CN111894545A - Method for determining proppant pumping scheme - Google Patents
Method for determining proppant pumping scheme Download PDFInfo
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Abstract
A method of proppant pumping protocol determination, comprising: the method comprises the steps of firstly, obtaining a first-level reservoir type of a reservoir to be analyzed of a propping agent to be pumped, determining a second-level reservoir type of the reservoir to be analyzed under the first-level reservoir type according to reservoir geological parameters of the reservoir to be analyzed, and simulating fracture system forms formed under different pumping conditions according to the second-level reservoir type; simulating migration and sedimentation rules of the proppant under different preset proppant pumping combination conditions according to the form of the fracture system, and determining the flow conductivity of the fracture system; and step three, screening to obtain the most potential seam net structure and the pump injection scheme according to the flow guide capacity of the seam system. The method can be used for evaluating the flow conductivity of the fracture system and the fracturing well capacity of the oil and gas wells with different types of oil and gas reservoirs, different types of reservoirs and different characteristics under the combination of different types of proppants and different pumping and injecting procedures of fracturing fluid, and is beneficial to improving the effective propping fracture network volume and the flow conductivity of the whole fracture system.
Description
Technical Field
The invention relates to the technical field of oil and gas exploration and development, in particular to a method for determining a proppant pumping scheme.
Background
More than 50% of oil and gas field blocks in China belong to shale, compact and low-permeability reservoirs, fracturing reformation becomes a conventional mode for realizing effective exploitation of oil and gas, and a propping agent is a necessary material for all hydraulic fracturing reformation and partial acid fracturing reformation. Aiming at different types of reservoirs, the optimal design of proppant pumping is developed, the effective supporting volume and the flow conductivity of a fracture system are improved to the maximum extent, and the method has important significance for improving the fracturing transformation effect, reducing the fracturing action risk and improving the oil-gas well recovery ratio and the oil field economic benefit.
Disclosure of Invention
The invention provides a proppant pumping scheme determination method, which comprises the following steps:
the method comprises the steps of firstly, obtaining a first-level reservoir type of a reservoir to be analyzed of a propping agent to be pumped, determining a second-level reservoir type of the reservoir to be analyzed under the first-level reservoir type according to reservoir geological parameters of the reservoir to be analyzed, and simulating fracture system forms formed under different pumping conditions according to the second-level reservoir type;
simulating migration and sedimentation rules of the proppant under different preset proppant pump injection combination conditions according to the form of the fracture system, and determining the flow conductivity of the fracture system;
and step three, screening to obtain the most potential seam net structure and the pump injection scheme according to the flow conductivity of the seam system.
According to an embodiment of the present invention, in the first step, the step of obtaining the reservoir type of the reservoir to be analyzed includes:
screening out main control factors influencing the effective fracturing modification volume and the fracturing network complexity from the reservoir geological parameters of the reservoir to be analyzed;
determining a comprehensive evaluation coefficient of the reservoir to be analyzed according to the dimensionless quantity value and the weight coefficient of each main control factor;
and determining the type of the secondary reservoir of the reservoir to be analyzed according to the comprehensive evaluation coefficient.
According to one embodiment of the present invention, the comprehensive evaluation coefficient is determined according to the following expression:
wherein alpha istDenotes the comprehensive evaluation coefficient, ciAnd ωiDimensionless values and weight coefficients representing the ith master factor, respectively, cmAnd the median of the dimensionless values of all the master factors is shown, and n is the total number of the master factors obtained by screening.
According to one embodiment of the invention, in the first step, the comprehensive evaluation coefficient of the reservoir to be analyzed is compared with a preset evaluation coefficient threshold value,
if the comprehensive evaluation coefficient of the reservoir to be analyzed is larger than a first preset evaluation coefficient threshold value, judging that the reservoir to be analyzed is a first type of reservoir;
if the comprehensive evaluation coefficient of the reservoir to be analyzed is smaller than or equal to a first preset evaluation coefficient threshold value but larger than a second preset evaluation coefficient threshold value, judging that the reservoir to be analyzed is a second type of reservoir;
and if the comprehensive evaluation coefficient of the reservoir to be analyzed is less than or equal to a second preset evaluation coefficient threshold value, judging that the reservoir to be analyzed is a third type reservoir.
