CN105843992A - Shale gas numerical simulation method based on fracture network system and percolation characteristics - Google Patents
Shale gas numerical simulation method based on fracture network system and percolation characteristics Download PDFInfo
- Publication number
- CN105843992A CN105843992A CN201610151740.4A CN201610151740A CN105843992A CN 105843992 A CN105843992 A CN 105843992A CN 201610151740 A CN201610151740 A CN 201610151740A CN 105843992 A CN105843992 A CN 105843992A
- Authority
- CN
- China
- Prior art keywords
- shale gas
- gas
- fracture
- numerical simulation
- crack
- Prior art date
- Legal status (The legal status is an assumption and is not a legal conclusion. Google has not performed a legal analysis and makes no representation as to the accuracy of the status listed.)
- Pending
Links
Classifications
-
- G—PHYSICS
- G06—COMPUTING; CALCULATING OR COUNTING
- G06F—ELECTRIC DIGITAL DATA PROCESSING
- G06F30/00—Computer-aided design [CAD]
- G06F30/30—Circuit design
- G06F30/36—Circuit design at the analogue level
- G06F30/367—Design verification, e.g. using simulation, simulation program with integrated circuit emphasis [SPICE], direct methods or relaxation methods
Landscapes
- Engineering & Computer Science (AREA)
- Computer Hardware Design (AREA)
- Physics & Mathematics (AREA)
- Theoretical Computer Science (AREA)
- Microelectronics & Electronic Packaging (AREA)
- Evolutionary Computation (AREA)
- Geometry (AREA)
- General Engineering & Computer Science (AREA)
- General Physics & Mathematics (AREA)
- Management, Administration, Business Operations System, And Electronic Commerce (AREA)
Abstract
The invention discloses a shale gas numerical simulation method based on a fracture network system and percolation characteristics. The shale gas numerical simulation method comprises the following steps: a) calculating the fracture width and the fracture height of a fracture and the pressure of a gas phase in a simulation process after spatial dispersion is carried out; and b) utilizing the following formula, according to the fracture width and the fracture height, which are obtained in the a), of the fracture and the pressure, which is obtained in the a), of the gas phase in the simulation process after spatial dispersion is carried out, calculating the total volume flow of a gas flowing direction. A shale gas discrete fracture network seepage numerical model is established on the basis of the discrete fracture, and the problem that a majority of numerical simulation of fracture development on the basis of a continuous medium seepage model has an inaccurate calculation result is solved.
Description
Technical field
The present invention relates to shale gas exploration and development technical field, be specifically related to shale gas method for numerical simulation based on fracture network system and seepage flow characteristics.
Background technology
The exploitation of shale gas has become as the focus of world, but about the theoretical research of shale gas also in the starting stage, application about shale gas method for numerical simulation at present is confined to the continuum Model that conventional oil Numerical Simulation of Gas Reservoir is used mostly, but shale gas intrinsic fracture is grown, anisotropism is strong, and continuum Model can not the distinctive seepage flow characteristics of accurate characterization shale gas.Numerical simulation calculation is used widely in terms of the establishment of gas field development Adjusted Option, development effectiveness prediction.Conventional numerical simulation method mainly includes that implicit expression calculates pressure, explicit algorithm saturation intent, implicit expression replaces method for solving, half implicit expression and fully implicit method, wherein, IMES and IMPIMS method term order solves, and all cannot obtain the analog result of shale gas pressure accurately.
Based on this, research and develop shale gas method for numerical simulation based on fracture network system and seepage flow characteristics.
Summary of the invention
The technical problem to be solved is that the precision of prediction of existing method for numerical simulation is low, present invention aim at providing shale gas method for numerical simulation based on fracture network system and seepage flow characteristics, solve the problem that the precision of prediction of existing method for numerical simulation is low.
