CN111608624B - Method for exploiting heavy oil reservoir by utilizing terrestrial heat - Google Patents
Method for exploiting heavy oil reservoir by utilizing terrestrial heat Download PDFInfo
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- CN111608624B CN111608624B CN201910141034.5A CN201910141034A CN111608624B CN 111608624 B CN111608624 B CN 111608624B CN 201910141034 A CN201910141034 A CN 201910141034A CN 111608624 B CN111608624 B CN 111608624B
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/24—Enhanced recovery methods for obtaining hydrocarbons using heat, e.g. steam injection
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/164—Injecting CO2 or carbonated water
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- E—FIXED CONSTRUCTIONS
- E21—EARTH DRILLING; MINING
- E21B—EARTH DRILLING, e.g. DEEP DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/34—Arrangements for separating materials produced by the well
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- Y—GENERAL TAGGING OF NEW TECHNOLOGICAL DEVELOPMENTS; GENERAL TAGGING OF CROSS-SECTIONAL TECHNOLOGIES SPANNING OVER SEVERAL SECTIONS OF THE IPC; TECHNICAL SUBJECTS COVERED BY FORMER USPC CROSS-REFERENCE ART COLLECTIONS [XRACs] AND DIGESTS
- Y02—TECHNOLOGIES OR APPLICATIONS FOR MITIGATION OR ADAPTATION AGAINST CLIMATE CHANGE
- Y02E—REDUCTION OF GREENHOUSE GAS [GHG] EMISSIONS, RELATED TO ENERGY GENERATION, TRANSMISSION OR DISTRIBUTION
- Y02E10/00—Energy generation through renewable energy sources
- Y02E10/10—Geothermal energy
Abstract
The invention discloses a method for exploiting a heavy oil reservoir by utilizing terrestrial heat, which comprises the following steps: step 1, judging whether a geothermal layer of available geothermal resources exists on the upper part or the lower part of a target oil reservoir according to the geological condition of the region where the target oil reservoir is located; step 2, after finding out available geothermal resources, deploying at least two injection wells and at least one production well in a target oil deposit position area, wherein the injection wells are used for injecting injection fluid; and 3, heating the injection fluid by utilizing the geothermal resources of the geothermal layer, and replacing the crude oil in the heavy oil reservoir by the heated injection fluid to realize the exploitation of the heavy oil reservoir. According to the invention, the continuous and stable heat energy supply is ensured by utilizing the geothermal resources of the geothermal layer, the cost of the heavy oil thermal recovery process is reduced, and the recovery ratio of the heavy oil reservoir is greatly improved.
Description
Technical Field
The invention relates to the technical field of oil exploitation, in particular to a method for exploiting a heavy oil reservoir by utilizing terrestrial heat.
Background
The thickened oil is a petroleum resource, has very special physical properties, and is mainly characterized by very viscous and poor fluidity. According to the general domestic industry standard, crude oil with the viscosity of more than 50mPa & s under the condition of an oil layer or the viscosity of more than 100mPa & s under the ground condition after degassing is defined as thick oil. According to oil and gas resource statistical data published worldwide, the heavy oil reserves account for 70% of the global oil reserves, but how to economically and effectively develop heavy oil reservoirs is still a world-level problem, and breakthrough of the heavy oil reservoir development technology can generate great influence on the world energy pattern.
Although the global heavy oil resources have complex and various geological conditions and crude oil properties, the residual heavy oil resources adopt a mining mode of reducing viscosity in the stratum except for heavy oil resources such as oil sand and asphalt which are buried shallowly. The technology for developing viscosity reduction of thick oil stratum mainly comprises steam injection heating viscosity reduction, chemical agent injection viscosity reduction, gas injection viscosity reduction and the like.
The method is characterized in that crude oil or natural gas is used as fuel of a thermal recovery steam generator and is sent into the thermal recovery steam generator to be combusted to produce thermal recovery steam, then the thermal recovery steam is injected into a thick oil reservoir to heat and reduce viscosity to recover the thick oil, and the steam huff-puff or steam drive technology is most commonly applied. However, the steam injection heating viscosity reduction for thick oil production also has a plurality of problems, firstly, the method needs to consume a large amount of fuel and simultaneously discharges a large amount of greenhouse gases, so the cost is high and the waste is large. Secondly, the heat loss is increased in the later period of steam huff and puff, the water saturation around the shaft is increased, the emulsification is serious, the utilization range is limited, and the recovery ratio is low; due to the influence of large oil-water viscosity ratio, heterogeneous reservoir and the like, steam flooding often causes low sweep efficiency and undesirable effect.
