CN109472037A - Shale gas reservoir man-made fracture parameter preferred method and system - Google Patents
Shale gas reservoir man-made fracture parameter preferred method and system Download PDFInfo
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Abstract
The invention discloses a kind of shale gas reservoir man-made fracture parameter preferred method and systems, comprising: stitches pessimistic concurrency control after establishing shale gas reservoir pressure；Determine the flow deformation coupled wave equation in matrix and crack；Establish productivity model after shale gas horizontal well pressure；The shale gas production capacity for calculating productivity model after pressing, turns to the preferred man-made fracture parameter of principle with production capacity maximum.The present invention provide it is a kind of consideration porous media deformation and Coupled with Flow shale gas reservoir fracturing improvement after Productivity, turning to principle with production capacity maximum can get optimal shale gas reservoir man-made fracture parameter combination.
Description
Technical field
The invention belongs to oil-gas field development fields, preferred more particularly, to a kind of shale gas reservoir man-made fracture parameter
Method and system.
Background technique
Shale gas reservoir generally requires the production that business exploitation could be formed using horizontal well and extensive hydraulic fracturing technology
Can, man-made fracture is interspersed with intrinsic fracture in reservoir and forms netted Fracture System after pressure break.Come with production capacity maximization
It is preferred that man-made fracture parameter is common method in FRACTURING DESIGN, and Complex Flows fracture is joined in accurate description fracture-type reservoir
Number design is most important.Currently used fracture-type reservoir numerical simulator is divided into two major classes: continuity dielectric model and from
Fractured model is dissipated, wherein continuity dielectric model includes diplopore list infiltration, the double infiltrations of diplopore, multi-dielectric model and equivalent medium mode
Deng.Continuity dielectric model is widely applied in fracture-type reservoir, but is only applicable to crack and is uniformly distributed and sends out very much
The reservoir educated, large error can be generated by developing general stratum model for local cracks.Noorishad and Mehra is proposed
It is a kind of while considering discrete fractures basement model (the Discrete Fracture that fluid flows in basement rock and crack
Model), need to be using unstructured grid and mesh refinement technology when grid division due to the complexity of fracture pattern, therefore it should
Model is suitable for crack non-uniform Distribution and the little reservoir of fracture spacing.
As pore pressure decline reservoir effective stress increases, reservoir rock matrix hole is caused to blend under fracture permeabgility
Drop, it is last to will affect the variation of pore pressure again, therefore how to describe matrix hole to blend fracture permeabgility variation to be that realization is accurate
Calculate the key of shale gas reservoir productivity.In shale gas numerical simulation for simplicity, matrix hole is usually blended crack to seep
The variation of saturating rate is converted into the function table of pore pressure or time, then imports in numerical model the explicit function relationship and carries out
AOF calculation.This method is feasible in the case where uniaxial strain and normal stress are assumed, but can not describe actual reservoir condition and flow down
Gu influence of the coupling effect to production.
In conclusion the prior art is mainly based upon simplified analytic solutions or diplopore to the calculating of production capacity after shale air pressure
Double infiltration numerical models, it is less for research of the discrete man-made fracture to pressure and yield effect, thus man-made fracture parameter optimization
Also lack tool.In terms of shale gas fluid structurecoupling research, for the stress sensitivity in shale matrix and crack frequently with theory
The processing method of pressure sensibility is modeled or is equivalent to, this method cannot really reflect the fluid structurecoupling in shale gas production process
Process.It is therefore desirable to provide a kind of shale gas reservoir man-made fracture parameter preferred method.
Summary of the invention
The present invention by provide it is a kind of consideration porous media deformation and Coupled with Flow shale gas reservoir fracturing improvement after produce
Energy calculation method, turns to principle with production capacity maximum and obtains optimal shale gas reservoir man-made fracture parameter combination.
