50 atm. Rcon. = 120 atm STOP mode.

The excess cement mortar was cut off with the cement-polymer cup remaining 10 m above the upper holes of the perforation interval. The tubing was raised to a safe depth of 150 m. The well was left under pressure P = 100 atm for 24 hours. A day later, the cement-polymer bridge was drilled and pressed, the result was hermetic. The well was left for commissioning at the underlying facilities.

After carrying out work to increase productivity, the producing well had the following parameters: oil production rate - 8.4 tons / day; water cut - 25%. Sequential injection of components into the bottom of the reservoir allowed to increase oil recovery by 6.7 tons / day and to eliminate breakthroughs of produced water from the underlying aquifer (zone A + B1).

Example 22

At the well that opened the fractured-porous reservoir in the interval 1415-1428 m, work was carried out to increase oil recovery. Prior to work on increasing productivity, the well had an oil production rate of 0.6 tons / day; water cut - 99%.

Oil recovery enhancement work was carried out in the producing well. Why the composition was pumped into a production well at the same time: a viscoelastic pack in an amount of 1.2 m ³ (150% of the volume of the first rim), a Geotherm-011 polymer resin in an amount of 0.8 m ³ , industrial water in an amount of 0.2 m ³ (25% of the volume of the first rim), polymer hardener "Geotherm-111" in an amount of 0.4 m ³ (50% of the volume of the first rim), industrial water in an amount of 0.2 m ³ (25% of the volume of the first rim) , water-based cement mortar in an amount of 1.6 m ³ (200% of the volume of the first rim).

Injection Pressure = 0 atm, Rcon. = 100 atm, the STOP mode.

The excess cement mortar was cut off with the cement-polymer cup remaining 10 m above the upper holes of the perforation interval. The tubing was raised to a safe depth of 150 m. The well was left under pressure P = 100 atm for 24 hours. A day later, the cement-polymer bridge was drilled and pressed. The well was left for commissioning at the underlying facilities.

After carrying out work to increase productivity, the producing well had the following parameters:

Oil production rate - 11.5 tons / day; water cut - 24%.

Sequential injection of components into the bottom of the formation allowed to increase oil recovery by 10.9 tons / day and to eliminate breakthroughs of produced water from the underlying aquifer - zone (B1).

Example 23

At the well, which uncovered a fractured gas condensate reservoir in the interval 3586-3606 m, work was carried out to increase gas recovery. Before the work on increasing productivity, the well had the following parameters: Rtr = 42 atm, Rzatr = 77 atm, flow rate of Qgas = 85 thousand m ³ / day, Q condensate = 33 m ³ / l, Q water = 22 m ³ / l. It was decided to carry out work to increase well productivity through the perforation interval. Why they pumped it into the wellbore at the injection pressure Rnach. = 0 atm and Rkon. = 20 atm simultaneously: fresh water in an amount of 2 m ³ (200% of the volume of the first rim), Geotherm-004 polymer resin in an amount of 1 m ³ , Geotherm-104 polymer hardener in an amount of 0.3 m ³ (30 % of the volume of the first rim), industrial water in an amount of 0.5 m ³ (50% of the volume of the first rim),

The composition is extruded into the reservoir. The well was left under pressure P = 20 atm for 24 hours. After a day, the well was mastered.

After carrying out work to increase productivity, the producing well had the following parameters:

Gas production = 170 thousand m ³ / day.

Additional gas production was obtained by injecting a mixed polymer composition into the aquifer through packs of fresh water.

Example 24

In the well, which uncovered a fractured gas condensate reservoir in the range of 3526-3562 m, work was carried out to increase the gas recovery of the formation. Before the work on increasing productivity, the well had the following parameters: Rtr = 47 atm, Rzatr = 57 atm, flow rate of Qgas = 222.7 thousand m ³ / day, Q condensate = 47 m ³ / l, Q water = 58 m ³ / l. It was decided to carry out work to increase well productivity through the perforation interval. Why they pumped it into the wellbore at the injection pressure Rnach. = 40 atm. and Rcon. = 60 atm. at the same time: fresh water in an amount of 2 m ³ (200% of the volume of the first rim), Geotherm-004 polymer resin in an amount of 1 m ³ , Geotherm-104 polymer hardener in an amount of 0.3 m ³ (30% of the volume the first rim), industrial water in an amount of 0.5 m ³ (50% of the volume of the first rim).

The composition is extruded into the reservoir. The well was left under pressure P = 60 atm for 24 hours. After a day, the well was mastered.

After carrying out work to increase productivity, the producing well had the following parameters:

Gas production = 352 thousand m3 / day.

Additional gas production was obtained by injecting a mixed polymer composition into the aquifer through packs of fresh water.

Example 25

At the well that opened the porous reservoir, work was carried out to increase productivity at a depth of 1921.5-1923 m.

Before carrying out work to increase productivity, the well had an oil production rate of 0.3 tons / day; water cut - 99.7%.

Oil recovery enhancement work was carried out in a production well,

why the sequentially pumped into the production well: gas condensate in the amount of 2 m ³ (330% of the volume of the first rim), then the polymer resin "FRF-50RM" in the amount of 0.6 m ³ , emulsifier in the amount of 0.5 m ³ (83% of the volume of the first rim), a solution of urotropine in formalin in an amount of 0.6 m ³ (100% of the volume of the first rim), gas condensate in an amount of 0.5 m ³ (83% of the volume of the first rim), water-based cement mortar with a density of 1 , 75 g / cm ³ in an amount of 2.8 m ³ (466% of the volume of the first rim), industrial water in an amount of 0.5 m ³ (83% of the volume of the first rim),

Injection Pressure = 90 atm. and Rcon. = 150 atm STOP mode.

The excess cement mortar was cut off with the cement-polymer cup remaining 10 m above the upper holes of the perforation interval. The tubing was raised to a safe depth of 150 m. The well was left at a pressure of P = 100 atm for 24 hours. A day later, the cement bridge was drilled and the production string was pressed.

