RU2613215C1 - Method for thermal action on formation - Google Patents

Abstract

FIELD: mining.

SUBSTANCE: method of thermal action on formation contains studying of the formation physical parameters, determining in-situ pressure of the formation and the fracturing pressure in the formation header, construction in a horizontally directed well barrel, containing a sealed heater filled with coolant in a heat exchanger form, and the liquid heating in the well barrel is carried out via pumping of a coolant preheated on the surface of the coolant. When heating the formation in the well, the pressure is maintained not less than the level of the initial formation pressure and not exceeding the pressure forming fractions in the header due to withdrawal of gas and liquid from the lower level of the well. The directional barrel is constructed upward to the bottom hole with a slope, excluding the downward to the bottom sections and consist of two parts. The first part the closest to the mouth, are built at the angle not exceeding 30° relatively to the horizon, and is equipped with a heater, which does not reach the end of the first part from 1/4 upto 3/4 of its length. The second part at the bottom hole is built with an angle of 40-90° relatively to the horizon.

EFFECT: restoration of the hydraulic connection of the formation with the well, increase in oil recovery from heavy oil formations and well capacity, ability to restart the operation of unprofitable oil, natural gas, fresh, mineral and thermal waters wells.

3 cl, 2 dwg

Description

The invention relates to mining and can be used for heat treatment of a productive formation with highly viscous oil, restoration of hydraulic connection between a formation and a well, increase in oil recovery from highly viscous oil and production rates, as well as the resumption of unprofitable wells for oil, natural gas, fresh, mineral and thermal waters.

The well-known "Method for the development of high-viscosity oil deposits" (patent RU No. 2379494, ЕВВ 43/24, published on January 20, 2010) using a pair of horizontal injection and production wells, the horizontal sections of which are placed parallel to one another in the vertical plane of the reservoir, equipped with a column tubing allowing simultaneous injection of coolant and product selection, injection of coolant, heating of the reservoir with the creation of a steam chamber, selection of products through a production well through a pumping well -compressor pipes and control of technological parameters of the formation and the well, with the ends of the tubing strings being located at opposite ends of the conventionally horizontal section of the wells, heating of the productive formation begins with steam injection into both wells, heats the inter-well zone of the formation, reduces the viscosity of highly viscous oil, and the steam the chamber is created by the injection of a coolant propagating to the upper part of the reservoir with an increase in the size of the steam chamber during the selection process, Eski, 2-3 times a week, determine the mineralization of the water being taken in by way, analyze the effect of changes in the mineralization of the water being taken in on the uniformity of heating the steam chamber, and taking into account the changes in the mineralization of the water being taken in, the steam chamber is uniformly heated by adjusting the coolant injection mode or selecting production wells Achievement of a stable mineralization value of associated water.

The disadvantages of this method are:

- a narrow scope associated with the inability to use to increase the productivity of formations with fresh, mineral and thermal waters;

- complex control over the process of steam-gravitational impact (PGW), which requires stopping the selection process for the analysis of its mineralization;

- large non-production costs associated with heating the coolant (practically not decreasing with increasing temperature in the heated formation) to high temperatures for injection into the formation, where it mixes with the production of the formation and with which the formation rises to the surface (at least 80% of the coolant in the produced products), after which a lot of money is spent on separating the coolant from the formation products;

- high pressure injection of the coolant (up to 20-40 MPa) into the reservoir, which can cause a breakthrough of the coolant in the aquifers and / or absorbing strata, which may lead to the inability to use the method or violate the environmental situation in underground water sources;

- it is impossible to analyze the parameters of the injection well without stopping its operation;

- oil recovery factor does not exceed 40% due to the formation of zones with a low relative to the initial reservoir resistivity and mudding due to high pressure exposure of sections of the reservoir that are not in zones with low reservoir resistance, which eliminates their further extraction using wells;

- the need to build expensive additional pairs of injection and producing horizontal wells, since the use of horizontal wells with a length of more than 200-250 m and a diameter of more than 140 mm does not affect the heating efficiency due to the formation of zones with low formation resistance in the formation;

- high financial and material costs of the use of expensive equipment operating at high pressures, and the need to build at least one pair of horizontal sections of the injection and production wells.

