CN114263451A - Hot dry rock hydraulic fracturing method - Google Patents
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- 238000002347 injection Methods 0.000 claims abstract description 91
- 239000007924 injection Substances 0.000 claims abstract description 91
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- 239000003638 chemical reducing agent Substances 0.000 claims description 32
- 239000007864 aqueous solution Substances 0.000 claims description 26
- 229920002401 polyacrylamide Polymers 0.000 claims description 26
- 239000003795 chemical substances by application Substances 0.000 claims description 25
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- KRHYYFGTRYWZRS-UHFFFAOYSA-N Fluorane Chemical compound F KRHYYFGTRYWZRS-UHFFFAOYSA-N 0.000 claims description 12
- VEXZGXHMUGYJMC-UHFFFAOYSA-N Hydrochloric acid Chemical compound Cl VEXZGXHMUGYJMC-UHFFFAOYSA-N 0.000 claims description 12
- 239000004576 sand Substances 0.000 claims description 7
- 239000002202 Polyethylene glycol Substances 0.000 claims description 6
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- 229920001223 polyethylene glycol Polymers 0.000 claims description 6
- KKEYFWRCBNTPAC-UHFFFAOYSA-L terephthalate(2-) Chemical compound [O-]C(=O)C1=CC=C(C([O-])=O)C=C1 KKEYFWRCBNTPAC-UHFFFAOYSA-L 0.000 claims description 6
- 206010017076 Fracture Diseases 0.000 abstract description 11
- 208000010392 Bone Fractures Diseases 0.000 abstract description 9
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Abstract
The invention discloses a hot dry rock hydraulic fracturing method, which comprises the following steps: firstly, the thickness of the film is 0.5 to 1.5m3The injection displacement is 50-100 m3Pumping the earth acid solution to a target reservoir position, and waiting for corrosion for 50-100 min; then, injecting degradable slick water fracturing fluid with different viscosities into a target reservoir in 5 stages in sequence to achieve the aims of modifying the reservoir in sequence such as corrosion, complex crack forming, temporary plugging and crack expanding, injecting ceramsite into the crack and pushing the ceramsite to the deep part of the crack;the method for hydraulic fracturing of the hot dry rock realizes the formation of a complex microfracture system in the hot dry rock of the stratum for communicating injection and production wells, provides a flow channel for a heat circulation system, effectively improves the longitudinal modification degree and the fracture complexity degree of a reservoir, ensures a fracture seepage channel, further realizes the purpose of improving the heat exchange area of the hot dry rock, and extracts the heat energy stored in the hot dry rock through the circulation of a heat-carrying fluid.
Description
Technical Field
The invention relates to the technical field of hot dry rock development, in particular to a hot dry rock hydraulic fracturing method.
Background
The Hot Dry Rock (HDR) refers to a high-temperature rock mass with no fluid or only a small amount of fluid inside, is a renewable clean energy with huge reserves, and has become an important direction for developing and researching new energy in various countries around the world. The heat energy of the hot dry rock is added in the rock, and the key technology of heat collection is to form a heat exchange system in the hot dry rock. Because the natural permeability of the hot dry rock is extremely low, geothermal energy cannot be economically extracted, and therefore an enhanced geothermal system (EGS for short) must be established for the development of the hot dry rock.
The EGS is to establish high-permeability artificial heat storage in hot dry rock by utilizing a hydraulic fracturing mode, and then to inject a low-temperature fluid medium to replace heat energy in the hot dry rock, so that the most key technology for realizing the EGS is fracturing. The complex microfracture system is formed in the hot dry rock reservoir through fracturing, so that the connectivity of an injection well and a production well is established, a necessary flow channel is provided for a hot dry rock heat energy circulating system, the heat exchange area is increased, the heat energy stored in the hot dry rock is extracted through circulation of a heat-carrying fluid, and the efficient development of the hot dry rock heat energy is realized.
