Fractured gneiss reservoir fracture network acid fracturing reconstruction method, device, medium and equipment

Abstract

The present application relates to a kind of fractured gneiss reservoir fracture network acid fracturing reconstruction method, device, medium and equipment, method includes the following steps: according to the geological characteristics of fractured gneiss reservoir, preliminary determination main body acid liquor and additive, different main body acid liquor system is formed, through experiment, finally determine main body acid liquor system;Based on the geology and fluid characteristics of oil and gas reservoir, acid fracturing fracture parameter is optimized;Using full three-dimensional fracturing model, combine acid fracturing fracture parameter, the reaction kinetics parameters of main body acid liquor system and acid fracturing pipe column, acid fracturing construction parameter is optimized;The pressure required for natural fracture under the artificial fracture deflection of temporary plugging is calculated;According to the temporary plugging position and the control field distribution calculation, determine final temporary plugging agent;The temporary plugging strength gradient of temporary plugging agent is obtained by testing, according to the pressure required for natural fracture under the artificial fracture deflection of temporary plugging calculation temporary plugging agent dosage;Main body acid liquor system and the determined dosage of temporary plugging agent are injected into fractured gneiss reservoir, and form fracture network acid fracturing.

Description

TECHNICAL FIELD

[0001] The present application relates to a method, device, medium and equipment for fracture network acid fracturing reconstruction of fractured gneiss reservoir, and belongs to the field of acid fracturing stimulation in oil and gas field development. BACKGROUND

[0002] As one of the key technologies for oil and gas reservoir stimulation, acid fracturing has been widely used in major oilfields around the world, especially in carbonate reservoirs, but there are few reports on its application in gneiss reservoirs. The reason is that acid fracturing in gneiss reservoirs is prone to secondary precipitation, which reduces the acid-etched fracture conductivity or damages the matrix permeability. Natural fractures in fractured reservoirs are not only oil and gas storage space, but also oil and gas flow channels. It is of great significance to activate, connect and make good use of natural fractures to improve the productivity of production wells. With the development of oil and gas exploration and development towards deep layers, the vertical stress is generally greater than the horizontal stress, and the artificial fractures produced by acid fracturing will extend along the direction of the maximum horizontal principal stress. When the strike of natural fractures is parallel to the direction of the maximum horizontal principal stress, the artificial fractures will remain parallel to the natural fractures, and the two cannot be connected. When the intersection angle between natural fractures and artificial fractures is too large, the artificial fractures will directly pass through the natural fractures, and the natural fractures will not be activated, so the natural fractures cannot be fully utilized. In addition, there is a risk of sand production in gneiss reservoirs, and some wells use sand control completion, such as screen pipe completion, quartz sand or ceramic proppant, chemical particles or fiber temporary plugging agent, which is difficult to pass through. SUMMARY

[0003] To solve the above technical problems, the present application provides a method, device, medium and equipment for fracture network acid fracturing reconstruction of fractured gneiss reservoir, which can effectively avoid the damage to fractures and reservoir matrix caused by gneiss acid fracturing, activate and connect cemented or uncemented natural fractures to form a fracture network, and overcome the problems caused by sand control completion tools.

[0004] To achieve the above purpose, the present application adopts the following technical solutions:

[0005] A method for fracture network acid fracturing reconstruction of fractured gneiss reservoir, comprising the following steps:

[0006] S1. According to the geological characteristics of the fractured gneiss reservoir, the main body of the acid and the additives are preliminarily determined, different main body acid systems are formed, and core displacement experiments and rock plate conductivity tests are used to finally determine the main body acid system;

[0007] S2. Based on the geology and fluid characteristics of the oil and gas reservoir, the seepage mechanics method is used to optimize the acid fracturing parameters; the full three-dimensional fracturing model is used to combine the acid fracturing parameters, the reaction kinetics parameters of the main body acid system finally determined in the step S1 and the acid fracturing string to optimize the acid fracturing construction parameters;

[0008] S3, combine the acid fracturing parameters to calculate the pressure required for the artificial fracture to divert to the natural fracture under the temporary plugging;

[0009] S4, according to the sand control completion and acid fracturing parameters, initially select the type of temporary plugging agent, and determine the final temporary plugging agent according to the temporary plugging position and field distribution calculation;

[0010] S5, test the temporary plugging strength gradient of the temporary plugging agent, and calculate the dosage of the temporary plugging agent according to the pressure required for the artificial fracture to divert to the natural fracture under the temporary plugging;

[0011] S6, inject the main acid liquid system and the determined dosage of the temporary plugging agent into the fractured gneiss reservoir to realize the diversion of the artificial fracture to the natural fracture, activate and connect the cemented or non-cemented natural fractures, and form a fracture network acid fracturing.

