CN115618759A - Shale gas formation fracturing construction parameter optimization method - Google Patents
Shale gas formation fracturing construction parameter optimization method Download PDFInfo
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Abstract
The invention discloses a shale gas formation fracturing construction parameter optimization method, which comprises the following steps: obtaining geological parameters, physical parameters and fracturing design parameters of a reservoir stratum of a shale fracturing block; establishing a shale gas horizontal well subsection multi-cluster fracturing complex fracture network dynamic expansion model; establishing a single-well yield calculation model after fracturing transformation of the shale gas horizontal well; establishing a shale gas horizontal well subsection multi-cluster fracturing reconstruction cost calculation model based on the expense required by each project of horizontal well fracturing reconstruction; and calculating the net current production value after shale gas horizontal well fracturing transformation under different fracturing design parameters by combining the fracture network dynamic expansion model, the single well yield calculation model and the fracturing transformation cost calculation model so as to optimize the fracturing design parameters. The shale gas formation fracturing construction parameter optimization method provided by the invention is reliable in principle, has operability and accuracy, and can be used for carrying out full-section optimization on shale gas horizontal well fracturing construction parameters on the premise of giving basic parameters.
Description
Technical Field
The invention relates to the field of yield increase transformation of oil and gas fields, in particular to a shale gas formation fracturing construction parameter optimization method.
Background
The hydraulic fracturing is a key technology for realizing large-scale development of unconventional oil and gas resources such as shale oil and gas, compact oil and gas and the like, a ground pump-injection truck group injects working fluid into a stratum through a shaft, reservoir rock is fractured and artificial fractures are generated under the action of fluid pressure, sand-carrying liquid is continuously pumped and injected, finally, sand-filled fractures with high flow conductivity are formed in the reservoir, the fluidity of the reservoir is effectively improved, the flow pressure difference of a fluid medium in the reservoir and the seepage distance in a porous medium are reduced, the unconventional reservoir is reformed, and the yield of oil and gas of a single well is increased.
The large-scale volume fracturing effect determines the exploitation yield of shale gas, and in order to ensure higher single-well yield, shale reservoirs need to be fully reformed. The formation of complex fractures with certain flow conductivity in a shale reservoir is the key of high yield, and the multiple fractures can be effectively initiated and uniformly expanded when multiple clusters of fracturing are performed in a horizontal well section, so that the complex fracture network is formed by effectively communicating natural fractures, and the optimization design of fracturing construction parameters of a shale gas horizontal well is required. On-site engineers increase the fracturing scale by increasing the fracturing fluid amount and the propping agent amount, so as to obtain high yield of the shale gas well, cause mismatching of the reservoir transformation degree and the reservoir productivity, cause a great deal of resource waste, increase the development cost of the shale gas, and be not in accordance with the exploitation principle of 'cost reduction and efficiency improvement' of the shale gas, which needs to provide higher requirements for the optimization design of fracturing construction parameters.
At present, when shale gas horizontal well fracturing construction parameters are optimized in China, effective initiation and effective extension of fractures are mainly focused, effective uniform extension of multi-cluster horizontal well staged fracturing multi-fractures and enough-length and wide fracture targets are formed, fracturing construction parameters are optimized, seepage after fracturing is not fully considered, economic evaluation on fracturing construction is lacked, namely fracturing construction parameters are optimized from 'synergy' (namely the economic effect of fracturing construction), and the aim of 'cost reduction' (namely the reduction of shale gas development cost) is weakened.
Disclosure of Invention
The invention mainly aims to provide a shale gas formation fracturing construction parameter optimization method, and aims to provide a shale gas formation fracturing construction parameter optimization method.
In order to achieve the aim, the invention provides a shale gas formation fracturing construction parameter optimization method which is characterized by comprising the following steps:
s1, obtaining geological parameters, physical parameters and fracturing design parameters of a reservoir stratum of a shale fracturing block;
s2, establishing a shale gas horizontal well subsection multi-cluster fracturing complex fracture network dynamic expansion model;
s3, establishing a single-well yield calculation model after shale gas horizontal well fracturing modification according to the geological parameters, fracturing design parameters and fractured fracture geometrical parameters obtained by the fracture network dynamic expansion model;
s4, establishing a shale gas horizontal well subsection multi-cluster fracturing reconstruction cost calculation model based on the cost required by each project of horizontal well fracturing reconstruction;
and S5, calculating the net current value of the production of the shale gas horizontal well after fracturing modification under different fracturing design parameters by combining the fracture network dynamic expansion model, the single well yield calculation model and the fracturing modification cost calculation model, and optimizing the fracturing design parameters by using the maximum net current value.
Preferably, the geological parameters include: horizontal maximum principal stress, horizontal minimum principal stress, stress difference between reservoir and barrier, reservoir stress gradient, rock tensile strength, young's modulus, poisson's ratio, rock compressibility, rock density, matrix permeability, matrix porosity, gas saturation, reservoir pressure coefficient, reservoir temperature, reservoir thickness, natural fracture length, natural fracture azimuth, natural fracture shear strength, natural fracture wall friction coefficient, natural fracture porosity, natural fracture permeability;
the fracture design parameters include: cluster spacing, perforation cluster number, perforation diameter, perforation number, construction discharge capacity, fracturing fluid viscosity and construction scale.