However, due to the characteristics of deep burial depth, high reservoir temperature, low porosity permeability and the like, the hot dry rock has complex lithology and high mechanical strength and heterogeneity, and the problems of high construction pressure, limited fracture extension, high reservoir temperature and the like exist in the fracturing of the hot dry rock. Therefore, although researchers have conducted a series of researches on the construction method of the artificial hot reservoir of the dry hot rock, the researches are basically in the stages of physical model tests and theoretical researches and are not practiced on site. Based on the characteristics and the current fracturing situation of the hot dry rock reservoir, a hot dry rock hydraulic fracturing process technology is urgently needed to be developed so as to realize the efficient development of the hot dry rock heat energy as soon as possible.
Disclosure of Invention
The invention aims to provide a hot dry rock hydraulic fracturing method for effectively fracturing hot dry rock to form a complex microfracture system.
Therefore, the technical scheme of the invention is as follows:
a hydraulic fracturing method for hot dry rock comprises the following specific implementation steps:
s1, 0.5-1.5 m3The injection displacement is 50-100 m3Pumping the earth acid solution to a target reservoir position, and waiting for corrosion for 50-100 min;
the step aims to erode the rock close to the well zone so as to reduce the construction pressure and improve the flow conductivity;
s2, injecting degradable slickwater fracturing fluid with different viscosities into a target reservoir in stages, wherein the method specifically comprises five stages:
stage 1: 1.0 to 2.0m3Injecting low-viscosity degradable slickwater fracturing fluid with the viscosity of 3-4 mPa.s into a target reservoir by the injection displacement of/min, wherein the injection fluid amount is 500-800 m3；
The purpose of this stage is: making complex fractures on a reservoir;
and (2) stage: 1.0 to 2.0m3Injecting medium-viscosity degradable slickwater fracturing fluid mixed with high-temperature resistant temporary plugging agent into a target reservoir stratum by the injection displacement of/min; wherein the medium-viscosity degradable slickwater fracturing fluid mixed with the high-temperature resistant temporary plugging agent is 100-200 m3The medium-viscosity degradable slickwater fracturing fluid with the viscosity of 28-30 mPa.s is mixed with 100-200 kg of high-temperature resistant temporary plugging agent;
the purpose of this stage is: suspending a high-temperature resistant temporary plugging agent in the medium-viscosity degradable slickwater fracturing fluid, and temporarily plugging a larger crack by using the high-temperature resistant temporary plugging agent after entering a reservoir so as to further complicate crack formation;
and (3) stage: at a distance of 2.5 to 3.5m3Injecting low-viscosity degradable slickwater fracturing fluid with the viscosity of 3-4 mPa.s into the target reservoir continuously at the injection discharge volume of/min, wherein the injection fluid volume is 200-300 m3；
The purpose of this stage is: continuously expanding the crack by using the low-viscosity degradable slickwater fracturing fluid;
and (4) stage: at a distance of 3.0 to 3.5m3Injecting high-viscosity degradable slick water fracturing fluid mixed with ceramsite into a target reservoir stratum by the injection discharge amount of/min; wherein the high-viscosity degradable slickwater fracturing fluid mixed with the ceramsite is 2-3 m3The high-viscosity degradable slickwater fracturing fluid with the viscosity of 38-40 mPa.s is mixed with a mixed solution formed by 40/70-mesh ceramsite, and the sand ratio of the mixed solution is 2-3%;
the purpose of this stage is: considering that the high-temperature resistant temporary plugging agent starts to be gradually degraded, suspending the ceramsite in the high-viscosity degradable slickwater fracturing fluid to enable the ceramsite entering the reservoir to enter newly-made cracks in the stage 1-stage 3, preventing the cracks from being closed and ensuring that channels are reserved;
and (5) stage: at a distance of 2.5 to 3.0m3Injecting low-viscosity degradable sliding with the viscosity of 3-4 mPa.s into the target reservoir continuously by the injection displacement of/minThe amount of the injected fluid is 50-100 m3；
The purpose of this stage is: the ceramsite from stage 4 is pushed further into the depth of the formation fractures in the reservoir.
Preferably, in step S1, the earth acid is a mixed solution having 12 wt.% hydrochloric acid and 3 wt.% hydrofluoric acid.
Preferably, in stage 1, stage 3, and stage 5 of step S2, the low viscosity degradable slickwater fracturing fluid is a 0.1 wt.% aqueous solution of a multifunctional friction reducer, which is a polyacrylamide friction reducer.