[0012] The fracture network acid fracturing reconstruction method of the fractured gneiss reservoir, preferably, in the step S1, the geological characteristics of the fractured gneiss reservoir include reservoir burial depth, temperature, oil and gas and geological characteristics, rock mineral composition and pipe column corrosion.

[0013] The fracture network acid fracturing reconstruction method of the fractured gneiss reservoir, preferably, in the step S1, the main acid liquid includes any one of retarded acid liquid, conventional mud acid liquid, alcohol-based acid liquid or water-based acid liquid; the additive includes any one or more of resistance reducing agent, surfactant, iron ion stabilizer, clay stabilizer or corrosion inhibitor.

[0014] The fracture network acid fracturing reconstruction method of the fractured gneiss reservoir, preferably, in the step S2, the acid fracturing crack parameters include acid etching crack length and acid etching crack conductivity; the main acid liquid system reaction kinetics parameters include reaction order, reaction speed constant, reaction activation energy, frequency factor and H + mass transfer coefficient; the acid fracturing parameters include acid liquid dosage and displacement.

[0015] The fracture network acid fracturing reconstruction method of the fractured gneiss reservoir, preferably, in the step S3, the pressure P div required for the artificial fracture to divert to the natural fracture under the temporary plugging is calculated, and the specific calculation formula is:

[0016] P div = σ NF + σ H - σ h - σ ind (1)

[0017] In the formula: σ NF is the shear strength or closure stress of the natural fracture; σ H is the horizontal maximum principal stress; σ h is the horizontal minimum principal stress; σ ind is the induced stress.

[0018] Preferably, in the step S4, the field distribution includes wellbore-fracture temperature field distribution and fracture pH field distribution, and the wellbore-fracture temperature field distribution is calculated as follows:

[0019]

[0020] wherein, ρ f is fluid density; C f is fluid specific heat capacity; v f is fluid flow rate; T f is fluid temperature; z is axial depth along the wellbore; t is time; r1 is pipe diameter; λ c is comprehensive heat transfer coefficient; T r is formation temperature; q a is reaction heat; λ f is fluid thermal conductivity; x is length along the fracture length direction; y is length in the vertical wall direction; α is wall heat transfer coefficient; w is fracture width;

[0021] The fracture pH field distribution is calculated as follows:

[0022]

[0023] wherein, φ is porosity; C H + is hydrogen ion molar concentration; t is time; ▽ is gradient operator (total differential in each direction in space, used to represent gradient); U is flow rate; C e,H + is hydrogen ion effective diffusion coefficient; R H + is surface reaction rate; α v is specific surface area.

[0024] Preferably, in the step S5, the temporary plugging agent dosage calculation formula is as follows:

[0025]

[0026] wherein, Q div is temporary plugging agent dosage; ζ is safety factor; h is fracture height; P bre is temporary plugging strength gradient.

[0027] The second aspect of the present application provides a fractured gneiss reservoir fracture network acid fracturing reconstruction device, comprising:

[0028] The first processing unit is used for preliminarily determining a main body acid liquid and an additive according to the geological characteristics of the fractured gneiss reservoir, composing different main body acid liquid systems, and finally determining the main body acid liquid system by using core displacement experiments and rock plate conductivity capacity test experiments;

[0029] The second processing unit is used for optimizing acid fracturing crack parameters by using a percolation mechanics method based on the geological and fluid characteristics of the oil and gas reservoir, optimizing acid fracturing construction parameters by using a full three-dimensional fracturing model in combination with the acid fracturing crack parameters, the reaction kinetics parameters of the main body acid liquid system finally determined in the step S1 and the acid fracturing string;

[0030] The third processing unit is used for calculating the pressure required for diverting artificial cracks to natural cracks under temporary plugging in combination with the acid fracturing construction parameters;

[0031] The fourth processing unit is used for initially selecting a temporary plugging agent type according to the sand control completion and acid fracturing construction parameters, and determining the final temporary plugging agent according to temporary plugging positions and field distribution calculation;

[0032] The fifth processing unit is used for injecting the main body acid liquid system and the determined amount of temporary plugging agent into the fractured gneiss reservoir, realizing the diversion of artificial cracks to natural cracks under temporary plugging, activating and connecting cemented or non-cemented natural cracks, and forming a fracture network acid fracturing.