After carrying out work to increase productivity, the producing well had the following parameters:

Oil production rate - 19.3 t / day; water cut - 17%.

The injection of components into the bottom of the formation allowed us to increase oil recovery by 19 tons / day due to additional oil inflows from the transition zone (B2) and its accession (B2) to the productive formation.

Example 26

At the well that opened the porous reservoir, work was carried out to increase productivity at a depth of 1771-1773 m.

Prior to work on increasing productivity, the well had an oil production rate of 0.2 t / day; water cut - 99.8%.

Oil recovery enhancement work was carried out in the producing well. For this purpose, the following was pumped into the production well sequentially: BFLH in an amount of 2 m ³ (330% of the volume of the first rim), then polymer resin “FRF-50RM” in an amount of 0.6 m ³ , gasoline in an amount of 0.5 m ³ (83 % of the volume of the first rim), a solution of urotropine in formalin in an amount of 0.6 m ³ (100% of the volume of the first rim), Sinol-M in an amount of 0.5 m ³ (83% of the volume of the first rim), cement mortar water-based density of 1.75 g / cm ³ in the amount of 1.2 m ³ (200% of the volume of the first rim), industrial water in the amount of 0.5 m ³ (83% of the volume of the first rim).

Injection Pressure = 120 atm and Rkon. = 160 atm STOP mode.

The excess cement mortar was cut off with the cement-polymer cup remaining 10 m above the upper holes of the perforation interval. The tubing was raised to a safe depth of 150 m. The well was left at a pressure of P = 100 atm for 24 hours. A day later, the cement bridge was drilled and the production string was pressed.

After carrying out work to increase productivity, the producing well had the following parameters:

Oil production rate - 17.1 tons / day; water cut - 31%.

The injection of components into the bottom of the formation allowed us to increase oil recovery by 16.9 tons / day due to additional oil inflows from the transition zone (B2) and its accession (B2) to the productive formation.

Example 27

At the well that opened the porous reservoir, work was carried out to increase the productivity of the well at a depth of 1892-1895 m.

Before carrying out work to increase productivity, the well had an oil production rate of 0.5 tons / day; water cut - 99.5%.

Oil recovery enhancement work was carried out in the producing well. Why the composition was pumped into the production well at the same time: substandard gasoline in an amount of 2 m ³ (330% of the volume of the first rim), polymer resin FRF-50RM in an amount of 0.6 m ³ , with the addition of magnesium powder in an amount of 50 kg (0 , 12% of the volume of the first rim), Sinol-M in an amount of 0.5 m ³ (83% of the volume of the first rim), a solution of urotropine in formalin in an amount of 0.6 m ³ (100% of the volume of the first rim), "Sinol - m" in an amount of 0.5 m ³ (83% by volume of the first rim), a cement-based aqueous solution to a density of 1.75 g / cm ³ in an amount of 2 m ³ (330% of the volume of the first minutes rim) process water in an amount of 0.5 m ³ (83% by volume of a first rim).

Injection Pressure = 90 atm. and Rcon. = 150 atm, the STOP mode.

The excess cement mortar was cut with the cement-polymer cup remaining 10 m above the upper holes of the perforation interval. The tubing was raised to a safe depth of 150 m. The well was left at a pressure of P = 100 atm for 24 hours. A day later, the cement bridge was drilled and the production string was pressed.

After carrying out work to increase productivity, the producing well had the following parameters:

Oil production - 14.3 tons / day; water cut - 17%.

The injection of components into the bottom of the formation allowed us to increase oil recovery by 13.8 tons / day due to additional oil inflows from the transition zone (B2) and its accession (B2) to the productive formation.

Example 28

At the well that opened the porous reservoir, work was carried out to increase the productivity of the well at a depth of 2543-2545 m.

Prior to work on increasing productivity, the well had an oil production rate of 0.1 t / day; water cut - 99.8%.

Oil recovery enhancement work was carried out in the producing well. Why the composition was pumped into the production well at the same time: “Sinol-M” 2 m ³ (500% of the volume of the first rim), polymer resin “FRF-50RM” in the amount of 0.4 m ³ , with the addition of carbon ammonium salt in the amount of 30 kg ( 7.5% of the volume of the first rim), NGL in an amount of 0.5 m ³ (125% of the volume of the first rim), a solution of urotropine in formalin in an amount of 0.6 m ³ (150% of the volume of the first rim), NGL in an amount 1 m ³ (250% of the volume of the first rim), a cement-based aqueous solution to a density of 1.75 g / cm ³ in an amount of 1.8 m ³ (450% of the volume of the first rim) in industrial water The number of 0.5 m ³ (125% of the first volume rim).

Injection Pressure = 100 atm and Rkon. = 130 atm. The excess cement mortar was cut off with the cement-polymer cup remaining 10 m above the upper holes of the perforation interval. The tubing was raised to a safe depth of 150 m. The well was left under pressure P = 100 atm for 24 hours. A day later, the cement bridge was drilled and the production string was pressed.

After carrying out work to increase productivity, the producing well had the following parameters:

Oil production rate - 21.4 tons / day; water cut - 15%.

The injection of components into the bottom of the formation allowed us to increase oil recovery by 21.3 tons / day due to additional oil inflows from the transition zone (B2) and its accession (B2) to the productive formation.

Example 29

At the well that opened the porous reservoir, work was done to increase the productivity of the well at a depth of 1612.2 m.

Before carrying out work to increase productivity, the well had an oil production rate of 0.3 tons / day; water cut - 99.6%.

Oil recovery enhancement work was carried out in the producing well. Why the composition was pumped into a production well at the same time: gasoline in the amount of 2 m ³ (330% of the volume of the first rim), FRF-50RM in the amount of 0.6 m ³ , gasoline in the amount of 0.5 m ³ (83% of the volume the first rim), a solution of urotropine in formalin in an amount of 0.6 m ³ (100% of the volume of the first rim), gasoline in an amount of 1 m ³ (167% of the volume of the first rim), water-based cement mortar with a density of 1.75 g / cm ³ in an amount of 2.4 m ³ (400% of the volume of the first rim), industrial water in an amount of 0.5 m ³ (83% of the volume of the first rim).