The viscosity reducer injecting method is a method for generating a low-viscosity emulsion system by injecting a certain chemical agent to react with the thickened oil. The chemical viscosity reduction method is often applied to the site to treat the viscosity reduction of a wellbore or a near wellbore zone so as to improve the oil recovery effect, and the viscosity reducer is difficult to develop and has higher price, so the viscosity reducer is not used as an oil displacement agent on the site. In addition, the viscosity reducer has poor universality, one viscosity reducer can only be used for viscosity reduction of thick oil with certain property due to the difference of crude oil properties of different oil reservoirs, a chemical viscosity reducer is very sensitive to formation conditions such as temperature, mineralization and the like, emulsion breaking or separation treatment of emulsion is difficult to generate after viscosity reduction, and the economic efficiency of a method for injecting the chemical viscosity reducer is general due to the problems of adsorption loss of the chemical viscosity reducer in the formation and the like. Meanwhile, the injection of the chemical viscosity reducer faces the environmental protection problems such as formation water pollution and the like.
The gas injection viscosity reduction can be divided into two types of injected hydrocarbon gas and non-hydrocarbon gas. The injected hydrocarbon gas includes natural gas, etc., but there exists a gas source in this methodThe problems of insufficiency, high cost, poor safety and the like exist, so that no mine field application is reported. The common non-hydrocarbon gas in the field of thickened oil gas injection viscosity reduction is CO 2 (carbon dioxide), but CO 2 Mixed phase with thick oil is difficult to form, and CO is injected into the thick oil 2 The main mechanism of viscosity reduction is CO 2 Dissolving in crude oil to expand crude oil volume and reduce viscosity, and simultaneously CO 2 After being separated out from the crude oil, the oil is dispersed in the crude oil in the form of small bubbles to form a 'foam oil' seepage state, so that the flowing capacity of the thick oil can be improved; research shows that CO 2 The viscosity-reducing effect increases with increasing temperature, so CO alone is used 2 The viscosity reduction and oil increase effects are not obvious, and CO is injected into steam injected in the steam huff-puff process of the thickened oil 2 The method achieves the effects of increasing energy, assisting drainage and improving the recovery ratio of the heavy oil reservoir.
In recent years, geothermal resources have received increasing attention due to their green and sustainable availability. Geothermal resources can be classified into convection type, conduction type, and hot rock type according to heat source conditions. The convection type geothermal energy brings heat in the deep part of the earth to the earth surface (30-350 ℃) through natural convection of hot water or water vapor in deep cracks; most of conductive geothermal energy is located in sedimentary rock reservoirs, and due to shielding of upper shale cover layers, heat conducted upwards deep in the strata is gathered in the reservoirs to form geothermal energy which mainly comprises deep saline aquifers, oil-gas field geothermal energy, earth pressure type geothermal energy and the like (30-200 ℃); the hot rock type geothermal energy refers to heat stored in high-temperature rock mass or magma, and the hot rock contains no water or a small amount of water, such as dry hot rock (90-650 ℃). The main traditional development mode of geothermal resources is to extract underground hot water or water vapor to the surface through a production well, and then inject cooling water back to the ground after heat is utilized, water is a conventional heat carrying medium for geothermal development, and in recent years, a plurality of students utilize CO 2 The feasibility of developing geothermal resources is researched, and the utilization of CO is proved 2 The development of geothermal resources has wide prospect. In addition, at present, medium-low temperature geothermal resources (lower than 150 ℃) of geothermal resources are directly used for heating and the like, high-temperature geothermal resources are mostly used for generating electricity, and related reports and texts for improving the recovery ratio of heavy oil reservoirs by utilizing the high-temperature geothermal resources are not availableA document is presented.
Disclosure of Invention
The invention aims to provide a method for exploiting heavy oil reservoirs at low cost, which utilizes high-temperature geothermal energy to heat injected fluid and realizes zero emission of greenhouse gases in the implementation process of a heavy oil thermal exploitation technology.
The invention provides a method for exploiting a heavy oil reservoir by utilizing terrestrial heat, which comprises the following steps:
step 1, judging whether a geothermal layer of available geothermal resources exists on the upper part or the lower part of a target oil reservoir according to the geological condition of the region where the target oil reservoir is located;
and 3, heating the injection fluid by utilizing the geothermal resources of the geothermal layer, and replacing the crude oil in the heavy oil reservoir by the heated injection fluid to realize the exploitation of the heavy oil reservoir.