[0033] The third aspect of the present application provides a computer readable storage medium, which stores a computer program, and the computer program is executed by a processor to realize the steps of the fractured gneiss reservoir fracture network acid fracturing reconstruction method.

[0034] The fourth aspect of the present application provides a computer device, which includes a memory, a processor and a computer program stored on the memory and executable on the processor, and the processor realizes the steps of the fractured gneiss reservoir fracture network acid fracturing reconstruction method when executing the computer program.

[0035] The present application has the following advantages due to the above technical solutions:

[0036] The reconstruction method of the present application can effectively avoid the damage of gneiss acid fracturing to cracks and reservoir matrix, can activate and connect cemented or non-cemented natural cracks to form a fracture network, and can overcome the problems caused by sand control completion tools. BRIEF DESCRIPTION OF DRAWINGS

[0037] Figure 1 The acid etching crack length and productivity ratio curve provided by an embodiment of the present application is provided;

[0038] Figure 2 The acid etching crack conductivity capacity and productivity ratio curve provided by the embodiment of the present application is provided;

[0039] Figure 3A wellbore temperature curve diagram provided for this embodiment of the present application;

[0040] Figure 4 A fracture temperature curve diagram provided for this embodiment of the present application. DETAILED DESCRIPTION

[0041] In order to make the objects, technical solutions and advantages of the present application clearer, the technical solutions in the present application are described clearly and completely below, obviously, the described embodiments are part of the embodiments of the present application, rather than all the embodiments. Based on the embodiments in the present application, all other embodiments obtained by those skilled in the art without creative labor fall within the protection scope of the present application.

[0042] The present application aims at the fact that in the existing gneiss reservoir, the artificial fractures are parallel to the natural fractures and cannot be connected with each other, when the intersection angle between the natural fractures and the artificial fractures is too large, the artificial fractures will directly pass through the natural fractures, the natural fractures are not activated, and the natural fractures cannot be fully utilized. In addition, the gneiss reservoir has the risk of sand production, some wells use sand control completion, for example, screen pipe completion, quartz sand or ceramic proppant, chemical particles or fiber temporary plugging agent, and a fracture gneiss reservoir network acid fracturing reconstruction method is proposed, which can effectively avoid the damage of gneiss acid fracturing to the fractures and reservoir matrix, can activate and connect the cemented or uncemented natural fractures to form a network, and overcome the problems brought by sand control completion tools.

[0043] The fracture gneiss reservoir network acid fracturing reconstruction method proposed in the present application has the following specific technical solutions.

[0044] Step S1: according to the reservoir burial depth, temperature, oil and gas and geological characteristics, rock mineral composition, pipe column corrosion, the main body of acid and additive is preliminarily determined; according to the core displacement experiment and rock plate conductivity test experiment, the main body of acid system is finally determined.

[0045] Specifically, if the reservoir temperature is high (generally greater than 120℃), the main acid should be selected as a retarded acid, and the commonly used retarded acids include multi-hydrogen acid, fluoroboric acid, and self-generating mud acid, otherwise, a conventional mud acid can be selected; if it is a gas reservoir and the pore throat is small, liquid lock is prone to occur, so the acid should be selected as alcohol-based, otherwise, it is water-based; if the well is deep or the reservoir fracture pressure is large, in order to reduce the construction injection pressure, a resistance reducing agent needs to be added; if the acid emulsifies with the reservoir crude oil or forms acid residue with colloid asphalt, reservoir particles migrate, or the flowback after the assisted pressure, a surfactant needs to be added; if the mineral components contain a large amount of iron compounds, an iron ion stabilizer needs to be added; if the reservoir is acid-sensitive or water-sensitive, a clay stabilizer needs to be added; if the corrosion of the acid to the pipe string exceeds the requirements of SY / T5405 standard, an inhibitor needs to be added; according to the main acid and the additives preliminarily determined, different main acid systems are formed, and the core displacement experiment is first carried out to optimize the main acid system which will not cause damage to the core permeability; the main acid system is optimized by the core displacement experiment, and then the rock plate conductivity test experiment is carried out to select the main acid system corresponding to the highest conductivity.