Injection Pressure = 110 atm, Rcon. = 140 atm. The excess cement mortar was cut off with the cement-polymer cup remaining 10 m above the upper holes of the perforation interval. The tubing was raised to a safe depth of 150 m. The well was left under pressure P = 100 atm for 24 hours. A day later, the cement bridge was drilled and the production string was pressed.

After carrying out work to increase productivity, the producing well had the following parameters:

Oil production rate - 9.8 tons / day; water cut - 27%.

The injection of components into the bottom of the formation allowed us to increase oil recovery by 9.7 tons / day due to additional oil inflows from the transition zone (B2) and its accession (B2) to the productive formation.

Example 29

At the well that opened the porous reservoir, work was carried out to increase the productivity of the well at a depth of 2583-2594 m.

Prior to work on increasing productivity, the well had an oil production rate of 0.4 tons / day; water cut - 99.7%.

Oil recovery enhancement work was carried out in the producing well. For this purpose, the following was pumped into the production well: BFLH in the amount of 2 m ³ (330% of the volume of the first rim), then FRF-50RM in the amount of 0.6 m ³ , BFLH in the amount of 0.5 m ³ (83% of the volume first rim), a solution of urotropine in formalin in an amount of 0.6 m ³ (100% of the volume of the first rim), BFLH in an amount of 1 m ³ (167% of the volume of the first rim), a water-based cement mortar with a density of 1.75 g / cm ³ in an amount of 2.4 m ³ (400% of the volume of the first rim), industrial water in an amount of 0.5 m ³ (83% of the volume of the first rim).

Injection Pressure = 70 atm. Rcon. = 100 atm. The excess cement mortar was cut off with the cement-polymer cup remaining 10 m above the upper holes of the perforation interval. The tubing was raised to a safe depth of 150 m. The well was left under pressure P = 100 atm for 24 hours. A day later, the cement bridge was drilled and the production string was pressed.

After carrying out work to increase productivity, the producing well had the following parameters:

Oil production rate - 16.1 tons / day; water cut - 23%.

The injection of components into the bottom of the formation allowed to increase oil recovery by 15.7 tons / day due to additional oil inflows from the transition zone (B2) and its accession (B2) to the productive formation.

Example 30

At the well that opened the porous reservoir, work was carried out to increase the productivity of the well at a depth of 2482-2458 m

Before carrying out work to increase productivity, the well had an oil production rate of 0.5 tons / day; water cut - 99.8%.

Oil recovery enhancement work was carried out in the producing well. For this, the composition was pumped into a production well at the same time: substandard gasoline in an amount of 2 m ³ (330% of the volume of the first rim), FRF-50RM resin in an amount of 0.6 m ³ with sodium carbonate in an amount of 30 kg (5% of the volume the first rim), substandard gasoline 0.5 m ³ (83% of the volume of the first rim), a solution of urotropine in formalin in an amount of 0.6 m ³ (100% of the volume of the first rim), substandard gasoline in an amount of 1 m ³ (167% of the volume of the first rim), a water-based cement mortar with a density of 1.75 g / cm ³ in an amount of 2.4 m ³ (400% of the volume of the first rim Ki), industrial water in an amount of 0.5 m ³ (83% of the volume of the first rim).

Injection pressure Pnach = 110 atm. and Rcon. = 150 atm.

The excess cement mortar was cut off with the cement-polymer cup remaining 10 m above the upper holes of the perforation interval. The tubing was raised to a safe depth of 150 m. The well was left at a pressure of P = 100 atm for 24 hours. A day later, the cement bridge was drilled and the production string was pressed. After carrying out work to increase productivity, the producing well had the following parameters: oil production rate - 13.7 tons / day; water cut - 36%.

The injection of components into the bottom of the formation allowed us to increase oil recovery by 13.3 tons / day due to additional oil inflows from the transition zone (B2) and its accession (B2) to the productive formation.

Example 31

At the well that opened the porous reservoir, work was carried out to increase the productivity of the well at a depth of 2600-2662.8 m. Prior to work to increase productivity, the well had an oil flow rate of 0.2 t / day; water cut - 99.6%.

Oil recovery enhancement work was carried out in the producing well. Why the composition was pumped into the production well at the same time: “Sinol-M” in an amount of 1.5 m ³ (150% of the volume of the first rim), “FRF-50RM” resin (t-110) in an amount of 1 m ³ , a solution of urotropine in formalin + sodium bicarbonate in an amount of 200 kg (20% of the volume of the first rim), "Sinol-M" in an amount of 0.5 m ³ (50% of the volume of the first rim).

Injection Pressure = 40 atm and Rkon. = 70 atm.

The well was left under pressure P = 70 atm for 24 hours.

The injectivity was determined in a day, it amounted to 320 m ³ / day at P = 60 atm.

After the work, the producing well had the following parameters: Oil production rate - 8.4 tons / day; water cut - 38%.

The injection of components into the bottom of the formation allowed us to increase oil recovery by 8.2 tons / day due to additional oil inflows from the transition zone (B2) and its accession (B2) to the productive formation.

Example 32

At the well that opened the porous reservoir, work was carried out to increase the productivity of the well at a depth of 2559-2587 m.

Prior to the work on increasing productivity, the well had an oil flow rate of 0.1 t / day; water cut - 99.5%.

Oil recovery enhancement work was carried out in production wells. Why the composition was pumped into the production well at the same time: substandard gasoline in an amount of 2 m ³ (330% of the volume of the first rim), FRF-50RM (t-110) in an amount of 0.6 m ³ , a solution of urotropine in formalin + a powder blowing agent - sodium carbonate in an amount of 120 kg (20% of the volume of the first rim), substandard gasoline in an amount of 0.5 m ³ (83% of the volume of the first rim).

Injection Pressure = 80 atm. Rcon. = 160 atm.

The well was left under pressure P = 100 atm for 24 hours.