According to an aspect of the invention, it is proposed that a kind of shale gas reservoir man-made fracture parameter preferred method, the method
It may include: to stitch pessimistic concurrency control after establishing shale gas reservoir pressure；Determine the flow deformation coupled wave equation in matrix and crack；Establish page
Productivity model after rock air water horizontal well pressure；The shale gas production capacity for calculating productivity model after the pressure, it is excellent to turn to principle with production capacity maximum
Work of choosing fracture parameters.
Preferably, pessimistic concurrency control is stitched after the pressure includes reservoir boundaries, horizontal wellbore, artificial major fracture and secondary fracture.
Preferably, the flow deformation coupled wave equation in the matrix and crack include: shale Medium Culture gas flow equation,
Fluid flows continuity equation in shale pore media deformation equation and crack.
Preferably, the shale Medium Culture gas flow equation indicates are as follows:
Wherein, αBFor Biot coefficient；P is pore pressure；μ is fluid viscosity；Z is Gas Compression Factor；M (p) is quasi- pressure
Power；εvFor bulk strain；M is Biot modulus,KgAnd KsRespectively represent the volume of gas and solid particle
Modulus；VLAnd PLRespectively represent Lang Gemiaoer volume and Lang Gemiaoer pressure；ρrRepresent shale density；T is the time；BgIt is stratum
Volume factor；QpFor source sink term；kaIt indicates to consider the apparent permeability that shale gas is slipped with transition flow；MgFor molecular weight gas；
T is gas temperature；R is gas molar constant.
Preferably, the shale pore media deformation equation indicates are as follows:
Wherein, u is displacement field；G is modulus of shearing；ν is Poisson's ratio；αBFor Biot coefficient；For plane problem [m]=
[1,1,0], for three-dimensional problem [m]=[1,1,1,0,0,0]；M (p) is pseudopressure；F is body force；μ is fluid viscosity；Z is
Gas Compression Factor.
Preferably, fluid flowing continuity equation indicates in the crack are as follows:
Wherein, SfFor crack packing coefficient；W is fracture width；V is fluid along crack boundary movement velocity；It is split for edge
The tangential divergence in seam face；P is pore pressure；ρgFor for fluid density；T is the time.
Preferably, the shale gas production capacity for calculating productivity model after the pressure includes:
1) based on the flow deformation coupling in the boundary and primary condition, the matrix and crack for stitching pessimistic concurrency control after the pressure
Equation obtains initial displacement field before carrying out incremental time calculating；
2) it is based on initial pressure field, displacement field and pressure field in each loop iteration step are calculated, according to the displacement
, parameter and fracture permeabgility are seeped in the hole for obtaining pore media；
3) pressure difference before and after loop iteration, if being unsatisfactory for the limits of error, repeatedly step 2) -3 are compared), it is no
Then, output unit node pressure and Gauss point stress calculate the shale gas production capacity；
4) judge calculate total time whether reach scheduled total time, if having reached scheduled total time, directly tie
Beam calculates, and otherwise, goes successively to next incremental time and is calculated, and repeats step 2) -4).
Preferably, the man-made fracture parameter includes: crack cluster spacing, grade spacing, half long, major fracture flow conductivity and secondary
Raw fracture condudtiviy.
According to another aspect of the invention, it is proposed that system described in a kind of shale gas reservoir man-made fracture parameter optimum decision system
Include: memory, is stored thereon with computer executable instructions；Processor, the processor execute the meter on the memory
Following steps are executed when calculation machine executable instruction: stitching pessimistic concurrency control after establishing shale gas reservoir pressure；Determine the stream in matrix and crack
Dynamic deformation coupled wave equation；Establish productivity model after shale gas horizontal well pressure；The shale gas production capacity of productivity model after the pressure is calculated,
The preferred man-made fracture parameter of principle is turned to production capacity maximum.
Preferably, the flow deformation coupled wave equation in the matrix and crack include: shale Medium Culture gas flow equation,
Fluid flows continuity equation in shale pore media deformation equation and crack.