According to one embodiment of the invention, the primary reservoir types include shale reservoirs, tight reservoirs, and conventional hypotonic reservoirs.
According to an embodiment of the invention, in the first step, the fracture system form formed by the stratum of the secondary reservoir type under different pumping conditions is simulated in a stress field superposition simulation mode, and the fracture propagation direction of the fracture system is determined by superposing all the induced stresses of the fracture units and utilizing a maximum hoop stress criterion.
According to one embodiment of the invention, the crack propagation direction is determined according to the following expression:
Itsinθ+Is(3cosθ-1)＝0
wherein, ItAnd IsBoth represent stress intensity factors, and θ represents the crack propagation direction.
According to an embodiment of the invention, in said step three,
calculating the fracturing well productivity under different preset proppant pump injection combination conditions according to the fracture system form and the fracture system flow conductivity;
and screening to obtain the most potential fracture network structure and a pump injection scheme according to the flow conductivity of the fracture system and the capacity of the fracturing well.
According to an embodiment of the invention, the method further comprises:
and step four, based on the most potential gap net structure obtained by screening, the step one is repeatedly executed to further optimize a pumping scheme on the basis of the most potential gap net existing in the reservoir to be analyzed, so as to obtain an optimized pumping scheme.
According to an embodiment of the invention, the method further comprises:
and step five, analyzing each target well in the reservoir to be analyzed by utilizing the steps from the first step to the fourth step, and correspondingly obtaining an optimized pumping scheme of each target well.
The proppant pumping scheme determining method provided by the invention can be used for evaluating the flow conductivity of a fracture system and the capacity of a fracturing well formed by oil and gas wells with different types of oil and gas reservoirs, different types of reservoirs and different characteristics under the combination of different types of proppant and different pumping programs of fracturing fluid, and is beneficial to improving the volume of an effective supporting fracture network and the flow conductivity of the whole fracture system, thereby realizing the long-term effective support of the fracture system or a complex fracture network.
Meanwhile, the method can be used for carrying out fracturing construction on a target oil-gas well of a target reservoir of a target oil-gas reservoir step by step through cyclic simulation, verification, optimization, test, evaluation and re-simulation, so that the operation efficiency is improved to the maximum extent, the operation risk is reduced, and guiding suggestions are provided for improving the fracturing construction effect of the oil-gas field and improving the economic benefit.
Additional features and advantages of the invention will be set forth in the description which follows, and in part will be obvious from the description, or may be learned by practice of the invention. The objectives and other advantages of the invention will be realized and attained by the structure particularly pointed out in the written description and claims hereof as well as the appended drawings.
Drawings
In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the following briefly introduces the drawings required in the description of the embodiments or the prior art:
FIG. 1 is a schematic flow chart of an implementation of a proppant pumping scheme determination method according to one embodiment of the present invention;
FIG. 2 is a schematic flow diagram of an implementation of determining a secondary reservoir type according to one embodiment of the present invention;
fig. 3 is a schematic flow chart of an implementation of determining the most potential slotted-net structure and pumping scheme according to an embodiment of the present invention.
Detailed Description
The following detailed description of the embodiments of the present invention will be provided with reference to the drawings and examples, so that how to apply the technical means to solve the technical problems and achieve the technical effects can be fully understood and implemented. It should be noted that, as long as there is no conflict, the embodiments and the features of the embodiments of the present invention may be combined with each other, and the technical solutions formed are within the scope of the present invention.