The injectivity was determined after 24 hours, it was 120 m ³ / day at P = 120 atm.

After carrying out work to increase productivity, the producing well had the following parameters:

Oil production rate - 23.1 tons / day; water cut - 14%.

The injection of components into the bottom of the formation allowed to increase oil recovery by 23 tons / day due to additional oil inflows from the transition zone (B2) and its accession (B2) to the productive formation.

Example 33

At the well that opened the porous reservoir, work was carried out to increase well productivity at a depth of 2795-2814 m.

Before carrying out work to increase productivity, the well had an oil production rate of 0.3 tons / day; water cut - 99.2%.

Oil recovery enhancement work was carried out in the producing well. Why the composition was pumped into the production well: “Sinol-M” in an amount of 2 m ³ (330% of the volume of the first rim), “FRF” resin (“Geotherm-005”) in an amount of 1 m ³ + dispersed blowing agent - magnesium powder + hardener ("Geotherm-105") in an amount of 200 kg (20% of the volume of the first rim),

"Sinol-M" in an amount of 0.5 m ³ (50% of the volume of the first rim).

Injection Pressure = 60 atm. Rcon. = 120 atm. The well was left at a pressure of P = 100 atm for 24 hours. In a day, the injectivity was determined, it was 220 m ³ / day at P = 90 atm.

After carrying out work to increase productivity, the producing well had the following parameters:

Oil production rate - 11.8 tons / day; water cut - 23%.

The injection of components into the bottom of the formation allowed to increase oil recovery by 11.5 t / day due to additional oil inflows from the transition zone (B2) and its accession (B2) to the productive formation.

Example 34

At the well that opened the porous reservoir, work was done to increase the productivity of the well at a depth of 2100-2110 m.

Before the work on increasing productivity, the producing well had the following parameters: oil production rate - 9.5 tons / day, water cut - 91%.

To carry out work to increase productivity, they pumped into the well sequentially: BFLH in the amount of 1.5 m ³ (150% of the volume of the first rim), after which the Geotherm-001 polymer resin in the amount of 1 m ³ , with the addition of 40 kg of carbon ammonium salt (4% of the volume of the first rim), NGL in an amount of 0.5 m ³ (50% of the volume of the first rim), Geotherm-101 polymer hardener in an amount of 1 m ³ (100% of the volume of the first rim), NGL in the amount of 0.5 m ³ (50% of the volume of the first rim).

Injection Pressure = 40 atm and Rkon. = 80 atm. The well was left at a pressure of P = 80 atm for 24 hours. In a day, the injectivity was determined, it was 250 m ³ / day at P = 60 atm.

After carrying out work to increase productivity, the producing well had the following parameters: oil production rate - 15 tons / day, water cut - 81%.

The injection of components into the bottom of the formation allowed to increase oil recovery by 5.5 tons / day due to additional oil inflows from the transition zone (B2) and its accession (B2) to the productive formation.

Example 35

At the well that opened the porous reservoir, work was carried out to increase the productivity of the well at a depth of 2645-2665 m.

Prior to work on increasing productivity, the well had an oil production rate of 10 tons / day; water cut - 85%.

Oil recovery enhancement work was carried out in the producing well. For this purpose, they sequentially pumped into the production well: alcohol-based buffer fluid in an amount of 1.5 m ³ (375% of the volume of the first rim), FRF resin (Geotherm-005) in an amount of 0.4 m ³ + blowing agent - aluminum powder + hardener (Geotherm-105) in an amount of 120 kg (30% of the volume of the first rim), an alcohol-based buffer liquid in an amount of 0.5 m ³ (125% of the volume of the first rim).

Injection Pressure = 60 atm and Rkon. = 60 atm. The well was left at a pressure of P = 60 atm for 24 hours. The injectivity was determined after 24 hours, it was 220 m ³ / day at P = 90 atm.

After carrying out work to increase productivity, the producing well had the following parameters:

Oil production - 16.4 tons / day; water cut - 72%.

The injection of components into the bottom of the formation allowed to increase oil recovery by 6.4 tons / day due to additional oil inflows from the transition zone (B2) and its accession (B2) to the productive formation.

Example 36

At the well that uncovered the porous reservoir, work was carried out to increase the productivity of the well at a depth of 2058-2070 m.

Before the work on increasing productivity, the producing well had the following parameters:

Fluid flow rate - 90 m ³ / day, Oil flow rate - 7.7 tons / day, water cut - 90%.

To carry out work to increase productivity, the composition was pumped into the well at the same time: BFLH in an amount of 1.5 m ³ (150% of the volume of the first rim), Geotherm-001 polymer resin in an amount of 1 m ³ , with an addition of 40 kg of magnesium powder (4% of the volume of the first rim), BFLH in the amount of 0.5 m ³ (50% of the volume of the first rim), Geotherm-101 polymer hardener in the amount of 1 m ³ (100% of the volume of the first rim), BFLH in the amount of 0.5 m (50% of the volume of the first rim).

Injection Pressure = 60 atm, Rkon. = 90 atm. The well was left at a pressure of P = 90 atm for 24 hours. The injectivity was determined after 24 hours, it was 270 m ³ / day at P = 60 atm.

After carrying out work to increase productivity, the producing well had the following parameters:

The oil production rate is 26.6 tons / day, the water cut is 64%.

The injection of components into the bottom of the formation allowed us to increase oil recovery by 21.1 tons / day due to additional oil inflows from the transition zone (B2) and its accession (B2) to the productive formation.

Example 37

At the well that opened the porous reservoir, work was carried out to increase well productivity at a depth of 2795-2814 m.

Prior to work on increasing productivity, the well had an oil production rate of 5 tons / day; water cut - 83%.

Oil recovery enhancement work was carried out in the producing well. For this, they pumped sequentially into the production well: gasoline in the amount of 2 m ³ (330% of the volume of the first rim), then the FRF resin (Geotherm-005) in the amount of 1 m ³ + dispersed blowing agent - Geotherm-105 in 200 kg (20% of the volume of the first rim), gasoline in the amount of 0.5 m ³ (50% of the volume of the first rim).