The beneficial effects of the present invention are: provide the shale gas reservoir of a kind of consideration porous media deformation and Coupled with Flow
Productivity after fracturing reform can simulate under dynamic production environment artificial fracture parameters to shale gas using this method
Optimal man-made fracture parameter combination can be obtained according to production capacity maximization principle for the affecting laws of production capacity.The present invention is innovation page
The method of rock gas AOF calculation improves the preferred basic theory of fracture parameters, the optimization design of hydraulic fracturing is instructed all to have one
Fixed theoretical and practical values.
Other features and advantages of the present invention will then part of the detailed description can be specified.
Detailed description of the invention
Exemplary embodiment of the invention is described in more detail in conjunction with the accompanying drawings, it is of the invention above-mentioned and its
Its purpose, feature and advantage will be apparent, wherein in exemplary embodiment of the invention, identical reference label
Typically represent same parts.
Fig. 1 shows the flow chart of the step of shale gas reservoir man-made fracture parameter preferred method according to the present invention.
Fig. 2 shows the schematic diagrams that pessimistic concurrency control is stitched after pressure according to an embodiment of the invention.
Fig. 3 shows crack normalization flow conductivity in varying strength shale according to an embodiment of the invention and returns
Curve.
Fig. 4 shows shale crack long-term flow conductivity experimental data according to an embodiment of the invention and returns bent
Line.
Fig. 5 shows cumulative production according to an embodiment of the invention with the long change curve of major fracture half.
Fig. 6 shows cumulative production according to an embodiment of the invention with crack grade spacing change curve.
Fig. 7 shows cumulative production according to an embodiment of the invention with crack cluster spacing change curve.
Fig. 8 shows cumulative production according to an embodiment of the invention and changes song with the initial flow conductivity of major fracture
Line.
Fig. 9 shows cumulative production according to an embodiment of the invention and changes song with the initial flow conductivity of secondary fracture
Line.
Specific embodiment
The preferred embodiment of the present invention is described in more detail below.Although the following describe preferred implementations of the invention
Mode, however, it is to be appreciated that may be realized in various forms the present invention without that should be limited by the embodiments set forth herein.Phase
Instead, these embodiments are provided so that the present invention is more thorough and complete, and can be by the scope of the present invention completely
It is communicated to those skilled in the art.
Embodiment 1
In this embodiment, shale gas reservoir man-made fracture parameter preferred method according to the present invention may include: to establish
Pessimistic concurrency control is stitched after shale gas reservoir pressure；Determine the flow deformation coupled wave equation in matrix and crack；Establish shale gas horizontal well pressure
Productivity model afterwards；The shale gas production capacity for calculating productivity model after pressing, turns to the preferred man-made fracture parameter of principle with production capacity maximum.
The present embodiment by provide it is a kind of consideration porous media deformation and Coupled with Flow shale gas reservoir fracturing improvement after
Productivity turns to principle with production capacity maximum and obtains optimal shale gas reservoir man-made fracture parameter.
Fig. 1 shows the flow chart of the step of shale gas reservoir man-made fracture parameter preferred method according to the present invention.Under
The specific steps of shale gas reservoir man-made fracture parameter preferred method according to the present invention are described in detail with reference to Fig. 1 for face.
Step 101, pessimistic concurrency control is stitched after establishing shale gas reservoir pressure.
In one example, pessimistic concurrency control is stitched after pressure includes reservoir boundaries, horizontal wellbore, artificial major fracture and secondary fracture.
Fig. 2 shows the schematic diagrams that pessimistic concurrency control is stitched after pressure according to an embodiment of the invention.
