CN111062129A - Shale oil complex seam network discrete fracture continuous medium mixed numerical simulation method - Google Patents
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Abstract
The invention discloses a shale oil complex seam network discrete fracture continuous medium mixed numerical simulation method, which comprises the following steps: analyzing the fracturing construction condition of a shale oil reservoir, determining the property of hydraulic fractures in a fracturing modification area, and performing explicit representation on the hydraulic fractures; establishing a seepage mathematical model of the hydraulic fracture-natural fracture and matrix after hydraulic fracturing modification; establishing an embedded discrete crack and continuous medium mixed numerical simulation mathematical model; constructing an embedded discrete crack and continuous medium model mixed numerical simulation model, including a single-phase or oil-water two-phase flow numerical simulation model, and solving; predicting the yield of different seam network reconstruction conditions of the compact reservoir by using the model; the method can treat the condition that matrix-natural fracture-hydraulic fracture multiple medium flow exists in a reservoir; the problem that the existing commercial numerical simulation method cannot accurately represent the fracturing reconstruction area is solved, and the calculation result is more objective and accurate.
Description
Technical Field
The invention relates to a new shale oil complex seam network discrete fracture continuous medium mixed numerical simulation method, and belongs to the field of unconventional oil and gas development.
Background
Shale oil reservoirs generally have artificial fracturing fractures, natural fractures, matrixes and other storage and flowing spaces, and large-scale hydraulic fractures are high in fluid flowing capacity, second-order natural fractures and worst in matrixes. At present, unconventional oil and gas fracture-matrix characterization methods are mainly divided into two types: dual media models and discrete fracture models. The dual medium model assumes the existence of the characterization unit bodies, and the matrix and the cracks have more uniform properties and have advantages in the aspect of computational efficiency. The shape factor is the most important parameter in the model, the traditional shape factor based on the matrix-natural fracture steady-state channeling hypothesis cannot meet the requirements of shale oil reservoir simulation, and the matrix-fracture channeling of the shale oil reservoir can be accurately described based on the shape factor of unsteady-state channeling. In addition to the correction of the cross-flow factor, multiple continuum models were proposed and applied to the development simulation of shale oil reservoirs. Thereafter, a multi-subdomain approach is proposed and applied to the simulation of a fractured reservoir. The basic idea is to divide the matrix into a plurality of subdomains based on pressure equipotential lines by local flow simulation, and to perform numerical simulation by establishing inter-subdomain and coarse inter-grid linking relationships and calculating the conductivity thereof. However, the multi-continuum model and the multi-subdomain method require complicated pre-processing to obtain the conductivity between different subdomains, and are limited in practical reservoir numerical simulation application.
In order to overcome the defect that the dual media can not accurately represent the fracture form and the flow of the fracture, a discrete fracture model is provided and widely applied. The model is generally based on unstructured grids, fractures are explicitly delineated, and the discrete fracture model is low in calculation efficiency because the discrete fracture model needs to be finely divided into grids to display and treat hydraulic fractures and natural fractures. At present, an embedded discrete fracture model shows great advantages in the aspect of numerical simulation of a shale oil reservoir. Flow simulation can be performed directly by modification of the black oil and composition simulator. The initial EDFM method is provided for high-flow-guide cracks, in order to effectively simulate low-flow-guide cracks, a projection embedded discrete crack model is provided, the pressure of a near crack area can be approximated by improving a mass transfer calculation method of cracks and a matrix system near the cracks, the oil-water two-phase flow simulation result of the method is more accurate than that of the EDFM method, and the calculation time cannot be lost.
At present, the EDFM method is a shale oil reservoir fracture-matrix coupling method which is popular in recent years, but the method often has multi-scale performance on a shale oil reservoir flow space, and a large calculation matrix scale and low calculation efficiency can still be caused by only utilizing an embedded discrete fracture model. Therefore, the EDFM theoretical method must be continuously developed and improved, so that the calculation accuracy is guaranteed, the calculation efficiency is improved, and the requirement of large-scale calculation is met.