Injection Pressure = 60 atm, Rkon. = 120 atm. The well was left at a pressure of P = 100 atm for 24 hours. In a day, the injectivity was determined, it was 220 m ³ / day at P = 90 atm.

After carrying out work to increase productivity, the producing well had the following parameters:

Oil production rate - 9.7 tons / day; water cut - 64%.

The injection of components into the bottom of the formation allowed to increase oil recovery by 4.7 tons / day due to additional oil inflows from the transition zone (B2) and its accession (B2) to the productive formation.

Example 38

At the well that opened the porous reservoir, work was carried out to increase the productivity of the well at a depth of 2170-2185 m.

Before the work on increasing productivity, the producing well had the following parameters:

Fluid flow rate - 19 m ³ / day, Oil flow rate - 0.2 t / day, water cut - 99%.

To carry out work to increase productivity, the composition was pumped into the well at the same time: Sinol-M in the amount of 1.5 m ³ (150% of the volume of the first rim), Geotherm-001 polymer resin in the amount of 1 m ³ , with the addition in the amount of 40 kg of carbon ammonium salt (4% of the volume of the first rim), Sinol-M in an amount of 0.5 m ³ (50% of the volume of the first rim), polymer hardener Geotherm-101 in an amount of 1 m ³ (100% of the volume of the first rim), "Sinol-M" in an amount of 0.5 m ³ (50% of the volume of the first rim).

Injection Pressure = 30 atm. Rcon. = 60 atm. The well was left at a pressure of P = 60 atm for 24 hours. In a day, the injectivity was determined, it was 370 m ³ / day at P = 50 atm.

After carrying out work to increase productivity, the producing well had the following parameters:

The oil production rate is 6.8 tons / day, the water cut is 32%.

The injection of components into the bottom of the formation allowed us to increase oil recovery by 6.6 tons / day due to additional oil inflows from the transition zone (B2) and its accession (B2) to the productive formation.

Example 39

At the well that opened the porous reservoir, work was carried out to increase the productivity of the well at a depth of 2160-2177 m.

Before the work on increasing productivity, the producing well had the following parameters:

The flow rate of the liquid is 56 m ³ / day, the flow rate of oil is 2.8 tons / day, the water cut is 95%.

To carry out work to increase productivity, we pumped sequentially into the well: solvent in an amount of 1.5 m ³ (150% of the volume of the first rim), then Geotherm-001 polymer resin in an amount of 1 m ³ , with the addition of 40 kg of aluminum powder (4% of the volume of the first rim), solvent in an amount of 0.5 m ³ (50% of the volume of the first rim), Geotherm-101 polymer hardener in an amount of 1 m ³ (100% of the volume of the first rim), solvent in an amount 0.5 m ³ (50% of the volume of the first rim).

Injection Pressure = 45 atm. Rcon. = 70 atm. The well was left at a pressure of P = 70 atm for 24 hours. In a day, the injectivity was determined, it was 370 m ³ / day at P = 50 atm.

After carrying out work to increase productivity, the producing well had the following parameters:

The oil production rate is 11.5 tons / day, the water cut is 70%.

The injection of components into the bottom of the formation allowed us to increase oil recovery by 8.7 tons / day due to additional oil inflows from the transition zone (B2) and its accession (B2) to the productive formation.

Example 40

At the well that opened the pore reservoir, work was carried out to increase the productivity of the well at a depth of 1181-1197 m.

Before the work on increasing productivity, the producing well had the following parameters:

Fluid flow rate - 20 m ³ / day, Oil flow rate - 1.0 t / day, water cut - 95%.

The composition was pumped into a production well at the same time: fresh water in an amount of 2 m ³ (200% of the volume of the first rim), polymer resin Geotherm-011 in an amount of 1 m ³ , fresh water of 0.2 m ³ (20% of the volume of the first rim ), polymer hardener "Geotherm-111" in an amount of 0.6 m ³ (60% of the volume of the first rim) with the addition of carbon ammonium salt in an amount of 30 kg (3% of the volume of the first rim), fresh water in an amount of 0.2 m ³ (20% of the volume of the first rim).

Injection Pressure = 0 atm. and Rcon. = 25 atm. The well was left at a pressure of P = 20 atm for 24 hours. In a day, the injectivity was determined, it amounted to 320 m ³ / day at P = 20 atm.

After carrying out work to increase productivity, the producing well had the following parameters:

The oil production rate is 4.7 tons / day, the water cut is 72%.

The injection of components into the bottom of the formation allowed to increase oil recovery by 3.7 tons / day due to additional oil inflows from the transition zone (B2) and its accession (B2) to the productive formation.

Example 41

At the well that opened the pore reservoir, work was carried out to increase the productivity of the well at a depth of 635-650 m.

Before the work on increasing productivity, the producing well had the following parameters:

Fluid flow rate - 24 m ³ / day, Oil flow rate - 1.7 tons / day, water cut - 93%.

The composition was pumped into the production well at the same time: fresh water in an amount of 0.5 m ³ (50% of the volume of the first rim), polymer resin Geotherm-011 in an amount of 1 m ³ , fresh water in an amount of 0.5 m ³ (50% of the volume of the first rim) with the addition of sodium bicarbonate in an amount of 20 kg (2% of the volume of the first rim), a polymer hardener "Geotherm-111" in an amount of 0.6 m ³ (60% of the volume of the first rim) with the addition of sodium bicarbonate in an amount 20 kg (2% of the volume of the first rim), fresh water in an amount of 0.2 m ³ (20% of the volume of the first rim).

Injection Pressure = 0 atm. Rcon. = 20 atm. The well was left at a pressure of P = 20 atm for 24 hours. In a day, the injectivity was determined, it was 370 m ³ / day at P = 10 atm.

After carrying out work to increase productivity, the producing well had the following parameters:

The oil production rate is 6.0 tons / day, the water cut is 68%.