The present invention is achieved through the following technical solutions:
Shale gas method for numerical simulation based on fracture network system and seepage flow characteristics, said method comprising the steps of:
The seam width in crack, seam height, the pressure of gas phase during simulating after step a, calculating spatial spreading；
Step b, utilize below equation, according to the seam width in simulation process crack, seam height, the total volumetric flow rate of the calculation of pressure gas flow direction of gas phase after the spatial spreading that step a obtains；
Wherein, h is that the seam in crack is high, and m, w are the seam width in crack, m, ugGas viscosity, mPa s,For barometric gradient mPa/m, QVFor volume flow, m3/S。
Further, in order to preferably realize the present invention, described shale gas method for numerical simulation also includes, also includes utilizing below equation to calculate shale gas molar density；
Wherein, R universal gas constant, 8.314 × 10-6MPa·m3·mol-1·k-1, Z is that shale gas compresses silver, zero dimension；V is shale gas volume, m3；ρ is the molar density of shale gas, mol/m3, P is the pressure residing for shale gas, mPa.
Further, in order to preferably realize the present invention, described shale gas molar density is under uniform temperature and pressure, the molal quantity of unit volume shale gas.
According to formula PV=ZNRT, wherein T is shale gas absolute temperature, K；R is general constant, 8.314 × 10-6MPa·m3·mol-1·k-1, Z is shale gas compressibility factor, zero dimension；V is shale gas volume, m3；P is the pressure residing for shale gas, MPa；N is shale gas molal quantity, mol.
From gas compressibility, gas density and temperature, pressure are relevant, it is known that under uniform temperature and pressure condition, shale makings metric density computing formula is
Wherein, M is shale gas relative molecular mass, kg/mol/.
Due to shale gas complicated component, relative molecular mass is difficult to determine, avoids calculating shale gas relative molecular weight to cause error by introducing molar density.
Further, in order to preferably realize the present invention, the overall accumulated amount of crack micro unit inflow and outflow of described unit interval is equal with unit interval crack micro unit molal quantity variable quantity.
Utilize mass conservation law and differentiation, with the intersection point P of any 2 cracks as object of study, the variable quantity of the overall accumulated amount of shale gas unit interval crack inflow and outflow=unit interval crack molal quantity.
The present invention compared with prior art, has such advantages as and beneficial effect:
(1) present invention establishes shale gas discrete fracture network seepage flow numerical model based on discrete fractures, solves majority and there is the inaccurate problem of result of calculation based on continuous media flow model in porous media numerical simulation fracture development.
(2) first based on discrete fracture network model, set up shale gas discrete fractures seepage experiment, filled up and existing Numerical Method Study considers the multiple dimensioned stream of shale gas and the blank of crack stream the most simultaneously.
(3) result of calculation of method for numerical simulation of the present invention is more accurately closer to practical situation, and the development for fractured reservoirs numerical simulation technology from now on lays the foundation.
Accompanying drawing explanation
Accompanying drawing described herein is used for providing being further appreciated by the embodiment of the present invention, constitutes the part of the application, is not intended that the restriction to the embodiment of the present invention.In the accompanying drawings:
Fig. 1 is P point schematic diagram in the present embodiment.
Detailed description of the invention
For making the object, technical solutions and advantages of the present invention clearer, below in conjunction with embodiment and accompanying drawing, the present invention is described in further detail, and the exemplary embodiment of the present invention and explanation thereof are only used for explaining the present invention, not as a limitation of the invention.
Embodiment:
Shale gas method for numerical simulation based on fracture network system and seepage flow characteristics, said method comprising the steps of:
The gaseous pressure in each moment, aqueous phase pressure during simulating after step a, calculating spatial spreading；
Step b, utilize below equation, according to the gaseous pressure in simulation process each moment, the total volumetric flow rate of aqueous phase calculation of pressure gas flow direction after the spatial spreading that step a obtains:
Wherein, h is that the seam in crack is high, and m, w are the seam width in crack, m, ugGas viscosity, mPa s,For barometric gradient mPa/m, QVFor volume flow, m3/S。
In view of Gas Compression Factor, the mass density computational methods of shale gas are:
Wherein, R universal gas constant, 8.314 × 10-6MPa·m3·mol-1·k-1, Z is that shale gas compresses silver, zero dimension；V is shale gas volume, m3；ρ is the molar density of shale gas, mol/m3, P is the pressure residing for shale gas, and mPa, M are shale gas relative molecular mass M=m/n, kg/mol.