Specifically, as shown in Fig. 2, seam pessimistic concurrency control includes reservoir boundaries, horizontal wellbore, artificial major fracture and secondary splits after pressure
Seam.It needs to be determined that input parameter include horizontal wellbore length, it is horizontal well production Control Radius, artificial major fracture item number, secondary
The deformation in fracture spacing and direction, initial level stress field, initial hole pressure field, boundary seepage flow condition and boundary constrains
Condition further includes that the elasticity modulus of rock, bulk modulus, Poisson's ratio, Biot coefficient, initial porosity, shale matrix are inherently seeped
The original permeability of saturating rate, shale artificial major fracture and secondary fracture.
Step 102, the flow deformation coupled wave equation in matrix and crack is determined.
Specifically, after shale air pressure in production process, with the continuous extraction of gas, matrix pores are acted on accordingly
Interior and fracture surface upper fluid pressure constantly reduces, so that effective stress increases, and the variation of stress necessarily causes reservoir in reservoir
The change of the parameters such as porosity, fluid neuron network speed and fracture permeabgility influences whether that matrix and fracture surface are upper again in turn
The variation of body pressure, the interaction relationship that this fluid neuron network and rock deformation mutually restrict in reservoir rock is seepage flow-
Stress coupling.In this embodiment it is assumed that reservoir rock porous media meets flexible deformation criterion, the variation of fracture permeabgility by
Effective stress and insertion double action influence.
In one example, the flow deformation coupled wave equation in matrix and crack includes: shale Medium Culture gas flow side
Fluid flows continuity equation in journey, shale pore media deformation equation and crack.
In one example, the gas flow of shale Medium Culture considers the diffusion and desorption of methane under actual gas state
Attached, shale Medium Culture gas flow equation indicates are as follows:
Wherein, αBFor Biot coefficient；P is pore pressure；μ is fluid viscosity；Z is Gas Compression Factor；M (p) is quasi- pressure
Power；εvFor bulk strain；M is Biot modulus,KgAnd KsRespectively represent the volume of gas and solid particle
Modulus；VLAnd PLRespectively represent Lang Gemiaoer volume and Lang Gemiaoer pressure；ρrRepresent shale density；T is the time；BgIt is stratum
Volume factor；QpFor source sink term；kaIt indicates to consider the apparent permeability that shale gas is slipped with transition flow；MgFor molecular weight gas；
T is gas temperature；R is gas molar constant.
In one example, petrosal foramen gap deformation of media establishes the relationship of porosity and strain, page according to gap Elasticity
Petrosal foramen gap deformation of media equation indicates are as follows:
Wherein, u is displacement field；G is modulus of shearing；ν is Poisson's ratio；αBFor Biot coefficient；For plane problem [m]=
[1,1,0], for three-dimensional problem [m]=[1,1,1,0,0,0]；M (p) is pseudopressure；F is body force；μ is fluid viscosity；Z is
Gas Compression Factor.
The relationship of shale matrix porosity and strain are as follows:
Wherein, φ0For initial porosity；αBFor Biot coefficient；εvFor bulk strain；P is
Pore pressure；p0For initial pore pressure；KsFor the bulk modulus of solid particle.
Rock intrinsic permeability can be characterized with porosity by cubic law:
Wherein, k∞Represent the intrinsic permeability (m of Rock Matrix2)；k0And φ0Respectively represent the initial infiltration of Rock Matrix
Rate and initial porosity；φ is the effecive porosity after rock deformation.
In one example, fluid flowing is taken as flowing inner boundary to handle in crack, and assumes only to be parallel to split
The flowing in seam face direction, ignore along slit width direction fluid flowing, therefore can fracture carry out dimension-reduction treatment, will be in two dimensional model
Plane suture indicate that stitching the volume in threedimensional model is indicated with boundary face with boundary line, fluid flows continuity side in crack
Journey indicates are as follows:
Wherein, SfFor crack packing coefficient；W is fracture width；V is fluid along crack boundary movement velocity；It is split for edge
The tangential divergence in seam face；P is pore pressure；ρgFor for fluid density；T is the time.