Preferably, in stage 2 of step S2, the medium viscosity degradable slickwater fracturing fluid is 0.5 wt.% of an aqueous solution of the multifunctional friction reducer, and the multifunctional friction reducer is a polyacrylamide friction reducer; the high-temperature resistant temporary plugging agent is a modified polyethylene glycol terephthalate fiber temporary plugging agent with the particle size of 100 meshes.
Preferably, in stage 4 of step S2, the highly viscous degradable slickwater fracturing fluid is a 0.8 wt.% aqueous solution of a multifunctional friction reducer that is a polyacrylamide based friction reducer.
Compared with the prior art, the dry hot rock hydraulic fracturing method sequentially undergoes earth acid corrosion and low discharge (1.0-2.0 m)3Min) crack expansion and high discharge capacity (2.5-3.0 m)3/min-3.0～3.5m3Min), forming a complex micro-fracture system in hot dry rock of a stratum to communicate an injection well and a production well by a plurality of hydraulic fracturing steps of longitudinal communication, high-viscosity slickwater/temporary plugging composite steering and sand adding, providing a flow channel for a heat circulation system, effectively improving the longitudinal modification degree and the fracture complexity degree of a reservoir, ensuring a fracture seepage channel, further realizing the purpose of improving the heat exchange area of the hot dry rock, and extracting heat energy stored in the hot dry rock through circulation of a heat-carrying fluid.
Detailed Description
The invention will be further illustrated by the following examples of the fracturing technology method applied in connection with the fracturing construction of the XX dry hot rock well group in the east of ji, but the following examples are in no way intended to limit the invention.
In the embodiment, the reservoir temperature of an XX dry hot rock well group in the east of Ji is about 160 ℃, the lithology is modified granite, and the dry hot rock well group has the characteristic of no fluid and meets the requirement of dry hot rock development; the fracturing process is further described below by taking four fracturing units in the XX dry hot rock well group in this east of ji as an example.
Example 1
The applied fracturing technical method is adopted to perform fracturing construction on the X unit of the well group, and the method comprises the following specific steps:
the method comprises the following steps: the earth acid is injected into the position of a target reservoir through a high-pressure pipeline connected with a fracturing pump truck, and the dosage is 50m3The injection displacement is 0.5m3Min, the corrosion time is 50min after injection; wherein, the earth acid is a mixed solution of 12 wt.% hydrochloric acid and 3 wt.% hydrofluoric acid;
step two: injecting degradable slickwater fracturing fluid with different viscosities into a target reservoir, wherein the 5 stages are as follows:
stage 1: at 1.0m3Injecting low-viscosity degradable slickwater fracturing fluid into a target reservoir stratum by using injection displacement per minute, wherein the injection fluid amount is 500m3(ii) a The low-viscosity degradable slickwater fracturing fluid is 0.1 wt.% of aqueous solution of polyacrylamide resistance reducing agents, and the viscosity of the low-viscosity degradable slickwater fracturing fluid is kept within 3-4 mPa.s throughout the whole injection process;
and (2) stage: at 1.0m3Injecting moderate-viscosity degradable slickwater fracturing fluid into a target reservoir stratum by using injection displacement of/min, wherein the injection fluid amount is 100m3(ii) a Wherein, at 100m3100kg of high-temperature resistant temporary plugging agent is mixed in the medium-viscosity degradable slickwater fracturing fluid; the medium-viscosity degradable slickwater fracturing fluid is 0.5 wt.% of polyacrylamide resistance reducing agent aqueous solution, so that the viscosity of the medium-viscosity degradable slickwater fracturing fluid is always kept at 28-30 mPa.s in the whole injection process; the high-temperature resistant temporary plugging agent is a modified polyethylene glycol terephthalate fiber high-temperature resistant temporary plugging agent with the particle size of 100 meshes;
and (3) stage: at 2.5m3Injecting low-viscosity degradable slickwater fracturing fluid into a target reservoir continuously at the injection displacement of/min, wherein the injection fluid amount is 200m3(ii) a Wherein the low-viscosity degradable slickwater fracturing fluid is 0.1 wt.% of aqueous solution of polyacrylamide resistance reducing agentThe viscosity of the slickwater fracturing fluid is kept within 3-4 mPa.s all the time in the whole injection process;