The existing numerical simulation method of the shale oil reservoir complex fracture system has defects in the aspects of calculation efficiency and calculation precision, for example, a dual medium model cannot depict the detailed information of fractures, and a discrete fracture model has extremely low calculation efficiency due to the large number of discrete grids.
Disclosure of Invention
In order to solve the problems, the method combines the advantages of an embedded discrete fracture model and a dual-medium model, constructs a discrete fracture-continuous medium mixed numerical simulation method on the basis of shale oil reservoir complex fracture network representation, and provides a technical tool for shale oil development.
The method can accurately describe seepage characteristics in a fracturing modification area, objectively reflect the related flow of a matrix, natural fractures, hydraulic fractures and a shaft, effectively perform numerical simulation on a shale oil reservoir with the natural fractures, and predict the capacity of a multistage fracturing horizontal well.
The technical scheme adopted by the disclosure is as follows:
a shale oil complex seam network discrete fracture continuous medium mixed numerical simulation method comprises the following steps:
analyzing the fracturing construction condition of a shale oil reservoir, determining the property of hydraulic fractures in a fracturing modification area, and performing explicit characterization on the hydraulic fractures;
establishing a seepage mathematical model of the hydraulic fracture-natural fracture and matrix after hydraulic fracturing modification;
establishing an embedded discrete fracture and continuous medium mixed numerical simulation mathematical model, wherein the hydraulic fracture is processed by using the embedded discrete fracture model, the mass transfer between the natural fracture and the matrix in the reservoir is processed by using a dual medium model, and the unsteady state flow channeling is considered in the flow channeling between the natural fracture and the matrix;
constructing an embedded discrete crack and continuous medium model mixed numerical simulation model, including a single-phase or oil-water two-phase flow numerical simulation model, and solving;
and (5) predicting the yield of different seam network reconstruction conditions of the compact reservoir by using the model.
Further, step (1) determines a fracture modification zone of the shale oil reservoir through in-situ micro-seismic analysis, and the flow between matrix-natural fracture-hydraulic fracture-wellbore is considered in the modification zone, and the flow between matrix-natural fracture is considered in the non-fracture modification zone. Among them, the flow capacity in different media is the strongest in hydraulic fractures and the weakest in matrix. And (4) performing explicit treatment on the hydraulic fracture, and defining parameters such as fracture length, fracture form, fracture conductivity and the like.
Further, step (2) is to establish a seepage mathematical model of the hydraulic fracture-natural fracture and matrix in the fracture modification area, and simultaneously establish a seepage mathematical model of the natural fracture and matrix in the non-modification area. Among these, the model has the following assumptions: (1) the fluid flows through the matrix, the natural fracture, the hydraulic fracture and the shaft in sequence, and the non-transformation area supplies liquid to the transformation area; (2) the flow is carried out under isothermal conditions; (3) the flow of fluid in different media all follows Darcy's law; (4) the channeling between the matrix and the natural fracture is unsteady channeling; (5) the flow conductivity of the hydraulic fracture is far greater than that of a natural fracture; (6) oil or water is a slightly compressible fluid and the production conditions of the well are either constant pressure or constant production. Establishing a continuity equation of the fluid flow in the matrix, the natural fracture and the hydraulic fracture in the modification area based on the assumptions, and establishing a flow equation of the hydraulic fracture and the shaft; at the same time, an equation of flow continuity for the matrix and natural fractures in the non-engineered region is established. And establishing a flow exchange equation between the matrix and the natural fracture by defining an unsteady flow channeling factor.
Further, step (3) establishes an embedded discrete crack and continuous medium model mixed simulation mathematical model. The flow between the hydraulic fracture and the natural fracture is processed using an embedded discrete fracture model, the flow between the matrix and the natural fracture being defined by a dual-media model. And (3) carrying out spatial dispersion on the matrix-natural fracture-hydraulic fracture, wherein a set of grid system is applied to the matrix grid and the natural fracture grid in the dispersion process, and the hydraulic fracture is automatically dispersed according to the boundary of the natural fracture grid. Five types of link relationships need to be defined in the calculation process: a linkage of the matrix mesh and the natural fracture mesh; natural fracture grids and links between the natural fracture grids; the hydraulic fracture units in the same natural fracture grid are linked with each other; the hydraulic fracture units in different natural fracture grids are linked with each other; a natural fracture network and hydraulic fracture cells. A complete discrete numerical simulation model can be obtained by adding links to the discrete equations.