The injection of components into the bottom of the formation allowed to increase oil recovery by 4.3 tons / day due to additional oil inflows from the transition zone (B2) and its accession (B2) to the productive formation.

Example 42

At the well that opened the pore reservoir, work was carried out to increase well productivity at a depth of 130-155 m.

Before the work on increasing productivity, the producing well had the following parameters:

Fluid flow rate - 35 m ³ / day, Oil flow rate - 1.05 t / day, water cut - 97%.

The composition was pumped into the production well at the same time: fresh water in an amount of 1 m ³ (100% of the volume of the first rim), polymer resin Geotherm-011 in an amount of 1 m ³ with the addition of sodium carbonate in an amount of 20 kg (2% of the volume of the first rim ), fresh water in an amount of 0.2 m ³ (20% of the volume of the first rim) with the addition of sodium carbonate in an amount of 20 kg, polymer hardener "Geotherm-111" in an amount of 0.6 m ³ (60% of the volume of the first rim) with the addition of sodium carbonate in an amount of 20 kg (2% by volume of the first rim), fresh water in an amount of 0.5 m ³ (about 50% of EMA first rim).

Injection Pressure = 0 atm and Rkon. = 10 atm. The well was left at a pressure of P = 10 atm for 24 hours. In a day, the injectivity was determined, it was 410 m ³ / day at P = 10 atm.

After carrying out work to increase productivity, the producing well had the following parameters:

The oil production rate is 8.7 tons / day, the water cut is 72%.

The injection of components into the bottom of the formation allowed to increase oil recovery by 7.65 tons / day due to additional oil inflows from the transition zone (B2) and its accession (B2) to the productive formation.

Example 43

At the well that opened the pore reservoir, work was carried out to increase the productivity of the well at a depth of 351 m.

Before carrying out work to increase productivity, the well had an oil production rate of 4.2 tons / day; water cut - 87%.

Oil recovery enhancement work was carried out in the producing well. Why the composition was pumped into a production well at the same time: fresh water in an amount of 1 m ³ (100% of the volume of the first rim), Geotherm-011 polymer resin in an amount of 1 m ³ , with the addition of carbon ammonium salt in an amount of 20 kg (2% of volume of the first rim), fresh water in an amount of 0.2 m ³ (20% of the volume of the first rim) with the addition of carbon ammonium salt in an amount of 20 kg (2% of the volume of the first rim), Geotherm-111 polymer hardener in an amount of 0, 6 m ³ (60% by volume of a first rim) with the addition of a blowing agent in an amount of 20 kg (2% by volume of a first GR glasses), fresh water in an amount of 0.5 m ³ (50% by volume of a first rim).

Injection Pressure = 60 atm and Rkon. = 100 atm. The well was left at a pressure of P = 100 atm for 16 hours. After 16 hours, the following injections were made: the Geotherm-06 polymer composition in an amount of 0.8 m ³ , the Geotherm-106 polymer hardener in an amount of 0.4 m ³ (50% from the volume of the first pack), mixed on the surface.

Injection Pressure = 100 atm and Rkon. = 130 atm. The excess polymer solution was cut off, leaving the polymer cup 10 m above the upper holes of the perforation interval. The tubing was raised to a safe depth of 150 m. The well was left under pressure P = 100 atm for 48 hours. After two days, the polymer bridge was drilled and the production string was pressed.

After carrying out work to increase productivity, the producing well had the following parameters:

Oil production - 8.5 tons / day; water cut - 64%.

The injection of components into the bottom of the formation allowed to increase oil recovery by 4.3 tons / day due to additional oil inflows from the transition zone (B2) and its accession (B2) to the productive formation.

Example 44

At the well that opened the pore reservoir, work was carried out to increase the productivity of the well at a depth of 2482-2458 m.

Prior to work on increasing productivity, the well had an oil production rate of 3.6 tons / day; water cut - 91%.

Oil recovery enhancement work was carried out in the producing well. Why the composition was pumped into a production well at the same time: fresh water in an amount of 1 m ³ (100% of the volume of the first rim), Geotherm-011 polymer resin in an amount of 1 m ³ , fresh water in an amount of 0.2 m ³ (20% of the volume of the first rim) with the addition of carbon ammonium salt in an amount of 20 kg (2% of the volume of the first rim), polymer hardener "Geotherm-111" in an amount of 0.6 m ³ (60% of the volume of the first rim) with the addition of carbon ammonium salt in an amount 20 kg (2% of the volume of the first rim), fresh water in an amount of 0.5 m ³ (50% of the volume of the first rim).

Injection Pressure = 125 atm and Rkon. = 130 atm. The well was left at a pressure of P = 100 atm for 16 hours. After 16 hours, the following was pumped: polymer composition “Geotherm-06” in an amount of 0.8 m ³ and polymer hardener “Geotherm-106” in an amount of 0.4 m ³ (50% from the volume of the first pack), mixed on the surface.

Injection Pressure = 135 atm. and Rcon. = 150 atm. The excess polymer solution was cut off, leaving the polymer cup 10 m above the upper holes of the perforation interval. The tubing was raised to a safe depth of 150 m. The well was left at a pressure of P = 100 atm for 24 hours. After a day, the polymer bridge was drilled and the production string was pressed.

After carrying out work to increase productivity, the producing well had the following parameters:

Oil production rate - 3.7 tons / day; water cut - 63%.

The injection of components into the bottom of the formation allowed to increase oil recovery by 4.3 tons / day due to additional oil inflows from the transition zone (B2) and its accession (B2) to the productive formation.

Example 45

At the well that opened the fractured reservoir, work was carried out to increase the productivity of the well at a depth of 3277 m. Prior to work to increase productivity, the well had an oil production rate of 0.1 t / day; water cut - 99.9%.