In the following description, for purposes of explanation, numerous specific details are set forth in order to provide a thorough understanding of the embodiments of the invention. It will be apparent, however, to one skilled in the art that the present invention may be practiced without some of these specific details or with other methods described herein.
Additionally, the steps illustrated in the flow charts of the figures may be performed in a computer system such as a set of computer-executable instructions and, although a logical order is illustrated in the flow charts, in some cases, the steps illustrated or described may be performed in an order different than here.
Currently, there are a number of problems with fracturing proppant pumping. For example, the existing fracturing proppant pumping technology is not deep enough to recognize the reservoir, and when simulation research and field test are carried out, the existing technology cannot subdivide a target oil and gas reservoir block and a reservoir type according to geological parameters, and is not clear enough to recognize a fracture system formed by different reservoir types under the same pumping condition; at present, software capable of truly simulating a complex seam network structure formed under a certain pump injection condition does not exist, and currently, universal meyer software only can form an orthogonal seam network; the research on the migration and laying rule of the proppant in different seam net systems needs to be further systematized and perfected; the migration and laying rule of the proppant in the complex seam net and the design of a fracturing pump injection program cannot be systematically and accurately associated; the numerical simulation research is disjointed with the field test, and the systematic and clear association between the field test effect and the evaluation result and the proppant pumping numerical simulation is not established; the field test and the large-scale fracturing construction cannot establish stable cycle correlation, and the fracturing construction cannot be developed step by taking one test well as initial propulsion.
In view of the problems in the prior art, the present invention provides a new method for determining a proppant pumping scheme, which is capable of determining an appropriate proppant pumping scheme for different reservoir types.
Fig. 1 shows a schematic implementation flow chart of the proppant pumping scheme determination method provided by this embodiment.
As shown in fig. 1, the method for determining a proppant pumping scheme provided in this embodiment preferably first obtains a first-order reservoir type of a reservoir to be analyzed, into which a proppant is to be pumped, in step S101. Specifically, in this embodiment, the first-stage reservoir type of the reservoir to be analyzed preferably includes: shale reservoirs, tight reservoirs and conventional hypotonic reservoirs. That is, the first reservoir type of the reservoir to be analyzed may be one of a shale reservoir, a tight reservoir, and a conventional hypotonic reservoir.
Of course, in other embodiments of the present invention, the above-mentioned first-stage reservoir type may also include other reasonable reservoir types according to actual situations, and the present invention is not limited to this.
After the first-level reservoir type of the reservoir to be analyzed is obtained, in this embodiment, the method further determines, in step S101, a second-level reservoir type of the reservoir to be analyzed under the first-level reservoir type according to the reservoir geological parameters of the reservoir to be analyzed.
Fig. 2 shows a schematic flow chart of the implementation of determining the secondary reservoir type in the present embodiment.
As shown in fig. 2, in this embodiment, when determining the secondary reservoir type of the reservoir to be analyzed, the method preferably first screens out the main control factors affecting the effective fracturing modification volume and the fracture network complexity from the reservoir geological parameters of the reservoir to be analyzed in step S201.
Specifically, in this embodiment, the method preferably employs a grey correlation method in step S201 to screen out the dominant factors affecting the effective fracture reformation volume and the complexity of the fracture network from a plurality of reservoir geological parameters. For example, the main control factors screened by the method can comprise brittleness index, Young modulus, Poisson ratio, stress difference of a storage layer and the like. Of course, in other embodiments of the present invention, the method may also adopt other reasonable manners to screen the master control factors, and meanwhile, the master control factors screened by the method may also include other reasonable parameters that are not listed, which is not specifically limited by the present invention.
After the master control factors affecting the effective fracturing modification volume and the complexity of the fracturing fracture network are obtained, as shown in fig. 2, in this embodiment, the method determines the comprehensive evaluation coefficient of the reservoir to be analyzed according to the dimensionless quantity values and the weight coefficients of the respective master control factors in step S202.