Preferably, the S2 specifically includes:
s21, establishing a relation between crack propagation stress and displacement based on a boundary element method;
s22, considering the condition that a plurality of hydraulic fractures are expanded simultaneously, and obtaining a composite stress field of any point in a fracture dynamic expansion reservoir according to a stress superposition principle under the action of induced stress among the fractures to obtain an induced stress field calculation model;
s23, regarding the fracturing fluid as an incompressible Newtonian fluid, considering the flow of the fracturing fluid in a horizontal shaft, a perforation hole and a fracturing fracture and the fluid loss effect of the fracturing fluid, and establishing a horizontal well segmented multi-cluster fracturing flow dynamic distribution model by adopting a Newtonian iteration method based on a pressure balance principle and a substance conservation principle;
s24, considering a composite failure mode of tension and shear of the crack, selecting a tip critical energy release rate criterion as a crack expansion rule, calculating the expansion direction of the crack according to a maximum tensile stress criterion, considering non-uniform expansion, correcting the multi-crack expansion step length, and establishing a multi-crack expansion step length and expansion direction calculation model;
s25, considering the influence of natural fractures developed in a shale reservoir on the expansion of the hydraulic fractures, wherein the hydraulic fractures can penetrate through the natural fractures and turn along the natural fractures, and the like, and simultaneously considering the filtration loss of fracturing fluid into the natural fractures, and establishing an intersection model of the hydraulic fractures and the natural fractures based on an empirical analytical formula;
and S26, coupling according to the relation between stress and displacement in the step S21, the induced stress field calculation model in the step S22, the fracturing fluid flowing field in the step S23 to form a fracture expansion fluid-solid full coupling model, combining the expansion criterion in the step S24 and the intersection criterion in the step S25 to form a fracture field model, and combining the fluid-solid full coupling model and the fracture field model to form a horizontal well subsection multi-cluster fracturing complex fracture network dynamic expansion model.
Preferably, when the connection between the fracture propagation stress and the displacement is established based on the boundary element method:
in the formula: u. of i Represents the normal displacement of the crack element i; v. of i Represents the tangential displacement of the crack element i; sigma j Represents the normal stress of the crack element j; tau. j Represents the fracture cell j tangential stress; a. The ij Representing a stress boundary influence coefficient matrix; g ij Representing a matrix of crack height correction coefficients, G, when the three-dimensional crack propagates ij Is an identity matrix;
the induced stress field calculation model is as follows:
in the formula: subscripts x and y indicate directions;
representing the induced stress field of the crack unit j acting on the crack unit i; g ij Indicating a crack height correction factor, G, when the three-dimensional crack propagates ij Has a value of 1; c ij Representing a displacement boundary influence coefficient;
representing the influence coefficient of the normal displacement of the crack unit j along the x direction on the positive stress of the crack unit i along the x direction;
representing positive stress in x-direction of a cracked cell i by tangential displacement of the cracked cell j in y-directionAn influence coefficient;
representing the influence coefficient of the normal displacement of the crack unit j along the x direction on the positive stress of the crack unit i along the y direction;
representing the influence coefficient of the normal displacement of the crack unit j along the y direction on the positive stress of the crack unit i along the y direction;
representing the influence coefficient of the normal displacement of the crack unit j along the x direction on the tangential stress of the crack unit i;
representing the influence coefficient of the normal displacement of the crack unit j along the y direction on the tangential stress of the crack unit i；u j And v j Respectively representing the normal displacement and the tangential displacement of the crack unit j;
the staged multi-cluster fracturing flow dynamic distribution model of the horizontal well comprises the following steps:
wherein t represents a fracturing time; x represents a position; a represents the cross-sectional area of the hydraulic fracture; q represents the fracturing fluid flow; q. q.s leak Representing the fluid loss rate of the fracturing fluid; p is a radical of formula Bottom Representing horizontal well heel bottom hole fluid pressure; p is a radical of well,i Representing the well bore friction between the heel of the horizontal well and the ith perforation cluster; p is a radical of p,i Representing perforation friction resistance of the ith perforation cluster; p is a radical of f,i Representing the inlet fluid pressure of the ith cluster of fractures;
the calculation model of the multi-crack expansion step length and the expansion direction is as follows:
in the formula, alpha represents a half value of the maximum crack propagation step; Δ x i Representing the expansion step of the ith fracture tip; g f,i Representing the maximum energy release rate of the ith fracture tip; g f Representing a fracture tip maximum energy release rate matrix; g critical Representing the critical energy release rate of crack tip propagation; beta is a crack propagation deflection angle; k Ι Represents a type I stress intensity factor; k is ∏ Representing a type II stress intensity factor; e represents Young's modulus; v represents the poisson's ratio;
the intersection model of the hydraulic fracture and the natural fracture is as follows:
in the formula, σ nf And τ nf Representing normal and tangential stress components for the natural fracture wall from a composite stress contribution of the in situ stress combined with the induced stress; mu.s nf Representing the friction coefficient of the wall surface of the natural crack; sigma h Represents the horizontal minimum principal stress; tau is 0 Representing the natural fracture shear strength; p is a radical of nf Representing fluid pressure within the natural fracture; t is a unit of rock Representing the tensile strength of the rock.
Preferably, the S3 specifically includes:
s31, according to reservoir geological parameters and physical parameters of a shale gas horizontal well staged multi-cluster fracturing complex fracture network dynamic expansion model, establishing a shale gas horizontal well fracturing modified single-well production geological physical model by combining fractured geometrical parameters obtained by calculation;
and S32, guiding the single-well production geological physical model after the shale gas horizontal well is fractured and transformed into an oil and gas reservoir numerical simulation software CMG, constructing a single-well yield calculation model after the shale gas horizontal well is fractured and transformed, and calculating the change of shale reservoir pressure and gas saturation along with time and the single-well accumulated gas yield under different production systems according to the single-well yield calculation model after the shale gas horizontal well is fractured and transformed.
Preferably, the S4 specifically includes:
considering material cost, tool cost and construction labor cost required by horizontal well fracturing modification, establishing a shale gas horizontal well subsection multi-cluster fracturing modification cost calculation model:
in the formula, G all Representing the total fracturing modification cost of the shale gas single-well horizontal well; m represents the total fracturing modification stage number; g fluid,i Representing the cost of the fracturing fluid for the i stage fracturing; g prop,i Represents proppant cost for the i-th stage fracture; g is a radical of formula tool,i Represents the tool cost of the i-th stage fracture; g work,i Representing the project cost of the i-th stage fracturing; g is a radical of formula else,i Representing the additional cost of the i-th stage fracture.