The work was carried out in the producing well, for which the composition was pumped into it at the same time: BFLH in the amount of 50 m ³ (5000% of the volume of the first rim), polymer resin “Geotherm-007” in the amount of 1 m ³ , fresh water in the amount of 5 m ³ ( 500% of the volume of the first rim) with the addition of carbon ammonium salt in an amount of 20 kg (2% of the volume of the first rim), polymer hardener "Geotherm-107" in an amount of 0.6 m ³ (60% of the volume of the first rim) with the addition of carbon ammonium salt in an amount of 20 kg (2% by volume of a first rim), fresh water in an amount of 0.5 m ³ (50% by volume of a first torochki).

Injection Pressure = 0 atm and Rkon. = 30 atm. The well was left at a pressure of P = 30 atm for 16 hours. After 18 hours, the following was injected: Geotherm-006 polymer resin in an amount of 1.0 m ³ (100%) and Geotherm-106 polymer hardener in an amount of 0.4 m ³ (40% of the volume of the first rim), mixed on the surface.

Injection Pressure = 30 atm. and Rcon. = 50 atm. The excess polymer solution was cut off, leaving the polymer cup 10 m above the leakage interval, the tubing was raised to a safe depth of 150 m. The well was left under pressure P = 50 atm. for 24 hours. After a day, the polymer bridge was drilled and the wellbore was pressed.

After carrying out work to increase productivity, the producing well had the following parameters:

Oil production rate - 26.2 t / day; water cut - 65%.

The injection of components into the bottom of the formation allowed us to increase oil recovery by 26.1 tons / day due to additional oil inflows from the transition zone (B2) and its accession (B2) to the productive formation.

Example 46

At the well that opened the fractured reservoir, work was carried out to increase the productivity of the well at a depth of 3120 m.

Prior to work on increasing productivity, the well had an oil production rate of 0.4 tons / day; water cut - 99.6%.

Oil recovery enhancement works were carried out in the production well, for which they pumped sequentially into the production well: acetone in an amount of 40 m ³ (4000% of the volume of the first rim), then Geotherm-007 polymer resin in an amount of 1 m ³ , fresh water in an amount 4 m ³ (400% of the volume of the first rim) with the addition of carbon ammonium salt in an amount of 25 kg (2.5% of the volume of the first rim), polymer hardener "Geotherm-107" in an amount of 0.5 m ³ (50% of the volume of the first rims) with the addition of ammonium carbonate in an amount of 25 kg (2.5% of the volume of the first rim), fresh South water in an amount of 0.4 m ³ (40% of the volume of the first rim).

Injection Pressure = 0 atm and Rkon. = 40 atm. The well was left at a pressure of P = 40 atm for 24 hours. After 24 hours, the following was injected: Geotherm-006 polymer resin in an amount of 1.0 m ³ (100%) and Geotherm-106 polymer hardener in an amount of 0.4 m ³ (40% of the volume of the first rim), mixed on the surface.

Injection Pressure = 40 atm and Rkon. = 60 atm. The excess polymer solution was cut off, leaving the polymer cup 10 m above the leakage interval, the tubing was raised to a safe depth of 150 m.The well was left under pressure P = 60 atm for 24 hours. After a day, the polymer bridge was drilled and the wellbore was pressed.

After carrying out work to increase productivity, the producing well had the following parameters:

The oil production rate is 18.9 tons / day; water cut - 56%.

The injection of components into the bottom of the formation allowed us to increase oil recovery by 18.5 tons / day due to additional oil inflows from the transition zone (B2) and its accession (B2) to the productive formation.

Example 47

At the well that uncovered the fractured reservoir, work was done to increase the productivity of the well at a depth of 2987 m.

Prior to work on increasing productivity, the well had an oil production rate of 0.2 t / day; water cut - 99.4%.

Oil recovery enhancement works were carried out in the producing well, for which purpose they pumped sequentially into the producing well: industrial water in an amount of 25 m ³ (2500% of the volume of the first rim), Geotherm-007 polymer resin in an amount of 1 m ³ , fresh water in an amount 2 m ³ (200% of the volume of the first rim), polymer hardener "Geotherm-107" in an amount of 0.5 m ³ (50% of the volume of the first rim) with the addition of carbon ammonium salt in an amount of 30 kg, fresh water in an amount of 0.4 m ³ (40% of the volume of the first rim).

Injection Pressure = 0 atm and Rkon. = 25 atm. The well was left at a pressure of P = 25 atm for 20 hours. After 20 hours, dry cement was pumped in diesel fuel with a density of 1.55 g / cm ³ in an amount of 4 m ³ (400% of the volume of the first rim) and industrial water in an amount of 0.5 m ³ (50% of the volume of the first rim)

Injection Pressure = 25 atm and Rkon. = 70 atm. The excess cement slurry was cut with the cement-polymer cup remaining 10 m above the leakage interval, the tubing was raised to a safe depth of 150 m. The well was left at a pressure of P = 70 atm for 24 hours.

A day later, the cement-polymer bridge was drilled and the wellbore was pressed. After carrying out work to increase productivity, the producing well had the following parameters:

Oil production - 14.9 tons / day; water cut - 67%.

The injection of components into the bottom of the formation allowed us to increase oil recovery by 14.7 tons / day due to additional oil inflows from the transition zone (B2) and its accession (B2) to the productive formation.

The proposed technical solution, by injecting the components directly into the transition zone B1 of the producing well, cutting off the water saturation zone A from the zone of maximum oil saturation G, either directly into the well of the injection well, or simultaneously into the producing and injection wells, allows to increase the productivity of the well due to inflows of well production from transition zone B2, connecting it to the reservoir, thereby thickening the reservoir, taking into account the subzone of loose-bound water of the transition zone, cutting off this subzone from the reservoir, and taking into account the presence or absence of clay bridges at the boundaries of the marginal water saturation zone and the transition zone.

The method can be additionally used to reduce or prevent the transfer of sands and proppants to the wellbore, reduce or limit annular circulation, eliminate the absorption of drilling fluid while drilling exploration and production wells, and restore the tightness of production casing.