[0046] Step S2: Based on the oil and gas reservoir geology and fluid characteristics, the acid fracturing parameters are optimized and designed using the percolation mechanics method (known method), including acid etching fracture length L ac and acid etching fracture conductivity D ac ; using the full three-dimensional fracturing model (known model), the acid fracturing parameters, the main acid system optimized in step S1, the reaction kinetics parameters of the main acid system, and the acid fracturing string are combined to optimize and design the acid fracturing construction parameters, including acid liquid dosage Q ac and displacement q ac .

[0047] Specifically, the acid fracturing parameters are optimized and designed using the mprod module of Meyer software, and then the MFrac module is used to optimize and design the acid fracturing construction parameters.

[0048] Step S3: The pressure P div required for the artificial fracture to divert to the natural fracture under temporary plugging is calculated in combination with the acid fracturing construction parameters, and the specific calculation formula is:

[0049] P div = σ NF + σ H - σ h - σ ind (1)

[0050] In the formula, P div is the pressure, MPa; σ NF is the shear strength or closure stress of the natural fracture, MPa; σ H is the horizontal maximum principal stress, MPa; σ h is the horizontal minimum principal stress, MPa; and σ indStress induced, MPa. Wherein, σ ind The calculation can use displacement discontinuity method or extended finite element method.

[0051] Step S4: According to the sand control completion and acid fracturing parameters, the type of temporary plugging agent is initially selected; according to the temporary plugging position and control field calculation, the final temporary plugging agent is determined.

[0052] Specifically, the solid type temporary plugging agent is difficult to pass through the sand control completion tool, the solid temporary plugging agent such as chemical particles and fibers which need to be carried by fluid is excluded, and only the pure liquid type temporary plugging agent can be selected; according to the control factors of the temporary plugging agent liquid (injection)-solid (temporary plugging)-liquid (flowback) transition process, the control field distribution (control field distribution includes: wellbore-fracture temperature field distribution and fracture internal pH field distribution) is calculated; according to the control field distribution, it is judged whether the temporary plugging agent can reach the predetermined temporary plugging position, so as to determine the final temporary plugging agent.

[0053] The wellbore-fracture temperature field distribution can be calculated by the following formula:

[0054]

[0055] In the formula, ρ f Fluid density, kg / m 3 ; C f Fluid specific heat capacity, J / (kg·℃); v f Fluid flow rate, m / s; T f Fluid temperature, ℃; z-Along the axial depth of the wellbore, m; t-Time, s; r1-Tube diameter, m; λ c Overall heat transfer coefficient, J / (m 2 ·℃·s); T r Formation temperature, ℃; q a Reaction heat, J / (m 2 ·s); λ f Fluid thermal conductivity, J / (m·℃·s); x-Along the length of the crack direction, m; y-Vertical wall direction length, m; α-Wall heat transfer coefficient, J / (m·℃·s); w-Crack width, m.

[0056] The fracture internal pH field distribution can be calculated by the following formula:

[0057]

[0058] In the formula, φ-Porosity, dimensionless; C H + Hydrogen ion molar concentration, mol / L; t-Time, s; ▽ is a gradient operator (total differential in each direction in space, used to represent the gradient); U-Flow rate, m / s; C e,H +Hydrogen ion effective diffusion coefficient, m 2 / s; R H + Surface reaction rate, mol / (m 2 ·s); a v Specific surface area, m -1 .

[0059] Step S5: test the temporary plugging strength gradient P bre of the temporary plugging agent, and design the temporary plugging agent dosage Q div .

[0060] Specifically, the pressure required to break through the temporary plugging layer under different temporary plugging lengths is measured using a temporary plugging strength tester, and the temporary plugging strength gradient is fitted; combined with the result calculated in step S3, the temporary plugging agent dosage calculation formula is:

[0061]

[0062] In the formula: Q div Temporary plugging agent dosage, m 3 ; z - safety factor, dimensionless; h - slot height, m; P bre Temporary plugging strength gradient, MPa / m.

[0063] Step S6, inject the main acid liquid system and the determined amount of temporary plugging agent into the fractured gneiss reservoir to realize the temporary plugging of artificial fractures to natural fractures, activate and connect the cemented or uncemented natural fractures, and form a fracture network acid fracturing.

[0064] The technical solutions of the present application will be described in detail below in combination with specific application examples.

[0065] Taking an offshore oilfield X condensate gas reservoir as an example.