The well-known "Method of developing deposits of heavy and ultra-viscous oils" (patent RU No. 2387818, ЕВВ 43/24, publ. 04/27/2010), including the injection of steam into the reservoir, heating the reservoir with the creation of a steam chamber, the combined injection of steam and hydrocarbon solvent and product selection moreover, a mixture of hydrocarbons of the limiting aliphatic and aromatic series, the main component of which is benzene, is used as a hydrocarbon solvent, and steam and a hydrocarbon solvent are injected together after reaching a temperature of ApoB chamber not less than the phase transition temperature of the mixture of steam and a hydrocarbon solvent, while the temperature in the steam chamber is not lower than the phase transition temperature steam mixture - hydrocarbon solvent.

The disadvantages of this method are:

- a narrow scope associated with the inability to use to increase the productivity of formations with fresh, mineral and thermal waters;

- complex control over the process of steam-gravitational impact (PGW), which requires stopping the selection process for the analysis of its mineralization;

- large non-production costs associated with heating the coolant (practically not decreasing with increasing temperature in the heated formation) to high temperatures for injection into the formation, where it mixes with the production of the formation and with which the formation rises to the surface (at least 80% of the coolant in the produced products), after which a lot of money is spent on separating the coolant from the formation products;

- high costs for the use of hydrocarbon solvent, since it is used as a percentage of the injected steam (3-20 t / h);

- high pressure injection of the coolant (up to 20-40 MPa) into the formation, which can cause a breakthrough of the coolant in the water-bearing and / or absorbing layers, which may lead to the inability to use the method or to disrupt the environmental situation in underground water sources;

- it is impossible to analyze the parameters of the injection well without stopping its operation;

- the need to build expensive additional horizontal injection wells, since the use of horizontal wells with a length of more than 200-250 m and a diameter of more than 140 mm does not affect the heating efficiency due to the formation of zones with low reservoir resistance in the formation;

- The oil recovery factor does not exceed 45% due to the formation of zones with a low relative to the initial reservoir resistivity and mudding due to high pressure exposure of sections of the reservoir that are not in zones with low reservoir resistance, which excludes their further extraction using wells;

- high financial and material costs of the use of expensive equipment operating at high pressures, and the need to build at least one pair of horizontal sections of the injection and production wells.

The well-known "Method of increasing oil recovery by exposure to the bottomhole formation zone by ultrasonic radiation (ultrasound)" (patent RU No. 2353760, ЕВВ 43/16, 43/24, 28/00, publ. 04/27/2009), which consists in simultaneous vibration and heat exposure moreover, the ultrasonic radiation is directed from the ground part of the well into the well through the tubing of the well, along the stem of the well pump and along the submersible waveguide located in the tubing and / or in the gap between the tubing and casing, stvlyayut during oil production from the well without stopping, and ultrasound power density supplied to the waveguides are selected in the range from 0.1 to 10 kW / cm ^2.

The disadvantages of this method are:

- a narrow scope associated with the inability to use to increase the productivity of formations with fresh, mineral and thermal waters;

- also a narrow scope associated with the need to select the column used for ultrasound transmission, with almost the same acoustic and electrical parameters of all its pipes and the formation with fairly uniform parameters along the entire opening length to eliminate the effect of “attenuation” of ultrasound during transmission through the pipe string and impact on the reservoir;

- it is necessary to use special expensive equipment (cables, sensors, relays, control panels, connection nodes, etc.), designed for the high power consumed by the ultrasound generator;

- it is impossible to analyze the parameters of the well and select products without stopping the operation of the ultrasound generator;

- high energy costs with a relatively small coverage of the reservoir, which significantly increases the time (not less than 20 times compared with the PGW) before the start of industrial development.

The closest in technical essence is the "Method of heat treatment of the bottom-hole zone of the well" (patent RU No. 2266401, ЕВВ 43/24, published on December 20, 2005), which includes filling a part of the body of the electrode heater with water, sealing it, placing it in the well and heating the bottom-hole zone wells, and the upper part of the casing is filled with inert gas under the initial pressure p ₁ and after placing the casing in the bottomhole zone of the well, water is heated to the working supercritical temperature T ₂ , while pressure p ₁ is determined from the relationship:

where p ₂ is the working pressure inside the heater body corresponding to the temperature T ₂ , Pa;

T ₁ - initial water temperature, K;

V is the volume of the heater body, m ³ ;

V ₂ - the working volume of water at a pressure of p ₂ and a temperature of T ₂ , m ³ ;

V ₁ - the volume of water at a pressure p ₁ and a temperature T ₁ , m ³ .