Specifically, in this embodiment, the method preferably determines the dimensionless value of each master factor according to the following expression:
wherein, ciAnd ωiDimensionless values and weight coefficients, f, representing the ith master factor, respectivelyiThe magnitude of the ith master factor is shown, and n is the total number of the screened master factors.
Based on the dimensionless values of the master factors, the method preferably determines a median value c from the dimensionless values of the master factorsmAnd then based on the median cmDetermining the dimensionless quantity value of each main control factor and weighting coefficient to determine the comprehensive evaluation coefficient of the reservoir to be analyzed.
For example, in this embodiment, the method may determine the comprehensive evaluation coefficient according to the following expression:
wherein alpha istDenotes the comprehensive evaluation coefficient, cmRepresenting all key factorsMedian dimensionless value of the elements.
Of course, in other embodiments of the present invention, the method may also determine the comprehensive evaluation coefficient α of the reservoir to be analyzed in other reasonable manners according to actual needstThe present invention is not particularly limited thereto.
As shown in fig. 2, the comprehensive evaluation coefficient alpha of the reservoir to be analyzed is obtainedtThe method may also be performed in step S203 based on the above-mentioned overall evaluation coefficient αtTo determine the secondary reservoir type of the reservoir to be analyzed. Specifically, in the present embodiment, the method is preferably performed by integrating the above-described comprehensive evaluation coefficient αtAnd comparing the evaluation coefficient with a preset evaluation coefficient threshold value, and determining the type of the secondary reservoir of the reservoir to be analyzed according to the comparison result.
For example, if the comprehensive evaluation coefficient of the reservoir to be analyzed is greater than a first preset evaluation coefficient threshold value, the method can determine that the reservoir to be analyzed is a first type of reservoir; if the comprehensive evaluation coefficient of the reservoir to be analyzed is less than or equal to the first preset evaluation coefficient threshold value but greater than the second preset evaluation coefficient threshold value, the method can judge that the reservoir to be analyzed is a second type of reservoir; and if the comprehensive evaluation coefficient of the reservoir to be analyzed is less than or equal to the second preset evaluation coefficient threshold value, the method can judge that the reservoir to be analyzed is a third type reservoir.
In the present embodiment, the first preset evaluation coefficient threshold is preferably configured to be 2/3, and the second preset evaluation coefficient threshold is preferably configured to be 1/3. Of course, in other embodiments of the present invention, according to actual needs, the first preset evaluation coefficient threshold and/or the second preset evaluation coefficient threshold may also be configured to be other reasonable values, and the present invention does not limit specific values of the first preset evaluation coefficient threshold and the second preset evaluation coefficient threshold.
As shown again in fig. 1, in this embodiment, after determining the secondary reservoir type of the reservoir to be analyzed, the method preferably simulates the fracture system morphology formed under different pumping conditions according to the secondary reservoir type in step S102.
Specifically, in the embodiment, the method can collect and arrange geological parameters of the target oil and gas field block, and simulate and research the form of a fracture system (including a complex fracture network) formed by different types of reservoirs under different pumping conditions based on the geological parameters.
For example, in step S102, the method may preferably simulate the fracture system morphology formed by the formation of the secondary reservoir type under different pumping conditions by means of stress field superposition simulation.
Assuming that a 2l long crack exists in the X-Y-Z coordinate system, the displacements of the two discontinuous crack surfaces in the X-Y-Z coordinate system are respectively
And
the displacement d is then preferably expressed as follows:
wherein d isx、dyAnd dyRepresenting the displacement components in the x, y and z directions, respectively.