Fluid flows through Darcy's law characterization in stitching:
Wherein, kfFor fracture permeabgility；μ is fluid viscosity；W is fracture width；▽TFor the divergence tangential along fracture surface；p
For pore pressure.
The relationship of shale man-made fracture permeability and effective stress may be expressed as:
Wherein, kf0Expression effective normal stress is σe0When crack original permeability, cfFor crack compression ratio, σeTo act on
Effective normal stress on fracture surface.
The quantitative relationship of shale man-made fracture flow conductivity and time:
FRCD=53t-0.16 (8)
Wherein, FRCDFor fracture condudtiviy, unit Dcm；T is time, unit h.
Step 103, productivity model after shale gas horizontal well pressure is established.
Specifically, it is contemplated that the seepage-pipe coupling model effect after shale air pressure in production process determines in matrix and crack
Flow deformation coupled wave equation, including the shale Medium Culture gas flow equation as shown in formula (1), as shown in formula (2)
Fluid flows continuity equation in shale pore media deformation equation and the crack as shown in formula (3), and coupling terms are then by formula
(4), formula (5), formula (7), formula (8) are constituted.
Step 104, the shale gas production capacity of productivity model after pressing is calculated, the preferred man-made fracture ginseng of principle is turned to production capacity maximum
Number.
Specifically, production capacity fluid structurecoupling numerical value calculating side after shale gas reservoir pressure is established using finite element method
Method solves the non-linear of equation using iterative method.
In one example, the shale gas production capacity of productivity model includes: after calculating pressure
1) boundary of pessimistic concurrency control is stitched after specifying pressure, and model is initialized, indirect assignment acquisition is carried out to pressure field
Initial pressure field, and according to the flow deformation coupled wave equation in matrix and crack, before carrying out incremental time calculating first
To the initial displacement field under edge load and Pore Pressure；
2) assignment is carried out to the gas physical parameter on each solution unit according to initial pressure field, is counted under boundary condition
The displacement field and pressure field obtained in each loop iteration step is calculated, the stress on Gauss point point is acquired according to modal displacement field
Cloth, and parameter and fracture permeabgility are seeped in the hole for obtaining pore media accordingly；
3) calculated result before and after loop iteration is compared, if being unsatisfactory for the limits of error, return step 2 continues to follow
Ring iterative, following iteration walk value and are generated by the weighted sum of the calculated value before current iteration step calculated value and current iteration step,
If meeting the limits of error, output unit node pressure and Gauss point stress calculate shale gas production capacity and export；
4) judge calculate total time whether reach scheduled total time, gone successively to if not up to scheduled total time
Next incremental time is calculated, and step 2) -4 is repeated), until calculating until predetermined total time, otherwise directly terminate to transport
It calculates.
In one example, man-made fracture parameter include: crack cluster spacing, grade spacing, half long, major fracture flow conductivity and
Secondary fracture flow conductivity.
Specifically, it on the basis of the shale gas horizontal well multistage fracturing productivity model of foundation, is produced to shale gas is influenced
The fracture parameters of energy optimize research.For crack cluster spacing, grade spacing, half long, major fracture flow conductivity and secondary split
The parameters such as flow conductivity are stitched, have studied each Parameters variation respectively to the affecting laws of production capacity, and give optimal man-made fracture
Parameter designing reference value.
Present embodiments provide it is a kind of consideration porous media deformation and Coupled with Flow shale gas reservoir fracturing improvement after produce
Energy calculation method can simulate influence of the artificial fracture parameters to shale gas production capacity under dynamic production environment using this method and advise
Rule, optimal man-made fracture parameter combination can be obtained according to production capacity maximization principle.For innovate shale gas AOF calculation method,
It improves the preferred basic theory of fracture parameters, instruct the optimization design of hydraulic fracturing that all there are certain theoretical and practical values.
Using example
A concrete application example is given below in the scheme and its effect of the embodiment of the present invention for ease of understanding.This field
It should be understood to the one skilled in the art that the example is only for the purposes of understanding the present invention, any detail is not intended to be limited in any way
The system present invention.