and (4) stage: at 3.0m3Injecting high-viscosity degradable slickwater fracturing fluid into a target reservoir stratum by using injection displacement of per minute, wherein the injection fluid amount is 2m3(ii) a Wherein, at 2m340/70-mesh ceramsite is mixed in the high-viscosity degradable slickwater fracturing fluid to form mixed solution with the sand ratio of 2%; the high-viscosity degradable slickwater fracturing fluid is 0.8 wt.% of polyacrylamide resistance reducing agent aqueous solution, so that the viscosity of the low-viscosity degradable slickwater fracturing fluid is always kept at 38-40 mPa.s in the whole injection process;
and (5) stage: at 2.5m3Injecting low-viscosity degradable slickwater fracturing fluid into a target reservoir continuously at the injection displacement of/min, wherein the injection fluid amount is 50m3(ii) a The low-viscosity degradable slickwater fracturing fluid is 0.1 wt.% of polyacrylamide resistance reducing agent aqueous solution, and the viscosity of the low-viscosity degradable slickwater fracturing fluid is kept within 3-4 mPa.s all the time in the whole injection process.
After the dry and hot rock well group is subjected to fracturing construction by adopting the hydraulic fracturing method of the embodiment, the reservoir modification volume is 41.5 multiplied by 10 as shown by the microseismic fracture monitoring result4And m, which shows that the communication volume between the hot dry rock well groups is effectively increased through hydraulic fracturing.
Example 2
The fracturing technology method is adopted to carry out fracturing construction on the Y unit of the well group, and the method comprises the following specific steps:
the method comprises the following steps: the earth acid is injected into the position of a target reservoir through a high-pressure pipeline connected with a fracturing pump truck, and the dosage is 100m3Injection displacement of 1.0m3Min, the corrosion time is 100min after injection; wherein, the earth acid is a mixed solution of 12 wt.% hydrochloric acid and 3 wt.% hydrofluoric acid;
step two: injecting degradable slickwater fracturing fluid with different viscosities into a target reservoir, wherein the 5 stages are as follows:
stage 1: at 1.5m3Injecting low-viscosity degradable slickwater fracturing fluid into a target reservoir stratum by the injection displacement of/min, wherein the injection fluid amount is 800m3(ii) a Wherein the degradable slickwater fracturing fluid with low viscosity is 01 wt.% of an aqueous solution of a polyacrylamide friction reducer, wherein the viscosity of the low-viscosity degradable slickwater fracturing fluid is always kept at 3-4 mPa.s in the whole injection process;
and (2) stage: at 2.0m3Injecting moderate-viscosity degradable slickwater fracturing fluid into a target reservoir stratum by using injection displacement per minute, wherein the injection fluid amount is 150m3(ii) a Wherein, at 150m3150kg of high-temperature resistant temporary plugging agent is mixed in the medium-viscosity degradable slickwater fracturing fluid; the medium-viscosity degradable slickwater fracturing fluid is 0.5 wt.% of polyacrylamide resistance reducing agent aqueous solution, so that the viscosity of the medium-viscosity degradable slickwater fracturing fluid is always kept at 28-30 mPa.s in the whole injection process; the high-temperature resistant temporary plugging agent is a modified polyethylene glycol terephthalate fiber high-temperature resistant temporary plugging agent with the particle size of 100 meshes;
and (3) stage: at 2.8m3Injecting low-viscosity degradable slickwater fracturing fluid into a target reservoir continuously at the injection discharge volume of/min, wherein the injection fluid volume is 300m3(ii) a The low-viscosity degradable slickwater fracturing fluid is 0.1 wt.% of aqueous solution of polyacrylamide resistance reducing agents, and the viscosity of the low-viscosity degradable slickwater fracturing fluid is kept within 3-4 mPa.s throughout the whole injection process;
and (4) stage: at 3.5m3Injecting high-viscosity degradable slickwater fracturing fluid into a target reservoir stratum by using injection displacement of per minute, wherein the injection fluid amount is 3m3(ii) a Wherein, in 3m340/70-mesh ceramsite is mixed in the high-viscosity degradable slickwater fracturing fluid to form mixed solution with the sand ratio of 2%; the high-viscosity degradable slickwater fracturing fluid is 0.8 wt.% of polyacrylamide resistance reducing agent aqueous solution, so that the viscosity of the low-viscosity degradable slickwater fracturing fluid is always kept at 38-40 mPa.s in the whole injection process;
and (5) stage: at 3m3Injecting low-viscosity degradable slickwater fracturing fluid into the target reservoir continuously at the injection displacement of/min, wherein the injection fluid amount is 80m3(ii) a The low-viscosity degradable slickwater fracturing fluid is 0.1 wt.% of polyacrylamide resistance reducing agent aqueous solution, and the viscosity of the low-viscosity degradable slickwater fracturing fluid is kept within 3-4 mPa.s all the time in the whole injection process.