Preferably, the S5 specifically includes:
s51, obtaining natural gas sales based on the benefits of the shale reservoir after fracturing modification, and establishing a sales income calculation model;
s52, carrying out economic evaluation on fracturing modification of the shale gas horizontal well by adopting a net present value method, and establishing a mining net present value calculation model;
s53, establishing a relation between different construction parameters and shale gas exploitation net current value by combining a fracture network dynamic expansion model, a single well yield calculation model, a fracturing modification cost calculation model and an exploitation net current value calculation model to obtain the maximum net current value as an optimization target, establishing a shale gas formation fracturing construction parameter optimization model, and combining the construction parameters corresponding to the maximum net current value as an optimization result.
Preferably, the sales revenue calculation model is:
in the formula, G in Representing the total revenue of natural gas sales within one year; c gas,i The natural gas price of the ith day after the shale gas well fracturing reformation starts to produce is represented; v gas,i And indicating the gas production on the ith day after the shale gas well fracturing reformation starts to be produced.
Preferably, the net present value calculation model is:
in the formula, NPV represents the net present value; t represents time; (G) in -G out ) Indicating a cash flow for year t; e represents the annual percentage of discount.
The shale gas formation fracturing construction parameter optimization method provided by the invention has the following beneficial effects:
1. the complex seam network dynamic expansion model in the optimization method is suitable for two-dimensional, three-dimensional simulation and three-dimensional fracture expansion simulation, and is selected according to requirements;
2. the complex gap network dynamic expansion model in the optimization method can realize multi-crack induced stress calculation, multi-cluster flow dynamic distribution calculation and complex gap network dynamic expansion simulation;
3. the single-well yield calculation model in the optimization method can calculate reservoir pressure, stress and gas saturation under various production systems after the shale reservoir is laminated;
4. by applying the optimization method, a plurality of processes of crack expansion, seepage after pressing and economic evaluation are integrated, and construction parameters such as pump injection displacement, liquid quantity scale and the like can be optimized, so that the maximum shale gas development economic benefit is obtained, and the condition that the construction cost is higher than the fracturing effect and is poor due to blind increase of the fracturing scale is avoided;
5. the method fully combines crack propagation and post-fracturing seepage, optimizes fracturing construction parameters in an economic evaluation mode, gives consideration to cost reduction and synergy, is reliable in principle, has operability and accuracy, and can optimize the fracturing construction parameters of the shale gas horizontal well in a whole well section on the premise of giving basic parameters.
Drawings
FIG. 1 is a schematic flow chart of a shale gas formation fracturing construction parameter optimization method of the present invention;
FIG. 2 is a schematic diagram of a complex seam network expansion trajectory obtained by simulation of scheme 1 in Table 2;
FIG. 3 is a schematic diagram of the complex seam net expansion trajectory planned by scheme 2 in Table 2;
FIG. 4 is a schematic diagram of the complex seam-net expansion trajectory proposed by scheme 3 in Table 2;
FIG. 5 is a schematic diagram of a complex seam-net expansion trajectory planned by scheme 4 in Table 2;
FIG. 6 is a schematic diagram of a geological physical model for calculating the yield of a rock gas well in the shale gas formation fracturing construction parameter optimization method;
FIG. 7 is a schematic diagram of a shale gas-hydraulic fracturing plane fracture model in CMG software;
FIG. 8 is a schematic diagram of a reservoir gas saturation profile 3 years after production in scenario 1;
FIG. 9 is a schematic representation of a 3 year old reservoir gas saturation profile from scenario 2 simulation;
FIG. 10 is a schematic representation of scenario 4 after 3 years of production to obtain a reservoir gas saturation profile;
FIG. 11 is a schematic representation of scenario 5 after 3 years of production for a reservoir gas saturation profile;
FIG. 12 is a schematic diagram of the variation curve of the cumulative gas production of a single well under different schemes.
The implementation, functional features and advantages of the present invention will be further described with reference to the accompanying drawings.
Detailed Description
It should be understood that the specific embodiments described herein are merely illustrative of the invention and are not intended to limit the invention.
It should be noted that in the description of the present invention, the terms "lateral", "longitudinal", "upper", "lower", "front", "rear", "left", "right", "vertical", "horizontal", "top", "bottom", "inner", "outer", etc. indicate orientations or positional relationships based on those shown in the drawings, and are only for convenience of description and simplicity of description, and do not indicate or imply that the referred device or element must have a specific orientation, be constructed and operated in a specific orientation, and thus, should not be construed as limiting the present invention. Furthermore, the terms "first," "second," and the like are used for descriptive purposes only and are not to be construed as indicating or implying relative importance.
Referring to fig. 1, the invention provides a shale gas formation fracturing construction parameter optimization method, which comprises the following steps:
s1, obtaining geological parameters, physical parameters and fracturing design parameters of a reservoir stratum of a shale fracturing block;
s2, establishing a shale gas horizontal well subsection multi-cluster fracturing complex fracture network dynamic expansion model according to geological parameters and fracturing design parameters;
s3, establishing a single-well yield calculation model after fracturing transformation of the shale gas horizontal well according to geological parameters, physical parameters, fracturing design parameters and fractured fracture geometrical parameters obtained by the fracture network dynamic expansion model;
s4, establishing a shale gas horizontal well subsection multi-cluster fracturing reconstruction cost calculation model based on the cost required by each project of horizontal well fracturing reconstruction;
and S5, calculating the net current value of the production of the shale gas horizontal well after fracturing modification under different construction parameters by combining the fracture network dynamic expansion model, the single well yield calculation model and the fracturing modification cost calculation model, and optimizing the fracturing construction parameters by using the maximum net current value.