And further, constructing an oil-water two-phase flow numerical simulation model of embedded discrete fracture and continuous medium model mixed numerical simulation, dispersing oil-water seepage mathematical models in different media by using a finite volume method, performing backward first-order Euler differential processing on time terms, solving after a nonlinear solving system is constructed, wherein solving variables comprise the pressure and water saturation of a matrix grid, a natural fracture grid and a hydraulic fracture grid and the yield of a well.
Further, different reservoir reconstruction geological models are established in the step (5), such as a multi-stage fracturing horizontal well model considering double-wing fractures, a complex fracture horizontal well model and the like, and the models are solved by utilizing the steps (1) to (4) to obtain a yield change curve of the well. And analyzing the distribution characteristics of the residual oil at different moments by using the simulation result.
Compared with the prior art, the beneficial effect of this disclosure is:
(1) the model well combines the advantages of an embedded discrete fracture model and a continuous medium model and can treat the condition that multiple media flow of matrix-natural fracture-hydraulic fracture exists in a reservoir. The method solves the problem that the conventional commercial numerical simulation method cannot accurately represent the fracturing reconstruction area, and has obvious advantages in calculation efficiency.
(2) The new shale oil complex fracture network discrete fracture-continuous medium mixed numerical simulation method can be used for fluid flow simulation under the condition of complex reconstruction volume after shale oil reservoir fracturing reconstruction, and the calculation result is more objective and accurate. The calculation method is convenient and practical, and is convenient for application and popularization in mines.
Drawings
The accompanying drawings, which are incorporated in and constitute a part of this application, illustrate embodiments of the application and, together with the description, serve to explain the application and are not intended to limit the application.
FIG. 1 is a schematic view of embedded discrete fracture non-adjacent links;
FIG. 2 is a schematic diagram of a shale oil complex seam network discrete fracture-continuous medium mixed numerical simulation method grid system;
FIG. 3 is a flow chart of shale oil complex fracture network discrete fracture-continuous medium mixed numerical simulation;
FIG. 4 is a schematic representation of the geological model of example 1;
FIG. 5 is a schematic representation of the well production under different parameters of example 1;
FIG. 6 is a schematic representation of the reservoir pressure distribution after 1000 days and 10 days under different parameters as in example 1;
FIG. 7 is a schematic view of a geological model according to example 2;
FIG. 8 is a schematic representation of the well production under different parameters from example 2;
FIG. 9 is a graph of unsteady and quasi-steady state blowby oil and water production;
FIG. 10 is a table of basic parameters of example 1;
FIG. 11 is a table of high pressure physical property parameters for the oil of example 1;
FIG. 12 is a table of basic parameters of example 2;
FIG. 13 is a table of relative permeability curves for example 2;
1. perforation point, 2, water conservancy crack, 3, natural crack, 4, shaft.
The specific implementation mode is as follows:
the present disclosure is further described with reference to the following drawings and examples.
It should be noted that the following detailed description is exemplary and is intended to provide further explanation of the disclosure. Unless defined otherwise, all technical and scientific terms used herein have the same meaning as commonly understood by one of ordinary skill in the art to which this application belongs.
It is noted that the terminology used herein is for the purpose of describing particular embodiments only and is not intended to be limiting of example embodiments according to the present application. As used herein, the singular forms "a", "an" and "the" are intended to include the plural forms as well, and it should be understood that when the terms "comprises" and/or "comprising" are used in this specification, they specify the presence of stated features, steps, operations, devices, components, and/or combinations thereof, unless the context clearly indicates otherwise.