[0066] Step S1: preliminarily determine the main acid liquid and additives according to the reservoir burial depth, temperature, oil and gas and geological characteristics, rock mineral composition, and pipe column corrosion; finally determine the main acid liquid system according to the core displacement experiment and rock plate conductivity capacity test experiment.

[0067] Specifically, the reservoir temperature is 183℃, the primary acid fluid is selected as a retarding acid, i.e., a multi-hydrogen acid, a fluoroboric acid, and a self-generating mud acid; the gas reservoir is a condensate gas reservoir, the average porosity is 3.2%, the average permeability is 0.1mD, there is edge water, the pore throat is small, and liquid lock is extremely prone to occur, the acid fluid is selected as an alcohol-based; the well is a deviated well, the well is deep (6538m), the fracture pressure is high (95MPa), and a resistance-reducing agent is added; in order to reduce the damage of the liquid to the reservoir and facilitate post-fracturing flowback, a surfactant (i.e., a flowback aid) is added; the reservoir is acid-sensitive and water-sensitive, and a clay stabilizer is added; the temperature is high, the wellbore is long, and the corrosion of the acid fluid to the pipe string without a corrosion inhibitor exceeds the requirements of the SY / T5405 standard, and a corrosion inhibitor is added; the resistance-reducing agent, the flowback aid, the clay stabilizer, and the corrosion inhibitor are market products. According to the primary selected main acid fluid and the additives, different main acid fluid systems are formed, and through core displacement experiments, the experimental results show that the multi-hydrogen acid system, the fluoroboric acid system, and the self-generating mud acid system all improve the core permeability, and the improvements are 12%, 8%, and 2%, respectively, and the three main acid fluid systems will not cause damage to the core permeability; the three main acid fluid systems are subjected to rock plate conductivity testing experiments, and the experimental results show that under a closure pressure of 20MPa, the etched fracture conductivity of the multi-hydrogen acid system, the fluoroboric acid system, and the self-generating mud acid system is 5.3, 3.4, and 1.7μm 2 ·cm, respectively, and the multi-hydrogen acid system with the highest conductivity is selected as the main acid fluid system.

[0068] Step S2: based on the oil and gas reservoir geology and fluid characteristics, using the percolation mechanics method, the acid fracturing fracture parameters are optimized and designed, including the acid etching fracture length L ac and the acid etching fracture conductivity D ac ; using a full three-dimensional fracturing model, the acid fracturing fracture parameters, the main acid fluid system reaction kinetics parameters selected in step S1, and the acid fracturing pipe string are combined to optimize and design the acid fracturing construction parameters, including the acid fluid amount Q ac and the displacement q ac .

[0069] Specifically, using the mprod module of the Meyer software, the single factor variable method is used, the acid etching fracture conductivity is fixed, the acid etching fracture length is changed, and the optimization result is shown in Figure 1 , the acid etching half-fracture length L ac is optimized to 200m; in the same way, the acid etching fracture length is fixed, the acid etching fracture conductivity is changed, and the optimization result is shown in Figure 2 , the acid etching fracture conductivity D ac is optimized to 5μm 2 ·cm. The multi-hydrogen acid system reaction kinetics parameters selected in step S1 are: the reaction order m is 2.5110, the reaction rate constant is 9.94×10 -7 (mol / L) 1-m / s, the reaction activation energy is 11.17kJ / mol, and the frequency factor is 1.66×10-5 (mol / L) 1-m / s, H + mass transfer coefficient 3.1 x 10 - 10 cm 2 / s, the acid fracturing pipe column size is 73 mm, the MFrac module is used to optimize the acid fracturing construction parameter, and the acid liquid consumption Q ac is 450 m 3 , and the displacement qac is 2.5 m 3 / min, so that the acid etching half-fracture length is 200 m and the acid etching fracture conductivity is 5 μm 2 ·cm.

[0070] Step S3: combined with the acid fracturing construction parameter, the pressure P div required for the artificial fracture to divert to the natural fracture under the temporary plugging is calculated.

[0071] Specifically, the closure stress σ NF of the natural fracture is 18.6 MPa, the horizontal maximum principal stress σ H is 96.9 MPa, the horizontal minimum principal stress σ h is 78.1 MPa, the induced stress σ ind calculated by using the displacement discontinuity method is 9.3 MPa, and the pressure P div required for the artificial fracture to divert to the natural fracture under the temporary plugging calculated by using formula (1) is 28.1 MPa.