Firstly, table 1 shows the basic parameter of shale gas reservoir model, according to the basic parameter in table 1, shale gas is established
Pessimistic concurrency control is stitched after reservoir pressure.
Table 1
| Physical quantity | Numerical value | Unit | Physical quantity | Numerical value | Unit |
| Initial porosity, φ | 0.04 | Bottom-hole producing pressure (PBHP), pw | 15.00 | MPa | |
| Poisson's ratio, ν | 0.25 | Temperature, T | 363.00 | K | |
| Biot coefficient, αB | 0.64 | Shale density, ρr | 2.40×103 | kg/m3 | |
| Young's modulus, E | 20.68 | GPa | Minimum horizontal principal stress, σh | -39.01 | MPa |
| Bulk modulus, K | 13.79 | GPa | Maximum horizontal principal stress, σH | -43.34 | MPa |
| Particle volume modulus, Ks | 37.82 | GPa | Lang Gemiaoer pressure, PL | 3.50 | MPa |
| Pore radius, Rc | 1.00E-8 | m | Lang Gemiaoer volume, VL | 2.41×10-3 | m3/kg |
| Adsorbent layer thickness, dm | 0.40E-9 | m | Major fracture original width, w | 5.00 | mm |
| Reservoir length, L | 2000.00 | m | Major fracture compression ratio, cf1 | 0.04 | 1/MPa |
| Reservoir half width, W | 320.00 | m | Secondary fracture original width, wi | 0.50 | mm |
| Stratum initial pressure, pi | 28.27 | MPa | Secondary fracture compression ratio, cf2 | 0.07 | 1/MPa |
Secondly, being determined in matrix and crack in view of the seepage-pipe coupling model effect after shale air pressure in production process
Flow deformation coupled wave equation, including the shale Medium Culture gas flow equation as shown in formula (1), the page as shown in formula (2)
Fluid flows continuity equation in petrosal foramen gap deformation of media equation and the crack as shown in formula (3), and coupling terms are then by formula
(4), formula (5), formula (7), formula (8) are constituted.
Fig. 3 shows in above-mentioned application example crack in varying strength shale and normalizes flow conductivity regression curve.Fig. 3
The experimental data of shale man-made fracture flow conductivity and effective stress is given, grade fracture width is to reservoir in laboratory experiment
Flow effect is little, assumes that fracture width is constant in discrete fractures model, only fracture permeabgility changes, therefore crack
Flow conductivity kfW is only related to permeability.It can be returned to obtain crack compression ratio c according to flow conductivity experimental dataf, Jin Erke
Obtain the quantitative relationship of shale man-made fracture permeability and effective stress as shown in formula (7).
Fig. 4 shows shale crack long-term flow conductivity experimental data and regression curve in above-mentioned application example.According to
Experimental data can return to obtain shown in shale fracture condudtiviy and the quantitative relationship of time such as formula (8).
Then, unity couping is carried out to the productivity model using business finite element solving device and solves displacement field and pressure field, choosing
Triangle element mesh is selected, and is encrypted around crack.After obtaining pressure distribution, counted according to such as formula 6
The yield and cumulative production of shale gas can be obtained in the fluid velocity field of calculation.
Finally, productivity model is solved and has been verified using multiple physical field couple solution device, for crack cluster spacing,
The artificial fracture parameters such as grade spacing, fracture half-length, major fracture flow conductivity and secondary fracture flow conductivity, using orthogonal experiment
In two horizontal parts molecular group design method find significant variable therein, target is turned to production capacity maximum, each parameter is carried out
Preferably.