Suppose that:
crack displacement (d)x,dy,dz) The displacement and stress generated by any field point n in the plane can be expressed by the following equation:
sx＝dx[2(1-v)f'yz-(y+z)f'xx]+dy[-(1-2v)f'xz-yf'xy-zf'xz]+dz[-(1-2v)f'xy-yf'xy-zf'xz](9)
sy＝dx[2(1-v)f'xz-(y+z)f'yy]+dy[-(1-2v)f'yz-yf'xy-zf'yz]+dz[-(1-2v)f'xy-yf'xy-zf'yz](10)
sz＝dx[2(1-v)f'xy-(y+z)f'zz]+dy[-(1-2v)f'yz-yf'yz-zf'xz]+dz[-(1-2v)f'xy-yf'yz-zf'xz](11)
this also holds true:
σxx＝2Gdx[2(f'xy+f'xz)+yf'xyy+zf'xzz]+2Gdy[f'yy+f'yz+yf'yyy+zf'yzz]+2Gdz[-f'yz+f'zz-yf'yyz+zf'zzz](12)
σyy＝2G(dx+dz)[-yf'xyy+yf'yzz]+2Gdy[f'yy+yf'yyy](13)
σzz＝2G(dx+dy)[-zf'xzz+zf'zzz]+2Gdz[f'zz+zf'zzz](14)
σxy＝2Gdx(f'yy+yf'xyy)+2Gdy(-yf'yyy) (15)
σxz＝2Gdx(f'zz+zf'xzz)+2Gdz(-zf'zzz) (16)
σyz＝2Gdy(f'zz+yf'yzz)+2Gdz(-zf'zzz) (17)
wherein σxx、σyy、σzzRespectively, positive stress in x, y, z directions, G shear modulus, σxyDenotes the x-y plane shear stress, σxzDenotes x-z plane shear stress, σyzDenotes y-z plane shear stress, f'xyRepresenting an x-y plane mapping function, f'xyyRepresenting the vector values of the x-y plane mapping function in the y direction.
Substituting the coordinates (x, y, z) of point n into the expression to obtain the crack generation displacement (d)x,dy,dz) The stress and displacement of the point.
Meanwhile, the method preferably determines the fracture propagation direction of the fracture system by using the maximum hoop stress criterion by superposing the induced stresses of all the fracture units. For example, in this embodiment, the method may determine the crack propagation direction according to the following expression:
Itsinθ+Is(3cosθ-1)＝0 (18)
wherein, ItAnd IsBoth represent stress intensity factors, and θ represents the crack propagation direction. Stress intensity factor ItAnd IsPreferably calculated from the tension and shear displacements of the fracture tip unit.
As shown in fig. 1, in this embodiment, the method preferably simulates migration and sedimentation rules of the proppant under different preset proppant pumping combination conditions according to the fracture system morphology obtained in step S102 in step S103, and determines the corresponding fracture system conductivity in step S104.
Specifically, in this embodiment, the method may select different types and combinations of proppants and fracturing fluids to perform the simulation one by one in step S103. For example, the method may draw fracture systems or complex fracture networks formed by different types of reservoirs under different pumping conditions in, for example, Fluent software based on the fracture morphology obtained in step S102, further simulate and research migration and settlement rules of one or one combination of proppants in the drawn fracture network, and calculate the corresponding fracture system conductivity in step S104.
After obtaining the fracture system conductivity, in this embodiment, the method preferably screens out the most potential fracture network structure and pumping scheme from the plurality of fracture results and pumping schemes according to the fracture system conductivity in step S105.
Specifically, based on the forms of the fracture systems formed under different pumping conditions obtained in step S102, the method preferably screens potential fracture network systems with preset numbers (values can be configured to different reasonable values according to actual needs). For each potential fracture system, different types of fracturing fluids and proppants are preferably selected in step S105 for pump injection combined optimization design, and then the most potential fracture network structure and the pump injection scheme are preliminarily screened out according to the obtained flow conductivity of the corresponding fracture system.
Fig. 3 shows a schematic flow chart of an implementation process for determining the most potential slotted-net structure and the pump injection scheme in the embodiment.
As shown in fig. 3, in this embodiment, the method preferably calculates the fracturing well productivity under different preset proppant pumping combination conditions according to the fracture system morphology and the fracture system conductivity in step S301, and then screens out the most potential fracture network structure and pumping scheme from a preset number of potential fracture network systems according to the fracture system conductivity and the fracturing well productivity in step S302.