In particular, the geological parameters include: horizontal maximum principal stress, horizontal minimum principal stress, stress difference between reservoir and barrier, reservoir stress gradient, rock tensile strength, young's modulus, poisson's ratio, rock compressibility, rock density, matrix permeability, matrix porosity, gas saturation, reservoir pressure coefficient, reservoir temperature, reservoir thickness, natural fracture length, natural fracture azimuth, natural fracture shear strength, natural fracture wall friction coefficient, natural fracture porosity, natural fracture permeability;
fracture design parameters include: cluster spacing, perforation cluster number, perforation diameter, perforation number, construction discharge capacity, fracturing fluid viscosity and construction scale.
The step S2 specifically includes:
s21, establishing a relation between crack propagation stress and displacement based on a boundary element method;
s22, considering the condition that a plurality of hydraulic fractures are expanded simultaneously, and obtaining a composite stress field of any point in a dynamic fracture expansion reservoir according to a stress superposition principle under the action of induced stress among the fractures to obtain an induced stress field calculation model;
s23, regarding the fracturing fluid as an incompressible Newtonian fluid, considering the flow of the fracturing fluid in a horizontal shaft, a perforation hole and a fracturing fracture and the fluid loss effect of the fracturing fluid, and establishing a horizontal well segmented multi-cluster fracturing flow dynamic distribution model by adopting a Newtonian iteration method based on a pressure balance principle and a substance conservation principle;
s24, considering a composite failure mode of tension and shear of the crack, selecting a tip critical energy release rate criterion as a crack expansion rule, calculating the expansion direction of the crack according to a maximum tensile stress criterion, considering non-uniform expansion, correcting the multi-crack expansion step length, and establishing a multi-crack expansion step length and expansion direction calculation model;
s25, considering the influence of natural fractures developed in a shale reservoir on the expansion of the hydraulic fractures, wherein the hydraulic fractures can penetrate through the natural fractures and turn along the natural fractures, and the like, and simultaneously considering the filtration loss of fracturing fluid into the natural fractures, and establishing an intersection model of the hydraulic fractures and the natural fractures based on an empirical analytical formula;
and S26, coupling the fracturing fluid flow field (the fracturing fluid flow field is calculated according to the horizontal well subsection multi-cluster fracturing flow dynamic distribution model) obtained according to the relation between stress and displacement in the step S21, the induced stress field calculation model in the step S22 and the horizontal well subsection multi-cluster fracturing flow dynamic distribution model in the step S23 to form a crack extension flow-solid fully-coupled model, combining the multi-crack extension step length and extension direction calculation model in the step S24 and the hydraulic crack and natural crack intersection model in the step S25 to form a fracture field model, and combining the flow-solid fully-coupled model and the fracture field model to form the horizontal well subsection multi-cluster fracturing complex fracture network dynamic extension model.
Specifically, a horizontal well subsection multi-cluster fracturing flow dynamic distribution model belongs to a part of fracturing fluid flow field calculation. The fracture propagation fluid-solid full coupling model = induced stress field calculation model + fracturing fluid flow field. The fracture expansion fluid-solid fully-coupled model comprises a horizontal well subsection multi-cluster fracturing flow dynamic distribution model.
In S21, when the relation between the crack propagation stress and the displacement is established based on the boundary element method:
in the formula: u. of i Represents the normal displacement of the crack element i; v. of i Represents the tangential displacement of the crack element i; sigma j Represents the normal stress of the crack element j; tau. j Represents the fracture cell j tangential stress; a. The ij Representing a stress boundary influence coefficient matrix; g ij Represents a seam height correction coefficient matrix, G, when the three-dimensional seam propagates ij Is an identity matrix;
in S22, the induced stress field calculation model is:
in the formula: subscripts x and y indicate direction;
representing the induced stress field of the crack unit j acting on the crack unit i; g ij Indicating a crack height correction factor, G, when the three-dimensional crack propagates ij Has a value of 1; c ij The displacement boundary influence coefficient is represented by,
representThe influence coefficient of the normal displacement of the crack unit j along the x direction on the normal stress of the crack unit i along the x direction;
representing the influence coefficient of the tangential displacement of the crack unit j along the y direction on the positive stress of the crack unit i along the x direction;
representing the influence coefficient of the normal displacement of the crack unit j along the x direction on the positive stress of the crack unit i along the y direction;
representing the influence coefficient of the normal displacement of the crack unit j along the y direction on the positive stress of the crack unit i along the y direction;
representing the influence coefficient of the normal displacement of the crack unit j along the x direction on the tangential stress of the crack unit i;
representing the influence coefficient of the normal displacement of the crack unit j along the y direction on the tangential stress of the crack unit i; u. u j And v j Respectively representing the normal displacement and the tangential displacement of the crack unit j;
in S23, the staged multi-cluster fracturing flow dynamic distribution model of the horizontal well is as follows:
wherein t represents the fracturing time; x represents a position; a represents the hydraulic fracture cross-sectional area; q represents the fracturing fluid flow; q. q.s leak Representing the fluid loss rate of the fracturing fluid; p is a radical of Bottom Representing horizontal well heel bottom hole fluid pressure; p is a radical of well,i Representing the friction resistance of the shaft between the heel part of the horizontal well and the ith perforation cluster; p is a radical of p,i Representing the friction of perforation holes of the ith perforation cluster; p is a radical of f,i Representing the inlet fluid pressure of the ith cluster of fractures;
in S24, the multi-fracture propagation step length and propagation direction calculation model is:
wherein, alpha represents the half value of the maximum crack propagation step; Δ x i Representing the expansion step of the ith fracture tip; g f,i Representing the maximum energy release rate of the ith fracture tip; g f Representing a fracture tip maximum energy release rate matrix; g critical Representing the critical energy release rate of crack tip propagation; beta is a crack propagation deflection angle; k Ι Represents a type I stress intensity factor; k ∏ Representing a type II stress intensity factor; e represents Young's modulus; v represents the poisson's ratio;
in S25, the intersection model of the hydraulic fracture and the natural fracture is as follows:
in the formula, σ nf And τ nf Representing normal and tangential stress components for the natural fracture wall from a composite stress contribution of the in situ stress combined with the induced stress; mu.s nf Representing the friction coefficient of the wall surface of the natural crack; sigma h Represents the horizontal minimum principal stress; tau is 0 Representing the natural fracture shear strength; p is a radical of nf Representing fluid pressure within the natural fracture; t is rock Representing the tensile strength of the rock.