The hydraulic fracturing method of the embodiment is adopted to carry out fracturing application on the hot dry rock well groupAfter construction, the micro-seismic fracture monitoring result shows that the reservoir reconstruction volume is 55.1 multiplied by 104m3And the communication volume between the hot dry rock well groups is effectively increased through hydraulic fracturing.
Example 3
The applied fracturing technology method is adopted to perform fracturing construction on the Z unit of the well group, and the specific steps are as follows:
the method comprises the following steps: the earth acid is injected into the position of a target reservoir through a high-pressure pipeline connected with a fracturing pump truck, and the dosage is 100m3Injection displacement of 1.0m3Min, the corrosion time is 100min after injection; wherein, the earth acid is a mixed solution of 12 wt.% hydrochloric acid and 3 wt.% hydrofluoric acid;
step two: injecting degradable slickwater fracturing fluid with different viscosities into a target reservoir, wherein the 5 stages are as follows:
stage 1: at 2.0m3Injecting low-viscosity degradable slickwater fracturing fluid into a target reservoir stratum by the injection displacement of/min, wherein the injection fluid amount is 700m3(ii) a The low-viscosity degradable slickwater fracturing fluid is 0.1 wt.% of aqueous solution of polyacrylamide resistance reducing agents, and the viscosity of the low-viscosity degradable slickwater fracturing fluid is kept within 3-4 mPa.s throughout the whole injection process;
and (2) stage: at 1.5m3Injecting moderate-viscosity degradable slickwater fracturing fluid into a target reservoir stratum by using injection displacement per minute, wherein the injection fluid amount is 150m3(ii) a Wherein, at 150m3200kg of high-temperature resistant temporary plugging agent is mixed in the medium-viscosity degradable slickwater fracturing fluid; the medium-viscosity degradable slickwater fracturing fluid is 0.5 wt.% of polyacrylamide resistance reducing agent aqueous solution, so that the viscosity of the medium-viscosity degradable slickwater fracturing fluid is always kept at 28-30 mPa.s in the whole injection process; the high-temperature resistant temporary plugging agent is a modified polyethylene glycol terephthalate fiber high-temperature resistant temporary plugging agent with the particle size of 100 meshes;
and (3) stage: at 3.0m3Injecting low-viscosity degradable slickwater fracturing fluid into a target reservoir continuously at the injection displacement of/min, wherein the injection fluid amount is 250m3(ii) a Wherein the low-viscosity degradable slickwater fracturing fluid is 0.1 wt.% of aqueous solution of polyacrylamide resistance reducing agentThe viscosity of the fracturing fluid is kept to be 3-4 mPa.s all the time in the whole injection process;
and (4) stage: at 3.0m3Injecting high-viscosity degradable slickwater fracturing fluid into a target reservoir stratum by using injection displacement of per minute, wherein the injection fluid amount is 3m3(ii) a Wherein, in 3m340/70-mesh ceramsite is mixed in the high-viscosity degradable slickwater fracturing fluid to form mixed solution with the sand ratio of 3 percent; the high-viscosity degradable slickwater fracturing fluid is 0.8 wt.% of polyacrylamide resistance reducing agent aqueous solution, so that the viscosity of the low-viscosity degradable slickwater fracturing fluid is always kept at 38-40 mPa.s in the whole injection process;
and (5) stage: at 2.8m3Injecting low-viscosity degradable slickwater fracturing fluid into a target reservoir continuously at the injection displacement of/min, wherein the injection fluid amount is 100m3(ii) a The low-viscosity degradable slickwater fracturing fluid is 0.1 wt.% of polyacrylamide resistance reducing agent aqueous solution, and the viscosity of the low-viscosity degradable slickwater fracturing fluid is kept within 3-4 mPa.s all the time in the whole injection process.