The disadvantages of this method are:

- narrow scope associated with the inability to use this method in horizontal wells due to descent on the cable;

- also a narrow scope associated with the need to conduct work near high-voltage power lines (power lines), since the generation of 1 MW of heat at a voltage of 380 V requires a current of 3700 A (which is approximately equal to the simultaneous use of 180 welding machines);

- it is necessary to use special expensive equipment (cables, sensors, relays, control panels, connection nodes, etc.) designed for high power consumed by the heater;

- an increase in the length of the electrode heater reduces the temperature by a unit of its length, which makes this method inefficient in wells with a large length of stimulation;

- high energy costs with a relatively small coverage of the reservoir, which significantly increases the time (about 15-20 times compared with even the GWP) before the start of industrial development;

- it is impossible to carry out the selection and analysis of well products without stopping the operation of the electrode heater, since for its effective operation it is necessary to install a packer in a vertical well above the formation that it affects.

The closest in technical essence is the "Method of thermal exposure to the reservoir" (patent RU No. 2471064, ЕВВ 43/24, publ. 12/27/2012, bull. No. 36), including filling the sealed heater with coolant, placement in the well and heating the bottom-hole zone of the well moreover, the bottom-hole zone of the well is built in the form of a horizontally-inclined or horizontal wellbore, the heater is made in the form of a circulation heat exchanger, in which pumping preheated on the surface of the coolant is carried out before placing the heat exchanger and they study the physical parameters of the formation, determine the in-situ pressure of the formation and the pressure of formation of cracks in the reservoir, while heating the bottom-hole zone of the formation in the well, maintain pressure not lower than the initial formation pressure of the formation and not higher than the pressure of formation of cracks in the reservoir due to the selection of gas and liquid from the well from the lowest level.

The disadvantages of the method are:

- a decrease in the efficiency of the method due to the construction of the well without taking into account the roughness of the horizontal wellbore in the formation;

- high material costs associated with the need to build a heat exchanger in the reservoir for the entire length of a horizontally-inclined or horizontal wellbore, as they require individual development of a heat exchanger, ordering materials and manufacturing for each well;

- low efficiency at the initial stage of the implementation of the method, since only the annular space inside the well between the inner wall and the heat exchanger works to displace formation products;

- increased time before the start of productive production in massive boards with a thickness of more than 50 and / or layer-by-layer heterogeneous formations, since it is difficult to supply heat at the initial stage to the bedroof part of the formation.

An object of the present invention is to provide a method of thermal action on a massive and / or layer-heterogeneous formation that works efficiently and at low material cost due to the possibility of using a unified heat exchanger for any of the wells and due to an increase in the free volume inside the well and the strength of steam rising from - due to the pressure drop, as well as due to the construction of the well, taking into account the possible curvature of the wellbore and the thickness and structure of the formation.

The technical problem is solved by the method of thermal action on the formation, including the study of the physical parameters of the formation, determination of the in-situ pressure of the formation and the pressure of formation of cracks in the reservoir, the construction of a horizontally inclined wellbore in the formation, in which a sealed heater filled with a coolant is placed in the form of a heat exchanger, heating the fluid in the wellbore due to pumping in the heater preheated on the surface of the coolant, and when the formation is heated in the well maintain a pressure not lower than the initial reservoir pressure of the formation and not higher than the pressure of formation of cracks in the reservoir due to the selection of gas and liquid from the lower level of the well.

New is that an oblique directional trunk is built ascending to the bottom with a slope that excludes sections descending to the bottom and consisting of two parts, the first of which, closest to the mouth, is built with an angle not exceeding 30 ° relative to the horizon, and equipped with a heater, which does not reach the end of the first part from 1/4 to 3/4 of its length, and the second part at the bottom of the well is built with an angle of 40-90 ° relative to the horizon.

Also new is the fact that in the layered-heterogeneous formations, the second part of the trunk is built with a length sufficient for opening all productive layers, and with an angle that allows opening these layers.

Also new is the fact that in massive formations, the second part of the trunk is built with a length sufficient to open from 1/2 to 4/5 of the thickness of the formation, and with an angle relative to the horizon, the greater the greater the thickness of the formation.

In FIG. 1 shows a diagram for the implementation of a well with a directional wellbore.

In FIG. 2 shows a section AA of FIG. one.

The method is implemented as follows.