Step S3 specifically includes:
s31, according to reservoir geological parameters and physical parameters of a shale gas horizontal well staged multi-cluster fracturing complex fracture network dynamic expansion model, establishing a shale gas horizontal well fracturing modified single-well production geological physical model by combining fractured geometrical parameters obtained by calculation;
and S32, guiding the single-well production geological physical model after the shale gas horizontal well is fractured and transformed into an oil and gas reservoir numerical simulation software CMG, constructing a single-well yield calculation model after the shale gas horizontal well is fractured and transformed, and calculating the change of shale reservoir pressure and gas saturation along with time and the single-well accumulated gas yield under different production systems according to the single-well yield calculation model after the shale gas horizontal well is fractured and transformed.
Step S4 specifically includes:
considering material cost, tool cost and construction labor cost required by horizontal well fracturing modification, establishing a shale gas horizontal well subsection multi-cluster fracturing modification cost calculation model:
in the formula, G all Representing the total cost of fracturing modification of a shale gas single-well horizontal well; m represents the total pressure cracking modification stage number; g fluid,i Representing the cost of the fracturing fluid for the i stage fracturing; g is a radical of formula prop,i Represents proppant cost for the i-th stage fracture; g tool,i Representing the tool cost of the i-th stage fracturing, such as bridge plugs, perforating bullets, temporary plugging balls, pump truck groups and the like; g work,i Representing the engineering cost of the i-th stage fracturing, such as perforation, fracturing and the like; g is a radical of formula else,i Representing other costs of the i-th fracture, such as workover operations, etc.
Step S5 specifically includes:
s51, obtaining natural gas sales based on the benefits of the shale reservoir after fracturing modification, and establishing a sales income calculation model;
s52, carrying out economic evaluation on fracturing modification of the shale gas horizontal well by adopting a net present value method, and establishing a mining net present value calculation model;
s53, establishing a relation between different construction parameters and shale gas exploitation net current value by combining a fracture network dynamic expansion model, a single well yield calculation model, a fracturing modification cost calculation model and an exploitation net current value calculation model to obtain the maximum net current value as an optimization target, establishing a shale gas formation fracturing construction parameter optimization model, and combining the construction parameters corresponding to the maximum net current value as an optimization result.
Specifically, the sales revenue calculation model is:
in the formula, G in Representing the total revenue of natural gas sales within one year; c gas,i The natural gas price of the ith day after the shale gas well fracturing reformation starts to produce is represented; v gas,i And indicating the gas production on the ith day after the shale gas well fracturing reformation starts to be produced.
Specifically, the net present value of mining calculation model is:
in the formula, NPV represents the net present value; t represents time; (G) in -G out ) Indicating a cash flow for year t; e represents the annual percentage of discount.
The following description is given with reference to a specific embodiment.
S1, collecting reservoir geological parameters and fracturing design parameters of a shale fracturing block.
In order to fit the model result with the engineering practice, basic parameters required by complex seam network expansion simulation and pressed single well yield calculation need to use field data. In this embodiment, the collected reservoir geological parameters and fracturing design parameters are shown in table 1, the method can perform optimization of single construction factor or multiple construction factors, the optimization of parameters of construction displacement is specifically described in this embodiment, and several preliminary optimization schemes are shown in table 2.
TABLE 1 reservoir geological parameters and fracturing design parameters
TABLE 2 optimization scheme of construction displacement
| | Scheme | 1 | |
|
|
| Construction displacement | 12m 3 /min | 14m 3 /min | 16m 3 /min | 18m 3 /min |
In the step S2, substituting the construction displacement parameters in the tables 1 and 2 into a horizontal well subsection multi-cluster fracturing complex fracture network dynamic expansion model, wherein the fracture-making liquid amount is 500m 3 Total fracturing fluid amount 2000m 3 And calculating to obtain the fracture geometric parameters, wherein the number of the fracture clusters is 6, and the using amount of the propping agent is 110 t. FIGS. 2 to 5 are crack propagation trajectories calculated in scheme 1, scheme 2, scheme 3 and scheme 4, respectively, wherein the average crack length, average crack height and average crack width of scheme 1 are 188m, 33.3m and 3.1mm, respectively; the average seam length, the average seam height and the average seam width of the scheme 2 are respectively 208m, 33.1m and 3.0mm; the average seam length, the average seam height and the average seam width of the scheme 3 are 228 mm, 33.6 mm and 2.4mm respectively; scheme 4The average seam length, average seam height and average seam width are respectively 202 mm, 32.8 mm and 3.3mm. As can be seen from FIGS. 2 to 5, the displacement is 16m 3 At/min, the resulting slotted mesh structure is more complex.
And S3, establishing a single-well yield calculation model after fracturing reformation of the shale gas horizontal well.
(1) According to reservoir geological parameters and physical parameters of the shale gas horizontal well staged multi-cluster fracturing complex fracture network in the table 1, fracture geometrical parameters after fracturing such as a scheme 1, a scheme 3 and a scheme 4 are obtained through calculation by combining the shale gas horizontal well staged multi-cluster fracturing complex fracture network dynamic expansion model in the step S2, a geological physical model of single well production after shale gas horizontal well fracturing modification is established, and a model schematic diagram is shown in FIG. 6.