After fracturing construction is carried out on the hot dry rock well group by adopting the hydraulic fracturing method of the embodiment, the reservoir modification volume is 53.8 multiplied by 10 as shown by the microseismic fracture monitoring result4m3And the communication volume between the hot dry rock well groups is effectively increased through hydraulic fracturing.
Example 4
The method for fracturing the F unit of the well group comprises the following steps:
the method comprises the following steps: the earth acid is injected into the position of a target reservoir through a high-pressure pipeline connected with a fracturing pump truck, and the dosage is 80m3Injection displacement of 1.2m3Min, waiting for 80min of corrosion after injection; wherein, the earth acid is a mixed solution of 12 wt.% hydrochloric acid and 3 wt.% hydrofluoric acid;
step two: injecting degradable slickwater fracturing fluid with different viscosities into a target reservoir, wherein the 5 stages are as follows:
stage 1: at 1.2m3Injecting low-viscosity degradable slickwater fracturing fluid into a target reservoir stratum by using injection displacement per minute, wherein the injection fluid amount is 500m3(ii) a Wherein the low-viscosity degradable slickwater fracturing fluid is0.1 wt.% of polyacrylamide drag reducer aqueous solution, wherein the viscosity of the low-viscosity degradable slickwater fracturing fluid is always kept at 3-4 mPa.s in the whole injection process;
and (2) stage: at 2.0m3Injecting moderate-viscosity degradable slickwater fracturing fluid into a target reservoir stratum by using injection displacement of/min, wherein the injection fluid amount is 100m3(ii) a Wherein, at 100m3200kg of high-temperature resistant temporary plugging agent is mixed in the medium-viscosity degradable slickwater fracturing fluid; the medium-viscosity degradable slickwater fracturing fluid is 0.5 wt.% of polyacrylamide resistance reducing agent aqueous solution, so that the viscosity of the medium-viscosity degradable slickwater fracturing fluid is always kept at 28-30 mPa.s in the whole injection process; the high-temperature resistant temporary plugging agent is a modified polyethylene glycol terephthalate fiber high-temperature resistant temporary plugging agent with the particle size of 100 meshes;
and (3) stage: at 3.5m3Injecting low-viscosity degradable slickwater fracturing fluid into a target reservoir continuously at the injection discharge volume of/min, wherein the injection fluid volume is 300m3(ii) a The low-viscosity degradable slickwater fracturing fluid is 0.1 wt.% of aqueous solution of polyacrylamide resistance reducing agents, and the viscosity of the low-viscosity degradable slickwater fracturing fluid is kept within 3-4 mPa.s throughout the whole injection process;
and (4) stage: at 3.5m3Injecting high-viscosity degradable slickwater fracturing fluid into a target reservoir stratum by using injection displacement of per minute, wherein the injection fluid amount is 2m3(ii) a Wherein, at 2m340/70-mesh ceramsite is mixed in the high-viscosity degradable slickwater fracturing fluid to form mixed solution with the sand ratio of 3 percent; the high-viscosity degradable slickwater fracturing fluid is 0.8 wt.% of polyacrylamide resistance reducing agent aqueous solution, so that the viscosity of the low-viscosity degradable slickwater fracturing fluid is always kept at 38-40 mPa.s in the whole injection process;
and (5) stage: at 3m3Injecting low-viscosity degradable slickwater fracturing fluid into a target reservoir continuously at the injection displacement of/min, wherein the injection fluid amount is 100m3(ii) a The low-viscosity degradable slickwater fracturing fluid is 0.1 wt.% of polyacrylamide resistance reducing agent aqueous solution, and the viscosity of the low-viscosity degradable slickwater fracturing fluid is kept within 3-4 mPa.s all the time in the whole injection process.