Build a well 1 (Fig. 1) with the placement of a directional shaft 3 in the reservoir 2, in which the casing 5 is perforated 4 (or during construction, the casing is equipped with sand filters - not shown). Then a sealed heater 6 is lowered into the well 1, for example, made in the form of a pipe 7 in a pipe 8, which is filled with a heat carrier and connected to a heat generator 9, for example: to a heat exchanger or heating boiler. In this case, the directional barrel 3 consists of two parts 10 and 11. The first part 10, closest to the wellhead 1, is built with an angle α1 not exceeding 30 ° (α1≤30 °) relative to the horizon, and equipped with a heater that does not reach to the end of the first part from 1/4 to 3/4 of its length. The second part 11 at the bottom 12 of the well 1 is built with an angle α2 = 40-90 ° relative to the horizon.

Moreover, the length of the heater 6 in the first part 10 of the directional barrel 3 should be (empirically determined):

where L _article - the length of the first part 10 of the directional shaft 3 of the well 1, m;

L _load - the length of the heater 6 in the barrel 3 of the well 1, m

Since heater 6 is hermetic, any high-temperature coolants, including synthetic oils (for example, Therminol by Solutia Inc., a coolant designed to operate in the range temperatures from - 115 ° С to + 400 ° С in the liquid and vapor phase or similar oils from other manufacturers: BP, Shell, etc.) The heater 6 will be connected to the heat generator 9 at the wellhead 1, which will heat the heat carrier and from which pump 13 produce A portion of the preheated coolant through the circulation heater 6, for example: the coolant is pumped into the inner pipe 7 by the pump 13 to the muffled end 14 of the outer pipe 8, from where it rises to the surface through the annular space of these pipes 7 and 8 and is looped in the heat generator 9. For a more efficient warming up the formation 2, the first part 10 of the barrel 3 of the well 1, it is recommended to build horizontally inclined, ascending to the bottom 12 with a slope α1 relative to the horizon, excluding sections descending to the bottom 12 of the well 1, but not more than 30 °, because natural convection is used for heating, which is more effective the larger the horizontal projection of part 10 of the barrel 3. Practice for the fields of the Republic of Tatarstan shows that to exclude 12 wells 1 sections descending to the bottom, for wells 1 with casing ∅168 mm part 10 of trunk 3 must be built with a slope of α: at least 2 ° for carbonate and at least 3 ° 20 'for terrigenous strata. Due to this design of the barrel 3, hydraulic locks in part 10 of the barrel 3 of the well 1 are eliminated. In order to eliminate errors in the construction of the barrel 3 of the well 1, the angle α1 is selected from 5 ° to 30 °. This structure of the part 10 of the barrel 3 of the well 1 allows the heater to be placed not for the entire length of the part 10 of the barrel 3. To ensure more intense heating in the layered-heterogeneous and massive layers 2, it is necessary to build the second part 11 of the barrel 3 with an angle α2 from 40 ° to 90 ° inclusive .

In layered heterogeneous formations 2, the second part 11 of the trunk 3 is built with a length L _st.v sufficient to open all productive layers (not shown) of formation 2, and with an angle α2 that allows opening these layers. Since, depending on the strength of the bridges (not shown) between productive layers more at a flatter entrance, drilling of the bridges and “slipping” of the drilling tool will be more difficult during their drilling.

до 4/5 толщины пласта, и с углом α2 относительно горизонта, тем большим, чем больше толщина пласта. На месторождениях Республики Татарстан, например, при толщине пласта 2 50÷70 м (Н_пл - см. фиг. 2) рекомендуется α2=40°÷60°, а при толщине более 70 м - 60°÷90°. От угла зависит длина части 11 ствола 3 L_ст.в и, как следствие, материальные затраты на строительство, исходя из которых и рассчитывают длину L_ст.в. Расстояние от кровли пласта 2 до забоя 12 скважины 1 Н2 должно быть:In massive strata 2, the second part 11 of the trunk 3 is built with a length of L _st.v , sufficient to open from

up to 4/5 of the thickness of the reservoir, and with an angle α2 relative to the horizon, the greater the greater the thickness of the reservoir. In deposits of the Republic of Tatarstan, for example, with a layer thickness of 2 50 ÷ 70 m (N _pl - see Fig. 2), α2 = 40 ° ÷ 60 ° is recommended, and with a thickness of more than 70 m - 60 ° ÷ 90 °. The length of part 11 of the barrel 3 L _st.v and, as a consequence, the material costs of construction, on the basis of which the length L _st.v. The distance from the roof of the formation 2 to the bottom 12 of the well 1 H2 should be:

where H2 is the distance from the roof of the formation 2 to the bottom 12 of the well 1, m;

N _PL - the thickness of the reservoir at the location of the bottom face 12, m

This ratio is determined depending on the initial permeability of formation 2: the greater the permeability, the farther from the roof should be placed the bottom face 12 of well 1 (determined empirically).