Of course, in other embodiments of the present invention, the method may also use other reasonable ways to screen out the most potential gap net structure and pumping scheme in step S104.
As shown in fig. 1, optionally, in this embodiment, in step S106, based on the most potential gap net structure obtained by screening in step S105, the method may further repeat the above steps S103 to S105 to further optimize the pumping scheme based on the most potential gap net existing in the reservoir to be analyzed, so as to obtain an optimized pumping scheme.
It should be noted that the number of times that the method repeatedly executes steps S103 to S105 when determining the optimal pumping scheme may be configured to be different reasonable values according to actual needs, and the present invention is not limited thereto.
In this embodiment, optionally, in order to verify the practicability and applicability of the obtained optimized pumping scheme, the method may further include a pumping scheme verification step. In the pump injection scheme verification step, the optimized pump injection scheme obtained in the step S106 may be applied to a field test developed in one target well of the reservoir to be analyzed, and the test effect may be evaluated. According to actual needs, the method can further adjust the pumping scheme according to the verification result.
As shown in fig. 1, in this embodiment, optionally, the method may further perform, in step S107, analysis on each target well in the reservoir to be analyzed by repeatedly performing steps S102 to S106, so as to obtain an optimized pumping scheme for each target well correspondingly.
After the optimized pump injection scheme of each target well in the reservoir to be analyzed is obtained, all simulation, test, evaluation and schemes can be packaged, sorted and stored by the method so as to provide a basis for determining the pump injection scheme of the next target well.
In this embodiment, for each different type of reservoir included in the target block, the method may obtain the optimized pumping scheme for each well of each type of reservoir by repeatedly performing steps S101 to S106, and perform post-compression evaluation, summarize and pack simulation, test, and evaluation data.
In addition, according to actual needs, in this embodiment, the method may further include designing an optimal pumping scheme for each well of each type of reservoir in each block of the target field by using the steps S101 to S107 according to different blocks divided from the target field, and summarizing, packaging, designing, and constructing data.
From the above description, it can be seen that the proppant pumping scheme determination method provided by the invention can be used for evaluating the conductivity and fracturing well productivity of a fracture system formed by oil and gas wells with different types of oil and gas reservoirs, different types of reservoirs and different characteristics under different combinations of different types of proppant and different pumping procedures of fracturing fluid, and is beneficial to improving the effective supporting fracture network volume and the conductivity of the whole fracture system, so that the long-term effective supporting of the fracture system or a complex fracture network is realized.
Meanwhile, the method can be used for carrying out fracturing construction on a target oil-gas well of a target reservoir of a target oil-gas reservoir step by step through cyclic simulation, verification, optimization, test, evaluation and re-simulation, so that the operation efficiency is improved to the maximum extent, the operation risk is reduced, and guiding suggestions are provided for improving the fracturing construction effect of the oil-gas field and improving the economic benefit.
It is to be understood that the disclosed embodiments of the invention are not limited to the particular structures or process steps disclosed herein, but extend to equivalents thereof as would be understood by those skilled in the relevant art. It is also to be understood that the terminology used herein is for the purpose of describing particular embodiments only, and is not intended to be limiting.
Reference in the specification to "one embodiment" or "an embodiment" means that a particular feature, structure, or characteristic described in connection with the embodiment is included in at least one embodiment of the invention. Thus, the appearances of the phrase "one embodiment" or "an embodiment" in various places throughout this specification are not necessarily all referring to the same embodiment.
While the above examples are illustrative of the principles of the present invention in one or more applications, it will be apparent to those of ordinary skill in the art that various changes in form, usage and details of implementation can be made without departing from the principles and concepts of the invention. Accordingly, the invention is defined by the appended claims.