In the method for exploiting the heavy oil reservoir by utilizing the geothermal heat, the geothermal resource of the geothermal layer heats the injected fluid, and the crude oil in the heavy oil reservoir is replaced by the injected fluid and the heated injected fluid, so that the heavy oil reservoir is exploited. The heat of geothermal resources is conducted to the crude oil through the injected fluid, and the viscosity of the crude oil is reduced after the temperature of the crude oil is increased, so that the cost of the thermal recovery process of the heavy oil is reduced, and the recovery ratio of a heavy oil reservoir is improved; further, the method of the invention fully utilizes geothermal resources, thereby saving energy, lowering the exploitation cost of the heavy oil reservoir and being more environment-friendly.
In some embodiments of the invention, the method further comprises the steps of:
and 4, monitoring the temperature of the fluid produced by the geothermal layer, the pressure of the geothermal layer and the content of the injected fluid of the production well in the oil production process, calculating the overall operation cost, and stopping production when the operation cost is equal to or more than the value of produced oil.
In some embodiments of the invention, in step 1, the geothermal layer in which the geothermal resource is located has a temperature above 150 ℃.
In some embodiments of the invention, in step 2, the injection wells comprise at least one first injection well and at least one second injection well, the wellbore of the first injection well is in communication with the geothermal layer, the wellbore of the second injection well is in communication with the target reservoir, and the wellbore of the production well is in communication with the geothermal layer and the target reservoir.
In some embodiments of the invention, step 3 comprises the steps of:
step 3.1, injecting normal-temperature injection fluid into the geothermal layer through the first injection well, and heating the injection fluid by the geothermal layer to obtain high-temperature injection fluid;
3.2, the high-temperature injection fluid enters a well bore of the production well through a communication part of the well bore of the production well and the geothermal layer, and the high-temperature injection fluid is lifted to the ground;
3.3, injecting the high-temperature injection fluid lifted to the ground into a second injection well, wherein the high-temperature injection fluid enters a target oil layer, and the high-temperature injection fluid displaces crude oil in the target oil layer;
and 3.4, lifting the mixed fluid of the high-temperature injection fluid and the crude oil to the ground through the production well, and exploiting the heavy oil reservoir in a replacement mode.
In some embodiments of the invention, step 3 further comprises the steps of:
and 3.5, separating the mixed fluid obtained in the step 3.4, recycling the separated injected fluid, storing and transporting the separated crude oil and natural gas, and treating the separated sewage.
In some embodiments of the invention, in step 2, the distance between the injection well and the production well is 50-250 m.
In some embodiments of the invention, the injection fluid is CO 2 A gas.
When the injection fluid is selected to be CO 2 When the gas is generated, the invention is to heat CO by utilizing high-temperature geothermal energy 2 A method for displacement exploitation of heavy oil reservoirs. The method converts CO 2 Gas is used as heat transfer medium to build injection-production well group to develop geothermal energy so as to produce a large amount of high-temperature CO 2 Gas, reuse of high temperature CO 2 The gas heats the thick oil reservoir and provides heat energy for the thick oil in the shaft in the lifting process, the viscosity of crude oil in the whole exploitation process is reduced, and the purpose of improving the recovery ratio of the thick oil reservoir by utilizing high-temperature geothermal resources is realized. The method changes waste into valuable, and converts CO into 2 Is applied to the development of heavy oil reservoirs and has the function of large-scale CO sequestration 2 For low cost, enhanced recovery of heavy oil reservoirs and enhanced CO 2 The economic feasibility of the buried project provides an important technical reference.
Drawings
The invention will be described in more detail hereinafter on the basis of embodiments and with reference to the accompanying drawings. Wherein:
fig. 1 is a schematic diagram of an injection and production system consisting of an injection well and a production well in a method of an embodiment of the invention for developing a heavy oil reservoir.
In the drawings, like parts are provided with like reference numerals. The drawings are not to scale.