When producing highly viscous and bituminous oils, it is recommended that prior to placing heater 6, a study is made of the physical parameters of formation 2 to determine the in-situ pressure of formation 2 in the initial state and the pressure of formation of cracks in the reservoir of formation 2. After the heater 6 is released when heating the formation 2, pressure is maintained in well 1, recorded on the manometer 15 (taking into account the location on the mouth), not lower than the initial reservoir pressure of the formation 2, in order to eliminate the violation of the integrity of the reservoir collector 2 when it is selected products, and not higher than the pressure of cracking in this reservoir, to exclude the formation of cracks with low resistance, which can cause breakthrough of steam or heated fluid, reducing the coverage and oil recovery of formation 2, and also to exclude a breakthrough into other layers (not shown), including including aquifers. When working while heating the bottom-hole zone 3 when boiling the products of the formation 2, the pressure in the well 1 rises (for maximum efficiency, use the temperature for heating exceeding the boiling point of the products of the formation), which is noted on the pressure gauge 15, which shows the pressure in the well 1 taking into account the depth formation 2, and as the selection of products from formation 2, the pressure estimated by the manometer 15 decreases. Assessing the readings of the pressure gauge 12, a decision is made to select the products of the formation 2 from the well 1 or to pump the pump 16 with liquid or steam into the formation 2 through the well 1, monitoring the pressure in the well 1, which is transmitted to the formation 2.

At the beginning of heating of the formation 2, the pressure in the well 1 increases due to boiling and expansion of the liquid products of the formation 2 and expansion of the gas at the bottom of the well 1 (located at a depth of H2), which heat up and rise along the vertical section 17 of the well 1, are selected and condensed, for example, prefabricated tank 18. In this case, light fractions of the products of the formation 2 released during the heating of the product can condense and collect in the tank 18 for further technological operations.

As it warms up and is covered by the temperature effect of the formation 2, the volume of incoming products into the well 1 increases and the power of the heater 6 is not enough to bring the fluid coming from the formation 2 to a boil. Then, the products of the formation 2 are selected using a submersible pump 19 (rod or high-temperature screw) run on a parallel pipe string 17, using double-barrel wellhead 21 (conventionally shown), with an input 22 located at the lowest possible level H1 of well 1 to ensure the most efficient about the selection of reservoir products 2.

As a result of the selection of the production of formation 2 from well 1 or other production wells (not shown), covered by the thermal effect of well 1, and an increase in the coverage of the temperature effect of formation 2, inside the formation pressure decreases. To maintain pressure in the formation 2, a liquid is pumped into it through a well 1 by a pump 16 (for example, water, water with solvents, including hydrocarbon, oil, etc.), carbonated liquid and / or drained steam. As a result, the liquid is brought to a boil under the action of the heater 6, and the gas, the generated steam and / or the injected steam is additionally heated, and creates the pressure necessary for further development in the well 1, which acts on the formation 2. Light fractions from the produced can be used as a hydrocarbon solvent products of formation 2 located in tank 18. Water with hydrocarbon solvents, oil and carbonated liquid are used when injected into formation 2 for the most efficient displacement with additional liquefaction eat highly viscous and bituminous oils from it. Water and steam are used in aquifers or oil reservoirs in which a vapor chamber (not shown) has already formed at the roof of the formation above the well 1 to maintain a balance between temperature, pressure and the volume of the chamber, which maintains the water in it in a vapor state.

Wellhead valves 23 are used to distribute the produced products of the formation 2 and inject liquid or steam and control the volumes of coolant injection in the heater 6. To center the heater 6 relative to the walls of the casing 5 (Fig. 2) of the well 1 (Fig. 1), rigid or spring centralizers are used 24 (Fig. 2), for centering the inner pipe 7 relative to the outer pipe 8 - centralizers 25.

The placement of the heater 6 (Fig. 1) not the entire length of the barrel 3 allows you to increase at the initial stage the volume of steam generated in the well 1, at the initial stage of the implementation of the method in relation to the closest analogue, which directly increases the efficiency of the proposed method, since the method is implemented using natural convection, the displacement force (Archimedes force) of which depends on the volume of the generated vapor (gas).