Fig. 5 shows in above-mentioned application example cumulative production with the long change curve of major fracture half.Fig. 6 is shown above-mentioned
Using cumulative production in example with crack grade spacing change curve.Fig. 7 shows in above-mentioned application example cumulative production with splitting
Stitch cluster spacing change curve.It is bent with the initial flow conductivity variation of major fracture that Fig. 8 shows the cumulative production in above-mentioned application example
Line.Fig. 9 shows in above-mentioned application example cumulative production with the initial flow conductivity change curve of secondary fracture.Extremely according to Fig. 5
Fig. 9 analysis recommends major fracture partly to grow in 200m or so under the conditions of the present embodiment after comprehensive analysis, and optimal crack grade spacing is
75m-100m, optimal crack cluster spacing be 30m-40m, recommend the initial flow conductivity of major fracture 10mdm-100mdm it
Between, the initial flow conductivity of secondary fracture be greater than 0.25mdm, that is, can guarantee higher cumulative production.
This application example provide it is a kind of consideration porous media deformation and Coupled with Flow shale gas reservoir fracturing improvement after
Productivity can simulate artificial influence of the fracture parameters to shale gas production capacity under dynamic production environment using this method
Optimal man-made fracture parameter combination can be obtained according to production capacity maximization principle for rule.For the side for innovating shale gas AOF calculation
Method improves the preferred basic theory of fracture parameters, the optimization design of hydraulic fracturing is instructed all to have certain theoretical and practical valence
Value.
It will be understood by those skilled in the art that above to the purpose of the description of the embodiment of the present invention only for illustratively saying
The beneficial effect of bright the embodiment of the present invention is not intended to limit embodiments of the invention to given any example.
Embodiment 2
According to an embodiment of the invention, providing a kind of shale gas reservoir man-made fracture parameter optimum decision system, system includes:
Memory is stored thereon with computer executable instructions；Processor, processor execute the computer executable instructions on memory
Shi Zhihang following steps: pessimistic concurrency control is stitched after establishing shale gas reservoir pressure；Determine the flow deformation coupled wave equation in matrix and crack；
Establish productivity model after shale gas horizontal well pressure；The shale gas production capacity for calculating productivity model after pressing, turns to principle with production capacity maximum
It is preferred that man-made fracture parameter.
In one example, the flow deformation coupled wave equation in matrix and crack includes: shale Medium Culture gas flow side
Fluid flows continuity equation in journey, shale pore media deformation equation and crack.
Present embodiments provide it is a kind of consideration porous media deformation and Coupled with Flow shale gas reservoir fracturing improvement after produce
Energy calculation method can simulate influence of the artificial fracture parameters to shale gas production capacity under dynamic production environment using this method and advise
Rule, optimal man-made fracture parameter combination can be obtained according to production capacity maximization principle.For innovate shale gas AOF calculation method,
It improves the preferred basic theory of fracture parameters, instruct the optimization design of hydraulic fracturing that all there are certain theoretical and practical values.
It will be understood by those skilled in the art that above to the purpose of the description of the embodiment of the present invention only for illustratively saying
The beneficial effect of bright the embodiment of the present invention is not intended to limit embodiments of the invention to given any example.
Various embodiments of the present invention are described above, above description is exemplary, and non-exclusive, and
It is not limited to disclosed each embodiment.Without departing from the scope and spirit of illustrated each embodiment, for this skill
Many modifications and changes are obvious for the those of ordinary skill in art field.
Claims (10)
1. a kind of shale gas reservoir man-made fracture parameter preferred method, which is characterized in that this method comprises:
Pessimistic concurrency control is stitched after establishing shale gas reservoir pressure；
Determine the flow deformation coupled wave equation in matrix and crack；
Establish productivity model after shale gas horizontal well pressure；
The shale gas production capacity for calculating productivity model after the pressure, turns to the preferred man-made fracture parameter of principle with production capacity maximum.
2. shale gas reservoir man-made fracture parameter preferred method according to claim 1, wherein stitch pessimistic concurrency control after the pressure
Including reservoir boundaries, horizontal wellbore, artificial major fracture and secondary fracture.