(2) And (3) leading the single-well production geological physical model after the shale gas horizontal well fracturing transformation into IMEX black oil and a non-scale simulator in oil-gas reservoir numerical simulation software CMG, and constructing a single-well production calculation model after the shale gas horizontal well fracturing transformation. In this embodiment, first, an IMEX simulator of the client in the CMG software is started, a DUALPERM double-permeability model is selected, the established single-well production geologic physical model is subjected to grid division by combining with the reservoir parameters in table 1, component data, phase permeability data and gas phase adsorption data are set, and the model is initialized. Then, in this embodiment, the horizontal section length of the horizontal well of the shale gas production well is 1200m, the section length of the fracturing section is 60m, and 20 sections are summed up, and then a shale gas hydraulic fracturing plane fracture model is established in the IMEX simulator, as shown in fig. 7. And finally, importing the model established by the Buider into an IMEX simulator for calculation to obtain the change of shale reservoir pressure and gas saturation along with time and the accumulated gas production rate of a single well under different production systems.
In this embodiment, fig. 8 to 11 are gas saturation distribution diagrams of the reservoir after 3 years of constant pressure production calculated by the scheme 1, the scheme 2, the scheme 3 and the scheme 4, respectively, and fig. 12 is a single well cumulative gas production rate change curve under different schemes. It can be seen that the cumulative yield for scenario 3 is higher.
And S4, establishing a shale gas horizontal well subsection multi-cluster fracturing reconstruction cost calculation model.
Comprehensively considering material cost, tool cost and construction labor cost required by horizontal well fracturing modification, establishing a shale gas horizontal well subsection multi-cluster fracturing modification cost calculation model:
in the embodiment, the horizontal section of the horizontal well 1 is 1200m, the section of the fracturing section is 60m, and the liquid consumption of a single section is 2000m 3 The using amount of the propping agent is 110t, the average cost of the single-stage liquid is 4.7 ten thousand yuan, the average cost of the single-stage propping agent is 18.5 ten thousand yuan, the average engineering cost of the single-stage fracturing construction is 70.5 ten thousand yuan, the tool cost of the single stage is 15.5 ten thousand yuan, the total single well gas testing cost is about 108 ten thousand yuan, and the total fracturing modification cost of the shale gas single-well horizontal well is 2292 ten thousand yuan.
S5, calculating the net current value of the shale gas horizontal well after fracturing transformation under different construction parameters, and optimizing fracturing construction parameters by using the maximum net current value.
In this embodiment, the shale gas yield after 2 years of constant pressure production under different schemes is obtained according to simulation calculation, for simplification of calculation, the average value of the daily natural gas price is 2.2 yuan/square, and the net present value of the shale gas well after 2 years of production under different schemes is obtained by calculation in combination with a sales income calculation model and a net present value calculation model, and the result is shown in table 3.
TABLE 3 net present value calculation results for different scenarios
| | Scheme | 1 | |
|
|
| Construction displacement | 12m 3 /min | 14m 3 /min | 16m 3 /min | 18m 3 /min | |
| Average seam length | 188m | 208m | 228m | 202m | |
| Mean seam height | 33.3m | 33.1m | 33.6m | 32.8m | |
| Average seam width | 3.1mm | 3.0mm | 2.4mm | 3.3mm | |
| Cumulative gas production (2 years) | 2097×10 4 m 3 | 2191×10 4 m 3 | 2512×10 4 m 3 | 2210×10 4 m 3 | |
| Marketing of natural gas | 4634.37 ten thousand yuan | 4842.11 ten thousand yuan | 5551.52 ten thousand yuan | 4884.1 ten thousand yuan | |
| NPV | 2342.37 ten thousand yuan | 2550.11 ten thousand yuan | 3259.52 ten thousand yuan | 2592.1 ten thousand yuan |
After establishing the relation between different construction parameters and the shale gas exploitation net current value, the calculation results in the table 3 show that different construction discharge volumes influence the yield of the shale gas well by influencing the complex structure of the fracture network and the geometric parameters of the fracture. In this embodiment, the maximum net present value is used as an optimization target to optimize the construction parameters, and the optimized construction displacement scheme 3 is that the construction displacement is 16m 3 And/min, the hydraulic fractures can communicate with the natural fractures to the maximum extent under the discharge capacity to form a fracture network with higher complexity, the reservoir productivity can be effectively released, and higher economic benefit can be obtained.
The shale gas formation fracturing construction parameter optimization method provided by the embodiment has the following beneficial effects:
1. the complex seam network dynamic expansion model in the optimization method is suitable for two-dimensional, quasi-three-dimensional and three-dimensional crack expansion simulation, and is selected according to requirements;
2. the complex gap network dynamic expansion model in the optimization method can realize multi-crack induced stress calculation, multi-cluster flow dynamic distribution calculation and complex gap network dynamic expansion simulation;
3. the single-well yield calculation model in the optimization method can calculate reservoir pressure, stress and gas saturation under various production systems after the shale reservoir is laminated, and the model accuracy is high;
4. by applying the optimization method, a plurality of processes of crack expansion, post-fracturing seepage and economic evaluation are integrated, and construction parameters such as pump injection displacement, liquid quantity scale and the like can be optimized, so that the maximum shale gas development economic benefit is obtained, and the conditions of high construction cost and unsatisfactory fracturing effect caused by blind increase of fracturing scale are avoided;
5. the method fully combines crack propagation and post-fracturing seepage, optimizes fracturing construction parameters in an economic evaluation mode, gives consideration to cost reduction and synergy, is reliable in principle, has operability and accuracy, and can optimize the fracturing construction parameters of the shale gas horizontal well in a whole well section on the premise of giving basic parameters.
The above description is only for the preferred embodiment of the present invention and is not intended to limit the scope of the present invention, and all equivalent structural changes made by using the contents of the present specification and the drawings, or any other related technical fields, are intended to be covered by the scope of the present invention.