Claims (24)

1. A method of increasing well productivity, including injecting the first and second rims through a hydrocarbon or water-based release fluid into the calculated area of the well, characterized in that in productive formations with loose - poorly cemented porous and / or fractured reservoirs, the presence of a zone of residual oil saturation is determined, determined the presence of a zone of maximum water saturation, determine the presence of an unsaturated transition zone with a zone of loose-bound water with an intense flow of diffuse layers of water and a zone of high oil content, determine the presence of a zone of maximum oil saturation, take into account the presence or absence of clay bridges at the boundaries of a zone of maximum water saturation and a transition zone, cut off a water-saturated zone from a zone of maximum oil saturation and provide an influx of oil into a reservoir from a subzone of a high oil content, injection is carried out in the calculated the area of production and / or injection wells, while the separation fluid is pumped in an amount of from 0.1 to 500% of the volume of the first rim, in oruyu rim injected in an amount of from 0.1 to 250% by volume of the first rim, the first rim as a polymer resin as the second rim is used polymeric hardener, is carried out after the injection well in the hydrocarbon inflow transfer mode. 2. The method according to p. 1, characterized in that as the polymer hardener use a liquid or powder polymer hardener of acidic or neutral composition. 3. The method according to p. 1, characterized in that it further carry out the injection of a cement mixture on a hydrocarbon basis in an amount of from 0.1 to 2000% of the volume of the first rim through a water-based separation liquid. 4. The method according to p. 1, characterized in that it further carries out the shutter speed of the well at rest for a predetermined time interval after the injection of the second rim. 5. The method according to p. 1, characterized in that the separation liquid is additionally equipped with a pore former in a given volume. 6. The method according to p. 1, characterized in that the first rim is additionally equipped with a pore former in a given volume. 7. The method according to p. 1, characterized in that the second rim is additionally equipped with a pore former in a given volume. 8. The method according to p. 1, characterized in that as a blowing agent use powdered or liquid products. 9. The method according to p. 1, characterized in that as the polymer hardener use a liquid or powder polymer hardener of an alkaline composition. 10. A method of increasing well productivity, including injecting a viscoelastic pack, first and second rims through a separation fluid into the calculated area of the well, characterized in that in productive formations with loose - poorly cemented porous and / or fractured reservoirs, the presence of a zone of residual oil saturation is determined, the presence of a zone is determined water saturation limit, determine the presence of an unsaturated transition zone with a zone of loose-bound water with an intense flow of diffuse layers of water and with a subzone higher content of oil, determine the presence of the zone of maximum oil saturation, take into account the presence or absence of clay bridges at the boundaries of the zone of maximum water saturation and the transition zone, cut off the saturated zone from the zone of maximum oil saturation and ensure the flow of oil into the reservoir from the subzone of high oil content, injection is carried out in the calculated area production and / or injection wells, while a viscoelastic pack is pumped in an amount of from 0.1 to 5000% of the volume of the first rim, the second rim is injected they are pumped in an amount from 0.1 to 250% of the volume of the first rim, the release fluid is pumped in an amount of from 0.1 to 500% of the volume of the first rim, and a cement or polymer-cement mortar is pumped in an amount of from 0.1 to 2000% of the volume of the first rim , a polymer resin is used as the first rim, a polymer hardener is used as the second rim, a water-based or hydrocarbon-based cement mortar is used as a cement mortar, after the injection, the well is transferred to the hydrocarbon inflow mode Oh yeah. 11. The method according to p. 10, characterized in that it further carries out the shutter speed of the well at rest for a predetermined time interval after injection of a water-based release fluid. 12. The method according to p. 10, characterized in that the first rim is additionally equipped with a pore former in a given volume. 13. The method according to p. 10, characterized in that the second rim is additionally equipped with a pore former in a given volume. 14. The method according to p. 10, characterized in that it further injects the separation fluid in an amount of from 0.1 to 500% of the volume of the first rim after injection of a viscoelastic pack. 15. The method according to p. 10, characterized in that the separation liquid is additionally provided with a pore former in a predetermined volume. 16. The method according to p. 10, characterized in that as a blowing agent use powdered or liquid products. 17. The method according to p. 10, characterized in that as the polymer-cement solution using a solution of polymer resin with a hardener and cement with a density of 1.45-1.5 t / m ³ . 18. A method of increasing well productivity, including injecting the first and second rims through a separation fluid, a viscoelastic pack into the calculated area of the well, characterized in that in productive formations with loose - poorly cemented porous and / or fractured reservoirs, the presence of a zone of residual oil saturation is determined, the presence of a zone is determined water saturation limit, determine the presence of an unsaturated transition zone with a zone of loose-bound water with an intense flow of diffuse layers of water and with a subzone higher content of oil, determine the presence of the zone of maximum oil saturation, take into account the presence or absence of clay bridges at the boundaries of the zone of maximum water saturation and the transition zone, cut off the saturated zone from the zone of maximum oil saturation and ensure the flow of oil into the reservoir from the subzone of high oil content, injection is carried out in the calculated area production and / or injection wells, while the second rim is pumped in an amount from 0.1 to 250% of the volume of the first rim, a viscoelastic injection pack they are mixed in an amount from 0.1 to 5000% of the volume of the first rim, cement or polymer-cement mortar is pumped in an amount of from 0.1 to 2000% of the volume of the first rim, a polymer resin is used as the first rim, a polymer hardener is used as the second rim, water-based or hydrocarbon-based cement mortar is used as a cement mortar; after injection, the well is transferred to the hydrocarbon inflow mode. 19. The method according to p. 18, characterized in that as the polymer hardener use a liquid or powder polymer hardener of acidic or neutral composition. 20. The method according to p. 18, characterized in that as the polymer hardener use a liquid or powder polymer hardener of an alkaline composition. 21. The method according to p. 18, characterized in that it further carries out the shutter speed of the well at rest for a predetermined time interval after the injection of the second rim. 22. The method according to p. 18, characterized in that the first rim is additionally equipped with a pore former in a given volume. 23. The method according to p. 18, characterized in that the second rim is additionally equipped with a pore former in a given volume. 24. The method according to p. 18, characterized in that as a blowing agent use powdered or liquid products.