Detailed Description
The invention will be further explained with reference to the drawings. The same unit symbol in the invention represents the same unit, wherein t/d represents ton/day, m is length unit meter, DEG C is temperature unit centigrade,
the invention provides a method for exploiting a heavy oil reservoir by utilizing terrestrial heat, which comprises the following steps:
step 1, judging whether a geothermal layer of available geothermal resources exists on the upper part or the lower part of a target oil layer according to the geological condition of the region where the target oil reservoir is located, wherein the temperature of the geothermal layer is preferably above 150 ℃.
And 2, after finding out available geothermal resources, deploying at least two injection wells and at least one production well in the target oil deposit position area, wherein the injection wells are used for injecting injection fluid, and the well spacing between the injection wells and the production well is preferably 50-250 m.
Further, the injection wells include at least a first injection well and a second injection well.
The shaft of the first injection well is only communicated with the geothermal layer, is not limited to a well type, can be a vertical well or a horizontal well, and all fluid injected by the first injection well enters the geothermal layer; the first injection well can carry out injection increasing measures such as fracturing, acidizing and the like before injecting fluid according to the physical conditions of the geothermal layer, such as porosity and permeability; the wellhead of the first injection well may be connected by a pipeline to the outlet end of a high pressure injection pump, the inlet end of which is connected to an injection fluid reservoir means.
The second injection well is only communicated with a target oil layer, is not limited to a well type, can be a vertical well or a horizontal well, and all fluid injected by the second injection well enters the target oil layer; the well mouth of the second injection well is connected with a high-pressure injection pump, and hot fluid after filtration treatment is injected into the reservoir through an oil pipe.
The production well can be a segmented perforation vertical well or a multi-branch horizontal well, and no matter which well type is adopted, a well shaft of the production well needs to be communicated with the geothermal layer and the target oil layer; the production well is connected with a flow dividing valve at the well mouth, an outlet of the flow dividing valve connected with an oil pipe is connected with a circulating and filtering device on the ground through a pipeline, the circulating and filtering device on the ground is connected with a high-pressure injection pump on the ground through a pipeline, and an outlet of the flow dividing valve connected with the shaft annulus is connected with a three-phase separator through a pipeline.
And 3, heating the injection fluid by utilizing geothermal resources of the geothermal layer, and replacing the crude oil in the heavy oil reservoir by the heated injection fluid to realize the exploitation of the heavy oil reservoir.
The whole production process of utilizing geothermal energy to heat injection fluid to replace and recover heavy oil reservoir is characterized by that firstly, utilizing geothermal energy to heat injection fluid, firstly, using high-pressure injection pump to inject the ground normal-temperature injection fluid capable of collecting and carrying heat energy in ground fluid storage device into first injection well, the injected normal-temperature injection fluid can be fed into geothermal layer by means of the portion of wellbore of first injection well communicated with geothermal layer, the injection fluid can be flowed in geothermal layer, and can absorb and carry away the heat energy in geothermal layer and can be converted into high-temperature injection fluid, under the action of pressure difference between injection wells and extraction wells these high-temperature injection fluids can be fed into the wellbore of production well by means of wellbore of production well and portion communicated with geothermal layer, and can be lifted to ground by means of production well oil pipe, then these high-temperature injection fluids can be passed through circulating and filtering device connected by means of heat-insulating pipeline, and can be injected into second injection well by means of high-pressure injection pump of wellhead of second injection well, and the high-temperature fluid enters the target oil layer along the oil pipe of the second injection well to the part of the well bore communicated with the target oil layer. And then the high-temperature injection fluid replaces and produces the process of the thick oil, because the temperature of the high-temperature fluid is higher than the temperature of the target oil layer, the high-temperature injection fluid exchanges heat with the fluid in the target oil layer after entering the target oil layer, and the crude oil in the target oil layer is heated. The viscosity of the crude oil is reduced after the temperature of the crude oil is increased, the crude oil is displaced under the action of pressure difference between the injection wells and the production wells to flow in a target oil layer, and finally the crude oil enters a well bore of the production well from a part of the well bore of the production well, which is communicated with the target oil layer. And finally, the produced mixed fluid is lifted to the ground along the annular space of the oil pipe of the production well, and in the process, because the high-temperature fluid which is just produced from the geothermal layer is arranged in the oil pipe on the inner side of the production well, the mixed fluid produced from a target oil layer can be heated for the second time, the mixed fluid is favorable for lifting the thick oil to the ground, and the mixed fluid reaching the wellhead is conveyed to the separation device along a pipeline through the flow dividing valve. The injected fluid obtained by separation through the separation device is recycled after passing through a storage tank of the injected fluid, the separated crude oil and natural gas are stored and transported, and sewage is treated.