Claims (9)
1. The shale gas formation fracturing construction parameter optimization method is characterized by comprising the following steps of:
s1, acquiring geological parameters, physical parameters and fracturing design parameters of a reservoir stratum of a shale fracturing block;
s2, establishing a shale gas horizontal well subsection multi-cluster fracturing complex fracture network dynamic expansion model;
s3, establishing a single-well yield calculation model after shale gas horizontal well fracturing modification according to the geological parameters, fracturing design parameters and fractured fracture geometrical parameters obtained by the fracture network dynamic expansion model;
s4, establishing a shale gas horizontal well subsection multi-cluster fracturing reconstruction cost calculation model based on the cost required by each project of horizontal well fracturing reconstruction;
and S5, calculating the net current value of the production of the shale gas horizontal well after fracturing modification under different fracturing design parameters by combining the fracture network dynamic expansion model, the single well yield calculation model and the fracturing modification cost calculation model, and optimizing the fracturing design parameters by using the maximum net current value.
2. The shale gas formation fracturing construction parameter optimization method of claim 1, wherein the geological parameters comprise: horizontal maximum principal stress, horizontal minimum principal stress, stress difference between reservoir and barrier, reservoir stress gradient, rock tensile strength, young's modulus, poisson's ratio, rock compressibility, rock density, matrix permeability, matrix porosity, gas saturation, reservoir pressure coefficient, reservoir temperature, reservoir thickness, natural fracture length, natural fracture azimuth, natural fracture shear strength, natural fracture wall friction coefficient, natural fracture porosity, natural fracture permeability;
the fracture design parameters include: cluster spacing, perforation cluster number, perforation diameter, perforation number, construction discharge capacity, fracturing fluid viscosity and construction scale.
3. The shale gas formation fracturing construction parameter optimization method of claim 1, wherein the S2 specifically comprises:
s21, establishing a relation between crack propagation stress and displacement based on a boundary element method;
s22, considering the condition that a plurality of hydraulic fractures are expanded simultaneously, and obtaining a composite stress field of any point in a dynamic fracture expansion reservoir according to a stress superposition principle under the action of induced stress among the fractures to obtain an induced stress field calculation model;
s23, regarding the fracturing fluid as an incompressible Newtonian fluid, considering the flow of the fracturing fluid in a horizontal shaft, a perforation hole and a fracturing fracture and the fluid loss effect of the fracturing fluid, and establishing a horizontal well segmented multi-cluster fracturing flow dynamic distribution model by adopting a Newtonian iteration method based on a pressure balance principle and a substance conservation principle;
s24, considering a composite failure mode of tension and shear of the crack, selecting a tip critical energy release rate criterion as a crack expansion rule, calculating the expansion direction of the crack according to a maximum tensile stress criterion, considering non-uniform expansion, correcting the multi-crack expansion step length, and establishing a multi-crack expansion step length and expansion direction calculation model;
s25, considering the influence of natural fractures developed in a shale reservoir on the expansion of the hydraulic fractures, wherein the hydraulic fractures can penetrate through the natural fractures and turn along the natural fractures, and the like, and simultaneously considering the filtration loss of fracturing fluid into the natural fractures, and establishing an intersection model of the hydraulic fractures and the natural fractures based on an empirical analytical formula;
s26, coupling according to the relation between stress and displacement in the step S21, the induced stress field calculation model in the step S22, the fracturing fluid flowing field in the step S23 to form a fracture expansion fluid-solid fully-coupled model, combining the expansion criterion in the step S24 and the intersection criterion in the step S25 to form a fracture field model, and combining the fluid-solid fully-coupled model and the fracture field model to form a horizontal well segmented multi-cluster fracturing complex fracture network dynamic expansion model.
4. The shale gas formation fracturing construction parameter optimization method of claim 3, wherein when establishing the connection between fracture propagation stress and displacement based on the boundary element method:
in the formula: u. u i Represents the normal displacement of the crack element i; v. of i Represents the tangential displacement of the crack element i; sigma j Represents the normal stress of the crack element j; tau is j Represents the fracture cell j tangential stress; a. The ij Representing a stress boundary influence coefficient matrix; g ij Representing a matrix of crack height correction coefficients, G, when the three-dimensional crack propagates ij Is an identity matrix;
the induced stress field calculation model is as follows:
in the formula: subscripts x and y indicate direction;
representing the induced stress field of the crack unit j acting on the crack unit i; g ij Represents the crack height correction factor, G, when the three-dimensional crack propagates ij Has a value of 1; c ij Representing a displacement boundary influence coefficient;
representing the influence coefficient of the normal displacement of the crack unit j along the x direction on the positive stress of the crack unit i along the x direction;
representing the influence coefficient of the tangential displacement of the crack unit j along the y direction on the positive stress of the crack unit i along the x direction;
representing the influence coefficient of the normal displacement of the crack unit j along the x direction on the positive stress of the crack unit i along the y direction;
representing the influence coefficient of the normal displacement of the crack unit j along the y direction on the positive stress of the crack unit i along the y direction;
representing the influence coefficient of the normal displacement of the crack unit j along the x direction on the tangential stress of the crack unit i;
representing the influence coefficient of the normal displacement of the crack unit j along the y direction on the tangential stress of the crack unit i; u. of j And v j Respectively represents the normal displacement of a crack unit j andtangential displacement;
the staged multi-cluster fracturing flow dynamic distribution model of the horizontal well comprises the following steps:
wherein t represents the fracturing time; x represents a position; a represents the hydraulic fracture cross-sectional area; q represents the fracturing fluid flow; q. q.s leak Representing the fluid loss rate of the fracturing fluid; p is a radical of Bottom Representing horizontal well heel bottom hole fluid pressure; p is a radical of well,i Representing the well bore friction between the heel of the horizontal well and the ith perforation cluster; p is a radical of p,i Representing perforation friction resistance of the ith perforation cluster; p is a radical of f,i Representing the inlet fluid pressure of the ith cluster of fractures;
the calculation model of the multi-crack expansion step length and the expansion direction is as follows:
wherein, alpha represents the half value of the maximum crack propagation step; Δ x i Representing the expansion step of the ith fracture tip; g f,i Represents the maximum energy release rate of the ith fracture tip; g f Representing a fracture tip maximum energy release rate matrix; g critical Representing the critical energy release rate of crack tip propagation; beta is a crack propagation deflection angle; k Ι Represents a type I stress intensity factor; k is ∏ Represents a type II stress intensity factor; e represents Young's modulus; v represents the poisson's ratio;
the intersection model of the hydraulic fracture and the natural fracture is as follows:
in the formula, σ nf Representing a normal stress component for the natural fracture wall from a composite stress contribution of the in situ stress combined with the induced stress; tau is nf Representing a tangential stress component for the natural fracture wall from a composite stress contribution of the in situ stress combined with the induced stress; mu.s nf Representing the friction coefficient of the wall surface of the natural crack; sigma h Represents the horizontal minimum principal stress; tau is 0 Representing the natural fracture shear strength; p is a radical of formula nf Representing fluid pressure within the natural fracture; t is rock Representing the tensile strength of the rock.