In the closest analogue, the resulting volume of steam involved in natural convection is calculated by the formula:

where V _1n - the resulting volume of steam in the barrel 3 in the closest analogue, m ³ ;

D _SLE - the inner diameter of the trunk 3 of the well 1, m;

_LOAD D - outside diameter of the heater 6 in the barrel 3, m;

L _article - the length of part 10 of the trunk 3 of the well 1, m

In the proposed method, the resulting volume of steam involved in natural convection is calculated by the formula:

where V _2n - the resulting volume of steam in the barrel 3 in the proposed method, m ³ ;

D _SLE - the inner diameter of the trunk 3 of the well 1, m;

_LOAD D - outside diameter of the heater 6 in the barrel 3, m;

L _article - the length of part 10 of the barrel 3 of the well 1, m;

L _load - the length of the heater 6 in the wellbore 3 of the well 1, m;

L _{St. in} - the length of part 11 of the barrel 3 of the well 1, m

And the difference of the obtained steam volumes ΔV in the proposed method and the closest analogue, ceteris paribus, will be subject to the inequality [1]:

where V _1n - the resulting volume of steam in the barrel 3 in the closest analogue, m ³ ;

V _2p - the resulting volume of steam in the barrel 3 in the proposed method, m ³ ;

_LOAD D - outside diameter of the heater 6 in the barrel 3, m;

L _article - the length of part 10 of the barrel 3 of the well 1, m;

D _SLE - the inner diameter of the trunk 3 of the well 1, m;

L _{St. in} - the length of part 11 of the barrel 3 of the well 1, m

For well 1, 250 m long, in a formation 100 m thick with α2 = 70 ° C Н2 = 30 m, casing diameter 5-168 mm (internal D _well ≈0.15 m) and heater outer diameter 6-100 mm (0 , 1 m), the resulting volume of steam in the proposed method is greater than in the closest analogue by 1.4-1.8 times.

At the same time, the pressure drop in the well 1 ΔР between the lowest point H1 and the bottom level 12 - Н2 allows initiating a more intense rise of steam (due to the lifting force of Archimedes) and, as a result, allows layer-by-layer inhomogeneous and / or massive formation 2 to be heated more quickly throughout its thickness:

where ΔР _s - pressure drop in the well, Pa;

R _well - the density of the well fluid, kg / m ³ ;

ρ _p - the density of the vapor generated during heating in borehole conditions, kg / m ³ ;

ΔН = H1-H2 - height difference in the well 1, m;

g = 9.81 - acceleration of gravity, m / s ² .

Using the heater 6 length L _LOAD ≈ 180 m is possible in the parts 10 of the barrel 3 wells length D 1 _rms ≈240 ÷ 720 m, and the heater length L _LOAD ≈ 300 m - 10 parts in the barrel 3 wells length D 1 _rms ≈400 ÷ 1200 m This greatly reduces the cost of construction of the well 1, since it does not require individual development of the heat exchanger 6, ordering materials and manufacturing it for each well 1.

The proposed method of thermal exposure to a massive and / or layer-heterogeneous formation works efficiently and with low material costs due to the possibility of using a unified heat exchanger for any of the wells and due to the increase in free volume inside the well and the force of vapor rise due to pressure drop, as well as due to well construction taking into account possible curvature of the wellbore and based on the thickness and structure of the formation.

Claims (3)

1. The method of thermal action on the formation, including the study of physical parameters of the formation, determination of the in-situ pressure of the formation and the pressure of formation of cracks in the reservoir, the construction of a horizontally inclined wellbore in the formation, in which a sealed heater filled with heat carrier is placed in the form of a heat exchanger, heating the fluid in the wellbore wells by pumping in the heater preheated on the surface of the coolant, and when the formation is heated in the well, the pressure is not lower the initial reservoir pressure of the formation and not higher than the pressure of formation of cracks in the reservoir due to the selection of gas and liquid from the lower level of the well, characterized in that the directional well is built ascending to the bottom with a slope, excluding sections descending to the bottom and consisting of two parts, the first of which, closest to the wellhead, they are built with an angle not exceeding 30 ° relative to the horizon, and equipped with a heater that does not reach the end of the first part from 1/4 to 3/4 of its length, and the second part at the bottom of the well is built with an angle of 40 -90 ° relative but the horizon. 2. The method of thermal action on the formation according to claim 1, characterized in that in the layered-heterogeneous formations the second part of the trunk is built with a length sufficient to open all productive layers, and with an angle that allows opening these layers. 3. The method of thermal action on the formation according to claim 1, characterized in that in massive formations the second part of the trunk is built with a length sufficient to open from 1/2 to 4/5 of the thickness of the formation, and with an angle relative to the horizon, the larger the larger formation thickness.

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