The dry and hot rock well group is fractured by adopting the hydraulic fracturing method of the embodimentAfter construction, the micro-seismic fracture monitoring result shows that the reservoir reconstruction volume is 49.7 multiplied by 104m3And the communication volume between the hot dry rock well groups is effectively increased through hydraulic fracturing.
In addition, after the hot dry rock well group is subjected to fracturing construction, the water inlet temperature of a hot dry rock injection well is 50 ℃, the water outlet temperature of a production well is 110 ℃, and the communication of the hot dry rock injection and production wells is proved to be realized, so that the purpose of heat energy replacement is effectively realized.
Claims (5)
1. The method for hydraulic fracturing of the hot dry rock is characterized by comprising the following steps:
s1, 0.5-1.5 m3The injection displacement is 50-100 m3Pumping the earth acid solution to a target reservoir position, and waiting for corrosion for 50-100 min;
s2, injecting degradable slickwater fracturing fluid with different viscosities into a target reservoir in stages, wherein the method specifically comprises five stages:
stage 1: 1.0 to 2.0m3Injecting low-viscosity degradable slickwater fracturing fluid with the viscosity of 3-4 mPa.s into a target reservoir by the injection displacement of/min, wherein the injection fluid amount is 500-800 m3；
And (2) stage: 1.0 to 2.0m3Injecting medium-viscosity degradable slickwater fracturing fluid mixed with high-temperature resistant temporary plugging agent into a target reservoir stratum by the injection displacement of/min;
wherein the medium-viscosity degradable slickwater fracturing fluid mixed with the high-temperature resistant temporary plugging agent is 100-200 m3The medium-viscosity degradable slickwater fracturing fluid with the viscosity of 28-30 mPa.s is mixed with 100-200 kg of high-temperature resistant temporary plugging agent;
and (3) stage: at a distance of 2.5 to 3.5m3Injecting low-viscosity degradable slickwater fracturing fluid with the viscosity of 3-4 mPa.s into the target reservoir continuously at the injection discharge volume of/min, wherein the injection fluid volume is 200-300 m3；
And (4) stage: at a distance of 3.0 to 3.5m3Injecting high-viscosity degradable slick water fracturing fluid mixed with ceramsite into a target reservoir stratum by the injection discharge amount of/min;
wherein the high-viscosity degradable slickwater fracturing fluid mixed with the ceramsite is 2-3 m3Has a viscosity of 38 to 40mPa.sThe high-viscosity degradable slickwater fracturing fluid is mixed with a mixed solution formed by 40/70-mesh ceramsite, wherein the sand ratio of the mixed solution is 2-3%;
and (5) stage: at a distance of 2.5 to 3.0m3Continuously injecting low-viscosity degradable slickwater fracturing fluid with the viscosity of 3-4 mPa.s into the target reservoir by the injection displacement of/min, wherein the injection fluid amount is 50-100 m3。
2. The hot dry rock hydraulic fracturing method of claim 1, wherein in step S1, the earth acid is a mixed solution having 12 wt.% hydrochloric acid and 3 wt.% hydrofluoric acid.
3. The hot dry rock hydraulic fracturing method of claim 1, wherein in stage 1, stage 3 and stage 5 of step S2, the low viscosity degradable slickwater fracturing fluid is a 0.1 wt.% aqueous solution of a multifunctional friction reducer that is a polyacrylamide based friction reducer.
4. The dry hot rock hydraulic fracturing method of claim 1, wherein in stage 2 of step S2, the medium viscosity degradable slickwater fracturing fluid is a 0.5 wt.% aqueous solution of a multifunctional friction reducer, the multifunctional friction reducer being a polyacrylamide type friction reducer; the high-temperature resistant temporary plugging agent is a modified polyethylene glycol terephthalate fiber high-temperature resistant temporary plugging agent with the particle size of 100 meshes.
5. The dry hot rock hydraulic fracturing method of claim 1, wherein in stage 4 of step S2, the high viscosity degradable slickwater fracturing fluid is a 0.8 wt.% aqueous solution of a multifunctional friction reducer that is a polyacrylamide based friction reducer.
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