5. The shale gas formation fracturing construction parameter optimization method of claim 1, wherein the S3 specifically comprises:
s31, according to reservoir geological parameters and physical parameters of a shale fracturing modification block, combining with post-fracturing fracture geometric parameters obtained by calculation of a shale gas horizontal well subsection multi-cluster fracturing complex fracture network dynamic expansion model, and establishing a single-well production geological physical model after shale gas horizontal well fracturing modification;
and S32, guiding the single-well production geological physical model after the shale gas horizontal well is fractured and transformed into an oil and gas reservoir numerical simulation software CMG, constructing a single-well yield calculation model after the shale gas horizontal well is fractured and transformed, and calculating the change of shale reservoir pressure and gas saturation along with time and the single-well accumulated gas yield under different production systems according to the single-well yield calculation model after the shale gas horizontal well is fractured and transformed.
6. The shale gas formation fracturing construction parameter optimization method of claim 1, wherein the S4 specifically comprises:
considering material cost, tool cost and construction labor cost required by horizontal well fracturing modification, establishing a shale gas horizontal well subsection multi-cluster fracturing modification cost calculation model:
in the formula, G all Representing the total fracturing modification cost of the shale gas single-well horizontal well; m represents the total fracturing modification stage number; g fluid,i Representing the cost of the fracturing fluid for the i stage fracturing; g prop,i Represents the proppant cost of the i-th stage fracture; g tool,i Represents the tool cost of the i-th stage fracture; g is a radical of formula work,i Representing the project cost of the i-th stage fracturing; g else,i Representing the additional cost of the i-th stage fracture.
7. The shale gas formation fracturing construction parameter optimization method of any of claims 1 to 6, wherein the S5 specifically comprises:
s51, obtaining natural gas sales based on the benefits of the shale reservoir after fracturing modification, and establishing a sales income calculation model;
s52, carrying out economic evaluation on fracturing modification of the shale gas horizontal well by adopting a net present value method, and establishing a mining net present value calculation model;
s53, establishing a relation between different construction parameters and shale gas exploitation net current value by combining a fracture network dynamic expansion model, a single well yield calculation model, a fracturing modification cost calculation model and an exploitation net current value calculation model to obtain the maximum net current value as an optimization target, establishing a shale gas formation fracturing construction parameter optimization model, and combining the construction parameters corresponding to the maximum net current value as an optimization result.
8. The shale gas formation fracturing construction parameter optimization method of claim 7, wherein the sales revenue calculation model is:
in the formula, G in Representing the total income of natural gas sales within one year；C gas,i The natural gas price of the ith day after the shale gas well fracturing reformation starts to produce is represented; v gas,i And indicating the gas production on the ith day after the shale gas well fracturing reformation starts to be produced.
9. The shale gas formation fracturing construction parameter optimization method of claim 7, wherein the net present exploitation value calculation model is:
in the formula, NPV represents the net present value; t represents time; (G) in -G out ) Indicating a cash flow for year t; e represents the annual percentage of discount.
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| CN116415519A (en) * | 2023-03-09 | 2023-07-11 | 同济大学 | Shale gas reservoir multi-cluster hydraulic fracture synchronous competition expansion numerical simulation method and system |
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| CN117633409A (en) * | 2024-01-25 | 2024-03-01 | 中国科学院地质与地球物理研究所 | Method, system and equipment for calculating shale oil and gas reservoir fracture network seepage parameters |
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| CN116415519A (en) * | 2023-03-09 | 2023-07-11 | 同济大学 | Shale gas reservoir multi-cluster hydraulic fracture synchronous competition expansion numerical simulation method and system |
| CN116415519B (en) * | 2023-03-09 | 2024-03-12 | 同济大学 | Shale gas reservoir multi-cluster hydraulic fracture synchronous competition expansion numerical simulation method and system |
| CN116838308A (en) * | 2023-08-11 | 2023-10-03 | 同济大学 | Repeated fracturing process optimization method and system |
| CN117574755A (en) * | 2023-10-27 | 2024-02-20 | 中国石油大学(华东) | Hierarchical multistage optimization method for fracturing parameters of horizontal well of shale reservoir well factory |
| CN117574755B (en) * | 2023-10-27 | 2024-05-07 | 中国石油大学(华东) | Hierarchical multistage optimization method for fracturing parameters of horizontal well of shale reservoir well factory |
| CN117633409A (en) * | 2024-01-25 | 2024-03-01 | 中国科学院地质与地球物理研究所 | Method, system and equipment for calculating shale oil and gas reservoir fracture network seepage parameters |
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