In the present disclosure, terms such as "upper", "lower", "left", "right", "front", "rear", "vertical", "horizontal", "side", "bottom", and the like indicate orientations or positional relationships based on those shown in the drawings, and are only relational terms determined for convenience in describing structural relationships of the parts or elements of the present disclosure, and do not refer to any parts or elements of the present disclosure, and are not to be construed as limiting the present disclosure.
In the present disclosure, terms such as "fixedly connected", "connected", and the like are to be understood in a broad sense, and mean either a fixed connection or an integral connection or a detachable connection; may be directly connected or indirectly connected through an intermediate. The specific meanings of the above terms in the present disclosure can be determined on a case-by-case basis by persons skilled in the relevant art or technicians, and are not to be construed as limitations of the present disclosure.
As introduced in the background art, the conventional numerical simulation method cannot accurately describe a transformation area, and is low in efficiency in calculation speed, and in order to solve the technical problems, the application provides a new shale oil complex seam network discrete fracture-continuous medium mixed numerical simulation method. The present disclosure is further described with reference to the following figures and examples.
Analyzing the fracturing construction condition of a shale oil reservoir, determining the property of hydraulic fractures in a fracturing modification area, and performing explicit characterization on the hydraulic fractures. As shown in fig. 1, after hydraulic fracturing, hydraulic fractures with high conductivity are formed around the well, and the hydraulic fractures play a dominant role in the production process of the well. Natural fractures develop in the reservoir, and the conductivity of the natural fractures is obviously lower than that of hydraulic fractures but higher than that of the matrix. The area of hydraulic fracture development is defined as the fracture modification area, while the area outside the fracture area is the non-fracture modification area.
And (2) establishing a seepage mathematical model of the hydraulic fracture-natural fracture and the matrix after hydraulic fracturing reconstruction.
Considering the oil-water two-phase flow, a continuity equation of two-phase seepage can be established according to a mass conservation equation:
where φ is porosity; ρ is the fluid density; q is a source or sink; u. of*The flow channeling quantity between the matrix and the fracture; t is time.
The flow of oil and water conforms to Darcy's law:
the equation of continuity for oil and water in the matrix is:
the cross-flow of the matrix and the natural fracture is:
the quasi-steady state cross flow factor is:
wherein k is the permeability; l isx,Ly,LzThe size of the matrix in the x, y and z directions; μ is the fluid viscosity; k is a radical ofrIs the relative permeability; subscripts m, f, w, o, represent matrix, natural fracture, water, oil.
The unsteady state cross flow factor is:
the auxiliary equation is:
Sof+Swf＝1 (9)
pcowf＝pof-pwf(10)
Som+Swm＝1 (11)
pcowm＝pom-pwm(12)
wherein S is not saturated; p is a radical ofcIs the capillary pressure.
And (3) establishing an embedded discrete fracture and continuous medium mixed numerical simulation mathematical model, wherein the hydraulic fracture is processed by using the embedded discrete fracture model, the mass transfer between the natural fracture and the matrix in the reservoir is processed by using a dual medium model, and the unsteady state flow channeling is considered in the flow channeling between the natural fracture and the matrix.
And (3) dispersing the continuity equation by using a full-implicit method:
wherein:
wherein, VbIs the grid volume; q is a source and sink item; t isfFor conductivity, the typical density ρ and viscosity μ are obtained using an arithmetic average;
calculating by utilizing a harmonic mean value; k is a radical ofrObtained by an upstream windward method.
Constructing an embedded discrete crack and continuous medium model mixed numerical simulation model, including a single-phase or oil-water two-phase flow numerical simulation model, and solving;
by adding non-adjacent links, the continuity equation is refined:
wherein q isNComprises the following steps:
and (5) predicting the yield of different fracturing fractures of the shale oil reservoir by using the model.
Case analysis
Example 1:
analyzing the fracturing construction condition of a shale oil reservoir, determining the property of hydraulic fractures in a fracturing modification area, and performing explicit characterization on the hydraulic fractures. Fig. 4 is a geological model of the present example, and the basic parameters of the model are as shown in fig. 10, wherein 3 hydraulic fractures and 20 large-scale natural fractures are developed.