In view of shale gas complicated component, relative molecular weight is difficult to determine, uses and introduces the unnecessary error that molar density can avoid shale gas relative molecular weight to cause.Under uniform temperature and pressure, the molal quantity of unit volume shale gas, it is represented byρ is the molar density of shale gas, mol/m3。
Utilizing mass conservation law and differentiation, with the intersection point P of any 2 cracks as object of study, set up fisstured flow mathematical model, unit interval crack infinitesimal inflow and outflow volume total amount is equal with molal quantity variable quantity in unit interval crack micro unit.
As it is shown in figure 1, flowing into P point volume flow along X-axis in the unit interval is-(Qv) p-e, the volume flow flowing out P point is (Qv) p-w；The volume flow flowing into P point along y-axis is-(Qv) p-n, and the volume flow along P point is (Qv) p-s；Owing to crack penetration is strong, unit interval internal fissure intersection point P volume change is 0, i.e.
ρ[(QV)P-W-(QV)P-E+(QV)P-S-(QV)P-N(QV)P-N]=0
Above-described detailed description of the invention; the purpose of the present invention, technical scheme and beneficial effect are further described; it is it should be understood that; the foregoing is only the detailed description of the invention of the present invention; the protection domain being not intended to limit the present invention; all within the spirit and principles in the present invention, any modification, equivalent substitution and improvement etc. done, should be included within the scope of the present invention.
Claims (4)
1. shale gas method for numerical simulation based on fracture network system and seepage flow characteristics, it is characterised in that said method comprising the steps of:
The seam width in crack, seam height, the pressure of gas phase during simulating after step a, calculating spatial spreading；
Step b, utilize below equation, according to the seam width in simulation process crack, seam height, the total volumetric flow rate of the calculation of pressure gas flow direction of gas phase after the spatial spreading that step a obtains；
Wherein, h is that the seam in crack is high, and m, w are the seam width in crack, m, ugGas viscosity, mPa s,For barometric gradient mPa/m, QVFor volume flow, m3/S。
Shale gas method for numerical simulation based on fracture network system and seepage flow characteristics the most according to claim 1, it is characterised in that: also include utilizing below equation to calculate shale gas molar density；
Wherein, R universal gas constant, 8.314 × 10-6MPa·m3·mol-1·k-1, Z is that shale gas compresses silver, zero dimension；V is shale gas volume, m3；ρ is the molar density of shale gas, mol/m3, P is the pressure residing for shale gas, mPa.
Shale gas method for numerical simulation based on fracture network system and seepage flow characteristics the most according to claim 2, it is characterised in that: described shale gas molar density is under uniform temperature and pressure, the molal quantity of unit volume shale gas.
Shale gas method for numerical simulation based on fracture network system and seepage flow characteristics the most according to claim 3, it is characterised in that: the overall accumulated amount of crack micro unit inflow and outflow of described unit interval is equal with unit interval crack micro unit molal quantity variable quantity.