In order to further reduce the production cost and make the production more controllable, step 4 may be provided, monitoring the temperature of the produced fluid of the geothermal layer, the geothermal layer pressure, the content of the injected fluid of the production well in the oil production process, calculating the overall operation cost, and stopping production when the operation cost is equal to or greater than the value of the produced oil.
Further, the injection fluid may be selected from CO 2 A gas. Injection fluid selection of CO 2 When the gas is generated, the invention is to heat CO by utilizing high-temperature geothermal energy 2 A method for displacement exploitation of heavy oil reservoirs. The method converts CO 2 Gas is used as heat transfer medium to build injection-production well group to develop geothermal energy so as to produce a large amount of high-temperature CO 2 Gas, reuse of high temperature CO 2 The gas heats the thick oil reservoir and provides heat energy for the thick oil in the shaft in the lifting process, the viscosity of crude oil in the whole exploitation process is reduced, and the purpose of improving the recovery ratio of the thick oil reservoir by utilizing high-temperature geothermal resources is realized. The method changes waste into valuable, and converts CO into 2 Is applied to the development of heavy oil reservoirs and has the function of large-scale CO sequestration 2 For low cost, enhanced recovery of heavy oil reservoirs and enhanced CO 2 The economic feasibility of buried projects provides important technical references.
As shown in fig. 1, a schematic diagram of the heavy oil reservoir development for the injection and production system consisting of injection wells and production wells in the method of the present embodiment is shown.
In the embodiment, the burial depth of the selected heavy oil reservoir is 1200-1312 m, the initial oil layer temperature is 55.2 ℃, geothermal resources available in the range of a target reservoir distribution area are located 3000m below the target oil layer, and the geothermal layer temperature is 200-220 ℃.
As shown in figure 1, a first injection well 14, a second injection well 12 and a production well 13 are deployed in a target reservoir position area, the well distance between the first injection well 14 and the production well 13 is 100m, and the well distance between the second injection well 12 and the production well 13 is 150 m.
In this embodiment, the first injection well 14 is a vertical well, and the wellbore perforation section is located in the geothermal layer 1, and the first injection well 14 is in communication with only the geothermal layer 1, so that CO injected into the first injection well 14 2 All enter the geothermal layer 1; the first injection well 14 in this embodiment is completed using fracturing, the fracturing interval being coincident with the perforated interval; the well head of the first injection well 14 is connected with the outlet end of a first high-pressure injection pump 4 through a first flow dividing valve 3 and a pipeline, and the inlet end of the first high-pressure injection pump 4 is connected with CO through a pipeline 2 The reservoir tank 7 is connected. In this embodiment, the second injection well 12 is a vertical well, and the perforated section of the well bore is located in the target oil layer, and the second injection well 12 is communicated with the target oil layer 2 only, so that the second injection well 12 injects CO 2 All the oil enters a target oil layer 2; the well mouth of the second injection well 12 is connected with a second high-pressure injection pump 15, and high-temperature CO after filtration treatment is injected into the target oil layer 2 through an oil pipe 2 A gas. The production well 13 is a segmented perforation concentric tube vertical well, and the lower part 10 of the well shaft of the production well 13 is connected with the groundThe thermal layers 1 are communicated, perforation fracturing is adopted for well completion, and the thermal layers are used for producing CO heated by the thermal layers 1 2 The upper part 9 of a well shaft of the gas production well 13 is communicated with the target oil layer 2, and the well is completed by perforation and is used for producing three-phase mixed fluid of oil, gas and water in the target oil layer 2; the wellhead of the production well 13 is connected with a second flow dividing valve 16, and the second flow dividing valve 16 is used for dividing CO produced by the inner oil pipe of the production well 13 2 The gas passes through the pipeline and the circulation and filtration device 5 on the ground, the circulation and filtration device 5 on the ground is connected with the second high-pressure injection pump 15 on the ground through the pipeline, the second shunt valve 16 connects the three-phase mixed fluid of oil, gas and water produced by the outer side oil pipe and the inner side oil pipe annulus of the production well 13 with the three-phase separator 6 through the pipeline, and part of CO can be separated through the three-phase separator 6 2 After separation, CO is returned via a line 2 The storage tank 7 is recycled, the separated crude oil and natural gas are stored and transported, and sewage is treated.