3. shale gas reservoir man-made fracture parameter preferred method according to claim 1, wherein in the matrix and crack
Flow deformation coupled wave equation include: in shale Medium Culture gas flow equation, shale pore media deformation equation and crack flow
Body flows continuity equation.
4. shale gas reservoir man-made fracture parameter preferred method according to claim 3, wherein the shale Medium Culture gas
Body percolation equationk indicates are as follows:
Wherein, αBFor Biot coefficient；P is pore pressure；μ is fluid viscosity；Z is Gas Compression Factor；M (p) is pseudopressure；εv
For bulk strain；M is Biot modulus,KgAnd KsRespectively represent the bulk modulus of gas and solid particle；
VLAnd PLRespectively represent Lang Gemiaoer volume and Lang Gemiaoer pressure；ρrRepresent shale density；T is the time；BgIt is formation volume system
Number；QpFor source sink term；kaIt indicates to consider the apparent permeability that shale gas is slipped with transition flow；MgFor molecular weight gas；T is gas
Temperature；R is gas molar constant.
5. shale gas reservoir man-made fracture parameter preferred method according to claim 3, wherein the shale pore media
Deformation equation indicates are as follows:
Wherein, u is displacement field；G is modulus of shearing；ν is Poisson's ratio；αBFor Biot coefficient；For plane problem [m]=[1,1,
0], for three-dimensional problem [m]=[1,1,1,0,0,0]；M (p) is pseudopressure；F is body force；μ is fluid viscosity；Z is gas
Compressibility factor.
6. shale gas reservoir man-made fracture parameter preferred method according to claim 3, wherein fluid stream in the crack
Dynamic continuity equation indicates are as follows:
Wherein, SfFor crack packing coefficient；W is fracture width；V is fluid along crack boundary movement velocity；For along fracture surface
Tangential divergence；P is pore pressure；ρgFor for fluid density；T is the time.
7. shale gas reservoir man-made fracture parameter preferred method according to claim 1, wherein calculate production capacity after the pressure
The shale gas production capacity of model includes:
1) based on the flow deformation coupling side in the boundary and primary condition, the matrix and crack for stitching pessimistic concurrency control after the pressure
Journey obtains initial displacement field before carrying out incremental time calculating；
2) it is based on initial pressure field, the displacement field and pressure field calculated in each loop iteration step is obtained according to the displacement field
Seep parameter and fracture permeabgility in the hole for obtaining pore media；
3) pressure difference before and after loop iteration, if being unsatisfactory for the limits of error, repeatedly step 2) -3 are compared), it is otherwise, defeated
Cell node pressure and Gauss point stress out calculate the shale gas production capacity；
4) judge calculate total time whether reach scheduled total time, if having reached scheduled total time, directly terminate to count
It calculates, otherwise, goes successively to next incremental time and calculated, repeat step 2) -4).
8. shale gas reservoir man-made fracture parameter preferred method according to claim 1, wherein the man-made fracture parameter
It include: crack cluster spacing, grade spacing, half long, major fracture flow conductivity and secondary fracture flow conductivity.
9. a kind of shale gas reservoir man-made fracture parameter optimum decision system, which is characterized in that the system comprises:
Memory is stored thereon with computer executable instructions；
Processor, the processor execute following steps when executing the computer executable instructions on the memory:
Pessimistic concurrency control is stitched after establishing shale gas reservoir pressure；
Determine the flow deformation coupled wave equation in matrix and crack；
Establish productivity model after shale gas horizontal well pressure；
The shale gas production capacity for calculating productivity model after the pressure, turns to the preferred man-made fracture parameter of principle with production capacity maximum.
10. shale gas reservoir man-made fracture parameter optimum decision system according to claim 9, wherein the matrix and crack
Interior flow deformation coupled wave equation includes: in shale Medium Culture gas flow equation, shale pore media deformation equation and crack
Fluid flows continuity equation.
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