Priority Applications (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201610151740.4A CN105843992A (en) | 2016-03-17 | 2016-03-17 | Shale gas numerical simulation method based on fracture network system and percolation characteristics |
Applications Claiming Priority (1)
| Application Number | Priority Date | Filing Date | Title |
|---|---|---|---|
| CN201610151740.4A CN105843992A (en) | 2016-03-17 | 2016-03-17 | Shale gas numerical simulation method based on fracture network system and percolation characteristics |
Publications (1)
| Publication Number | Publication Date |
|---|---|
| CN105843992A true CN105843992A (en) | 2016-08-10 |
Family
ID=56587140
Family Applications (1)
| Application Number | Title | Priority Date | Filing Date |
|---|---|---|---|
| CN201610151740.4A Pending CN105843992A (en) | 2016-03-17 | 2016-03-17 | Shale gas numerical simulation method based on fracture network system and percolation characteristics |
Country Status (1)
| Country | Link |
|---|---|
| CN (1) | CN105843992A (en) |
Cited By (2)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN108709477A (en) * | 2018-01-19 | 2018-10-26 | 上海市计量测试技术研究院 | The measuring and calculation method of window gap size |
| CN109558614A (en) * | 2017-09-27 | 2019-04-02 | 中国石油化工股份有限公司 | The analogy method and system that gas flows in shale gas reservoir multi-scale facture |
-
2016
- 2016-03-17 CN CN201610151740.4A patent/CN105843992A/en active Pending
Non-Patent Citations (1)
| Title |
|---|
| 糜利栋 等: "页岩气离散裂缝网络模型数值模拟方法研究", 《天然气地球科学》 * |
Cited By (3)
| Publication number | Priority date | Publication date | Assignee | Title |
|---|---|---|---|---|
| CN109558614A (en) * | 2017-09-27 | 2019-04-02 | 中国石油化工股份有限公司 | The analogy method and system that gas flows in shale gas reservoir multi-scale facture |
| CN109558614B (en) * | 2017-09-27 | 2021-09-14 | 中国石油化工股份有限公司 | Simulation method and system for gas flow in shale gas reservoir multi-scale fracture |
| CN108709477A (en) * | 2018-01-19 | 2018-10-26 | 上海市计量测试技术研究院 | The measuring and calculation method of window gap size |
Similar Documents
| Publication | Publication Date | Title |
|---|---|---|
| CN107130960B (en) | Numerical simulation method considering nonlinear seepage characteristics of tight sandstone reservoir | |
| JP5646679B2 (en) | On-site saturated hydraulic conductivity measuring instrument | |
| CN105738252B (en) | The measurement method of the flowable aperture boundary of viscous crude in a kind of crack | |
| CN104297126B (en) | Gas seepage starting pressure gradient measuring device and method for low-permeability reservoir | |
| CN101446196A (en) | Well test analysis method and device of treble medium oil pool branch horizontal well | |
| CN104316449A (en) | Experimental method and experimental device for determinating volcanic gas-water relative permeability | |
| CN105332698B (en) | The method for measuring the method and oil-water relative permeability relationship of residual oil saturation | |
| CN107577831A (en) | A kind of fracture-cavity type carbonate oil-gas reservoir solution cavity scale computational methods | |
| CN106761613B (en) | A kind of up-front well testing of carbon dioxide displacement determines method | |
| CN103048246A (en) | Device and method for measuring rock core-formation water-CO2 wettability change | |
| CN106869918A (en) | Offshore field productivity test method of real-time adjustment | |
| CN102915406A (en) | Calculation method for relative permeability curve of oil and water in radial flow condition | |
| Mourhatch et al. | Determination of the true pore size distribution by flow permporometry experiments: an invasion percolation model | |
| CN104463345B (en) | Method and device for predicting stratum oil-water interface position | |
| CN104297130B (en) | The intrinsic permeability means of interpretation of low-permeability reservoir and system | |
| CN109060639A (en) | A kind of measuring method of long cores permeability saturation curve | |
| CN113484216B (en) | Method for evaluating water phase flowback rate and reasonable flowback pressure difference of tight sandstone gas reservoir | |
| CN106802271A (en) | A kind of measurement apparatus and method of poly- oil reservoirs fluid neuron network free-boundary problem | |
| CN107944620A (en) | A kind of Non-linear of individual well steady state productivity | |
| CN113836695A (en) | Oil reservoir numerical simulation method based on non-grid connecting elements | |
| CN111734394A (en) | Method for determining unsteady flow bottom pressure of tight reservoir fracturing well | |
| CN105843992A (en) | Shale gas numerical simulation method based on fracture network system and percolation characteristics | |
| CN106777663B (en) | Fracturing fluid filtering stall degree calculation method considering natural fractures | |
| CN104881522A (en) | Fluid potential field based remaining oil representation method and device | |
| CN110006788B (en) | Device and method for measuring spreadability of water shutoff agent at porous medium air-water interface |
Legal Events
| Date | Code | Title | Description |
|---|---|---|---|
| C06 | Publication | ||
| PB01 | Publication | ||
| SE01 | Entry into force of request for substantive examination | ||
| SE01 | Entry into force of request for substantive examination | ||
| RJ01 | Rejection of invention patent application after publication | ||
| RJ01 | Rejection of invention patent application after publication |
Application publication date: 20160810 |