Claims (10)
1. A method of proppant pumping schedule determination, the method comprising:
the method comprises the steps of firstly, obtaining a first-level reservoir type of a reservoir to be analyzed of a propping agent to be pumped, determining a second-level reservoir type of the reservoir to be analyzed under the first-level reservoir type according to reservoir geological parameters of the reservoir to be analyzed, and simulating fracture system forms formed under different pumping conditions according to the second-level reservoir type;
simulating migration and sedimentation rules of the proppant under different preset proppant pump injection combination conditions according to the form of the fracture system, and determining the flow conductivity of the fracture system;
and step three, screening to obtain the most potential seam net structure and the pump injection scheme according to the flow conductivity of the seam system.
2. The method of claim 1, wherein in step one, the step of obtaining the reservoir type of the reservoir to be analyzed comprises:
screening out main control factors influencing the effective fracturing modification volume and the fracturing network complexity from the reservoir geological parameters of the reservoir to be analyzed;
determining a comprehensive evaluation coefficient of the reservoir to be analyzed according to the dimensionless quantity value and the weight coefficient of each main control factor;
and determining the type of the secondary reservoir of the reservoir to be analyzed according to the comprehensive evaluation coefficient.
3. The method of claim 2, wherein the comprehensive evaluation coefficient is determined according to the following expression:
wherein alpha istDenotes the comprehensive evaluation coefficient, ciAnd ωiDimensionless values and weight coefficients representing the ith master factor, respectively, cmAnd the median of the dimensionless values of all the master factors is shown, and n is the total number of the master factors obtained by screening.
4. The method according to claim 2 or 3, characterized in that in step one, the comprehensive evaluation coefficient of the reservoir to be analyzed is compared with a preset evaluation coefficient threshold value,
if the comprehensive evaluation coefficient of the reservoir to be analyzed is larger than a first preset evaluation coefficient threshold value, judging that the reservoir to be analyzed is a first type of reservoir;
if the comprehensive evaluation coefficient of the reservoir to be analyzed is smaller than or equal to a first preset evaluation coefficient threshold value but larger than a second preset evaluation coefficient threshold value, judging that the reservoir to be analyzed is a second type of reservoir;
and if the comprehensive evaluation coefficient of the reservoir to be analyzed is less than or equal to a second preset evaluation coefficient threshold value, judging that the reservoir to be analyzed is a third type reservoir.
5. The method of any one of claims 1 to 4, wherein the primary reservoir types comprise shale reservoirs, tight reservoirs, and conventional hypotonic reservoirs.
6. The method according to any one of claims 1 to 5, wherein in the first step, the fracture system morphology formed by the stratum of the secondary reservoir type under different pumping conditions is simulated by a stress field superposition simulation mode, and the fracture propagation direction of the fracture system is determined by superposing all the induced stresses of the fracture units and utilizing a maximum hoop stress criterion.
7. The method of claim 6, wherein the crack propagation direction is determined according to the expression:
Itsinθ+Is(3cosθ-1)＝0
wherein, ItAnd IsBoth represent stress intensity factors, and θ represents the crack propagation direction.
8. The method according to any one of claims 1 to 7, wherein, in step three,
calculating the fracturing well productivity under different preset proppant pump injection combination conditions according to the fracture system form and the fracture system flow conductivity;
and screening to obtain the most potential fracture network structure and a pump injection scheme according to the flow conductivity of the fracture system and the capacity of the fracturing well.
9. The method of any one of claims 1 to 8, further comprising:
and step four, based on the most potential gap net structure obtained by screening, the step one is repeatedly executed to further optimize a pumping scheme on the basis of the most potential gap net existing in the reservoir to be analyzed, so as to obtain an optimized pumping scheme.
10. The method of claim 9, wherein the method further comprises:
and step five, analyzing each target well in the reservoir to be analyzed by utilizing the steps from the first step to the fourth step, and correspondingly obtaining an optimized pumping scheme of each target well.
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