[0072] Step S4: according to the sand control completion and the acid fracturing construction parameter, the type of the temporary plugging agent is initially selected; and according to the temporary plugging position and the control field calculation, the final temporary plugging agent is determined.

[0073] Specifically, the sand control screen pipe completion is selected for the pure liquid type temporary plugging agent; the temporary plugging position is at the fracture length of 45 m, the temporary plugging agent needs 10.9 min to flow in the wellbore and needs 5.8 min to flow to the temporary plugging position in the fracture; the temperature-controlled temporary plugging agent is used, the wellbore-fracture temperature field distribution is calculated by formula (2), the fluid density ρ f is 1060 kg / m 3 , the fluid specific heat capacity C f is 3200 J / (kg·℃), the fluid flow rate v f is 9.96 m / s, the r1 pipe diameter is 0.073 m, the comprehensive heat transfer coefficient λ c is 2.1 J / (m 2 ·℃·s), the formation temperature T r is 183℃, the fluid thermal conductivity λ f is 0.17 J / (m·℃·s), the ground injection temperature is 15℃, and the fracture parameters are obtained in step S2, so that the wellbore temperature is calculated as shown in Figure 3 and the fracture temperature is calculated as shown inFigure 4 As shown, the temporary plugging agent needs 16.8 min to solidify at 70℃, which is greater than the sum of 10.9 min and 5.8 min, and the temporary plugging agent just meets the requirement.

[0074] Step S5: The temporary plugging strength gradient P of the temporary plugging agent is tested bre , and the temporary plugging agent dosage Q is designed div . Specifically, the temporary plugging strength tester is used to measure the pressure required to break through the temporary plugging layer under different temporary plugging lengths, and the temporary plugging strength gradient P bre of 8.4 MPa / m is fitted; combined with the result calculated in step S3, the safety factor ζ is 1.3, the slot width w is 0.004 m, the slot height h is 40 m, and the temporary plugging agent dosage Q div of 1.4 m 3 is calculated using formula (4).

[0075] Step S6: The main acid liquid system and the determined dosage of the temporary plugging agent are injected into the fractured gneiss reservoir to realize the temporary plugging of the artificial fractures to the natural fractures, activate and connect the cemented or non-cemented natural fractures, and form a fracture network acid fracturing.

[0076] Finally, it should be noted that the above examples are only used to illustrate the technical solutions of the present application, and not to limit them; although the present application has been described in detail with reference to the foregoing examples, those skilled in the art should understand that they can still modify the technical solutions recorded in the foregoing examples, or make equivalent replacements for part of the technical features; and these modifications or replacements do not make the essence of the corresponding technical solutions deviate from the spirit and scope of the technical solutions of the embodiments of the present application.

Claims

1. A method for fracture network acid fracturing reconstruction of a fractured gneiss reservoir, characterized in that, The method comprises the following steps: According to the geological characteristics of the fractured gneiss reservoir, the main acid liquid and the additive are preliminarily determined, different main acid liquid systems are composed, and the core displacement experiment and the rock plate conductivity capacity test experiment are used to finally determine the main acid liquid system; Based on the geological and fluid characteristics of the oil and gas reservoir, the acid fracturing crack parameters are optimized by using the percolation mechanics method; The acid fracturing construction parameters are optimized by using the full three-dimensional fracturing model, combining the acid fracturing crack parameters, the finally determined reaction kinetics parameters of the main acid liquid system and the acid fracturing pipe column; The pressure required for the artificial crack to turn to the natural crack under the temporary plugging is calculated in combination with the acid fracturing construction parameters; According to the sand control completion and the acid fracturing construction parameters, the type of the temporary plugging agent is initially selected, and the final temporary plugging agent is determined according to the temporary plugging position and the field distribution calculation; The temporary plugging strength gradient of the temporary plugging agent is tested, and the dosage of the temporary plugging agent is calculated according to the pressure required for the artificial crack to turn to the natural crack under the temporary plugging; The main acid liquid system and the temporary plugging agent with the determined dosage are injected into the fractured gneiss reservoir to realize the temporary plugging of the artificial crack to the natural crack, activate and connect the cemented or non-cemented natural cracks, and form the network acid fracturing. The field distribution includes the wellbore-crack temperature field distribution and the pH field distribution in the crack, and the specific calculation process of the wellbore-crack temperature field distribution is as follows: where: p f is fluid density; C f is fluid specific heat; v f is fluid flow rate; T f is fluid temperature; z is axial depth along the wellbore; t is time; r1 is pipe diameter; λ c is overall heat transfer coefficient; T r is formation temperature; q a is heat of reaction; λ f is fluid thermal conductivity; x is length along the slot length; y is length perpendicular to the wall; a is wall heat transfer coefficient; w is slot width; The specific calculation process of the pH field distribution in the crack is as follows: where: Φ is the porosity; C H + is the molar concentration of hydrogen ions; t is time; is the gradient operator; U is the flow velocity; C e,H + is the effective diffusion coefficient of hydrogen ions; R H + is the surface reaction rate; a v is the specific surface area.