As shown in fig. 1, the first injection well 14 injects normal temperature CO into the geothermal layer 1 at the beginning 2 Gas is injected at a rate of 100t/d and the entire production well 13 is depressurized, when the presence of CO in the lower part 10 of the well is detected 2 When producing, the part of produced CO is started 2 Injecting the CO into the well bore of the second injection well 12 through the filtering device 5 by a second high-pressure injection pump 15 at a speed corresponding to the CO production of the production well 13 2 Is constant in speed, high temperature CO 2 After entering the target oil layer 2, the oil spontaneously reacts with the thickened oil in the target oil layer 2 in a physical and chemical way, and simultaneously carries heat to the target oil layer to heat the thickened oil fluid in the target oil layer; the initial production of the upper wellbore portion 9 of the production well 13 is 40t/d and the later stages are based on the injection of CO 2 Can be adjusted.
Monitoring temperature of fluid produced by geothermal layer, geothermal layer pressure and CO in production process of production well 2 Content, measured as oil price $ 60/barrel, volume of crude oil produced and CO produced from the target block well 2 When the volume ratio of (a) to (b) is less than 0.2, the entire production is stopped.
While the invention has been described with reference to a preferred embodiment, various modifications may be made and equivalents may be substituted for elements thereof without departing from the scope of the invention. In particular, the technical features mentioned in the embodiments can be combined in any way as long as there is no structural conflict. It is intended that the invention not be limited to the particular embodiments disclosed, but that the invention will include all embodiments falling within the scope of the appended claims.
Claims (5)
1. A method for exploiting a heavy oil reservoir by utilizing geothermal heat comprises the following steps:
step 1, judging whether a geothermal layer of available geothermal resources exists on the upper part or the lower part of a target oil layer according to the geological condition of a region where the target oil reservoir is located;
step 2, after finding out available geothermal resources, deploying at least two injection wells and at least one production well in a target oil deposit position area, wherein the injection wells are used for injecting injection fluid;
step 3, heating the injection fluid by utilizing geothermal resources of the geothermal layer, and replacing crude oil in the heavy oil reservoir by the heated injection fluid to realize the exploitation of the heavy oil reservoir;
step 4, monitoring the temperature of the fluid produced by the geothermal layer, the pressure of the geothermal layer and the content of the injected fluid in the production well in the oil production process, calculating the overall operation cost, and stopping production when the operation cost is equal to or more than the value of produced oil;
in step 2, the injection wells comprise at least one first injection well and at least one second injection well, the wellbore of the first injection well is communicated with the geothermal layer, the wellbore of the second injection well is communicated with the target oil layer, and the wellbore of the production well is communicated with the geothermal layer and the target oil layer;
the step 3 comprises the following steps:
step 3.1, injecting normal-temperature injection fluid into the geothermal layer through the first injection well, and heating the injection fluid by the geothermal layer to obtain high-temperature injection fluid;
3.2, the high-temperature injection fluid enters a well bore of the production well through a communication part of the well bore of the production well and the geothermal layer, and the high-temperature injection fluid is lifted to the ground;
3.3, injecting the high-temperature injection fluid lifted to the ground into a second injection well, wherein the high-temperature injection fluid enters a target oil layer, and the high-temperature injection fluid displaces crude oil in the target oil layer;
3.4, lifting the mixed fluid of the high-temperature injection fluid and the crude oil to the ground through a production well to realize the exploitation of the heavy oil reservoir in a replacement mode;
the production well comprises an inner oil pipe and an outer oil pipe, the inner oil pipe is communicated with the geothermal layer, and an annulus between the outer oil pipe and the inner oil pipe is communicated with the target oil layer;
in step 3.4, the inner oil pipe of the production well contains the high-temperature fluid which is just produced from the geothermal layer, and the mixed fluid of the target oil layer produced from the annular space between the outer oil pipe and the inner oil pipe can be heated secondarily.
2. The method of claim 1, wherein in step 1, the geothermal resource is located in a geothermal layer having a temperature of 150 ℃ or higher.
3. The method of claim 1, wherein step 3 further comprises the steps of:
and 3.5, separating the mixed fluid obtained in the step 3.4, recycling the separated injected fluid, storing and transporting the separated crude oil and natural gas, and treating the separated sewage.
4. The method according to claim 1, wherein in step 2, the distance between the injection well and the production well is 50-250 m.
5. A process according to any one of claims 1 to 4, wherein the injection fluid is CO 2 A gas.
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