2. The fractured gneiss reservoir network acid fracturing modification method according to claim 1, characterized in that, The geological characteristics of the fractured gneiss reservoir include the reservoir burial depth, temperature, oil and gas and geological characteristics, rock mineral composition and pipe column corrosion.

3. The fractured gneiss reservoir network acid fracturing modification method according to claim 1, characterized in that, The main acid liquid includes any one of the retarded acid liquid, the conventional mud acid liquid, the alcohol-based acid liquid or the water-based acid liquid; the additive includes any one or more of the resistance reducing agent, the surfactant, the iron ion stabilizer, the clay stabilizer or the corrosion inhibitor.

4. The fractured gneiss reservoir network acid fracturing modification method according to claim 1, characterized in that, The acid-fracture parameters include acid-etched fracture length and acid-etched fracture conductivity; the main acid-liquid system reaction kinetics parameters include reaction order, reaction speed constant, reaction activation energy, frequency factor and H + mass transfer coefficient; the acid-fracturing construction parameters include acid-liquid amount and displacement.

5. The fractured gneiss reservoir network acid fracturing modification method according to claim 1, characterized in that, P = (Pf - Pw) / (1 - Sf) div P = (Pf - Pw) / (1 - Sf) P div = σ NF + σ H - σ h - σ ind (1) where: σ NF is the shear strength or closure stress of the natural fractures; σ H is the horizontal maximum principal stress; σ h is the horizontal minimum principal stress; σ ind is the induced stress.

6. The fractured gneiss reservoir network acid fracturing modification method according to claim 5, characterized in that, The dosage calculation formula of the temporary plugging agent is: where: Q div is the temporary plugging agent dosage; ζ is the safety factor; h is the fracture height; P bre is the temporary plugging strength gradient.

7. A device for fracture network acid fracturing reconstruction of fractured gneiss reservoirs for implementing the method for fracture network acid fracturing reconstruction of fractured gneiss reservoirs according to any one of claims 1-6, characterized in that, It comprises: The first processing unit is used for preliminarily determining the main acid liquid and the additive according to the geological characteristics of the fractured gneiss reservoir, composing different main acid liquid systems, and finally determining the main acid liquid system by using the core displacement experiment and the rock plate conductivity capacity test experiment; The second processing unit is used for optimizing the acid fracturing crack parameters by using the percolation mechanics method based on the geological and fluid characteristics of the oil and gas reservoir; The acid fracturing construction parameters are optimized by using the full three-dimensional fracturing model, combining the acid fracturing crack parameters, the finally determined reaction kinetics parameters of the main acid liquid system and the acid fracturing pipe column; The third processing unit is used for calculating the pressure required for the artificial crack to turn to the natural crack under the temporary plugging in combination with the acid fracturing construction parameters; The fourth processing unit is used for initially selecting the type of the temporary plugging agent according to the sand control completion and the acid fracturing construction parameters, and determining the final temporary plugging agent according to the temporary plugging position and the field distribution calculation; The fifth processing unit is used for injecting the main acid liquid system and the temporary plugging agent with the determined dosage into the fractured gneiss reservoir to realize the temporary plugging of the artificial crack to the natural crack, activate and connect the cemented or non-cemented natural cracks, and form the network acid fracturing.

8. A computer readable storage medium having stored thereon a computer program, characterized in that, The computer program is executed by the processor to realize the steps of the fractured gneiss reservoir network acid fracturing reconstruction method in any one of claims 1-6.

9. A computer device comprising a memory, a processor, and a computer program stored on the memory and executable on the processor, characterized in that, The processor executes the computer program to realize the steps of the fractured gneiss reservoir network acid fracturing reconstruction method in any one of claims 1-6.

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