And (2) establishing a seepage mathematical model of the hydraulic fracture-natural fracture and the matrix after hydraulic fracturing reconstruction. The seepage mathematical model is fully referenced to equations (1) (2).
And (3) establishing an embedded discrete fracture and continuous medium mixed numerical simulation mathematical model, wherein the hydraulic fracture is processed by using the embedded discrete fracture model, the mass transfer between the natural fracture and the matrix in the reservoir is processed by using a dual medium model, and the unsteady state flow channeling is considered in the flow channeling between the natural fracture and the matrix. The model final form is referred to equation (23).
And (4) constructing an embedded discrete crack and continuous medium model mixed numerical simulation model, including a single-phase or oil-water two-phase flow numerical simulation model, and solving. The solving process is shown in figure 3.
And (5) predicting the yield of different seam network reconstruction conditions of the compact reservoir by using the model. The yields are shown in FIG. 5.
Example 2:
analyzing the fracturing construction condition of a shale oil reservoir, determining the property of hydraulic fractures in a fracturing modification area, and performing explicit characterization on the hydraulic fractures. Fig. 7 is a geological model of the present example, with the basic parameters of the model shown in fig. 11, in which multiple hydraulic fractures are developed.
And (2) establishing a seepage mathematical model of the hydraulic fracture-natural fracture and the matrix after hydraulic fracturing reconstruction. The seepage mathematical model is fully referenced to equations (1) (2).
And (3) establishing an embedded discrete fracture and continuous medium mixed numerical simulation mathematical model, wherein the hydraulic fracture is processed by using the embedded discrete fracture model, the mass transfer between the natural fracture and the matrix in the reservoir is processed by using a dual medium model, and the unsteady state flow channeling is considered in the flow channeling between the natural fracture and the matrix. The model final form is referred to equation (23).
And (4) constructing an embedded discrete crack and continuous medium model mixed numerical simulation model, including a single-phase or oil-water two-phase flow numerical simulation model, and solving. The solving process is shown in figure 3.
And (5) predicting the yield of different seam network reconstruction conditions of the compact reservoir by using the model. The yields are shown in FIG. 9.
Although the present disclosure has been described with reference to specific embodiments, it should be understood that the scope of the present disclosure is not limited thereto, and those skilled in the art will appreciate that various modifications and changes can be made without departing from the spirit and scope of the present disclosure.
Claims (10)
1. A shale oil complex seam network discrete fracture continuous medium mixed numerical simulation method is characterized by comprising the following steps:
analyzing the fracturing construction condition of a shale oil reservoir, determining the property of hydraulic fractures in a fracturing modification area, and performing explicit characterization on the hydraulic fractures;
establishing a seepage mathematical model of the hydraulic fracture-natural fracture and matrix after hydraulic fracturing modification;
establishing an embedded discrete fracture and continuous medium mixed numerical simulation mathematical model, wherein the hydraulic fracture is processed by using the embedded discrete fracture model, and the mass transfer between the natural fracture and the matrix in the reservoir is processed by using a dual medium model;
constructing an embedded discrete crack and continuous medium model mixed numerical simulation model, including a single-phase or oil-water two-phase flow numerical simulation model, and solving;
and (5) predicting the yield of different seam network reconstruction conditions of the tight reservoir by using the seepage mathematical model, the simulation mathematical model and the numerical simulation model.
2. The continuous-media-blending numerical simulation method of claim 1, wherein step (1) determines a fracture-modified zone of the shale oil reservoir by in-situ microseismic analysis, taking into account matrix-natural fracture-hydraulic fracture-wellbore flow in the modified zone and matrix-natural fracture flow in the non-fracture modified zone.
3. The continuous medium mixing numerical simulation method of claim 1, wherein step (2) establishes a mathematical model of hydraulic fracture-natural fracture and matrix seepage in the fracture-modified zone, and simultaneously establishes a mathematical model of natural fracture and matrix seepage in the unmodified zone.
4. The continuous medium mixed numerical simulation method of claim 1, wherein step (3) establishes an embedded discrete fracture and continuous medium model mixed simulation mathematical model; the flow between the hydraulic fracture and the natural fracture is processed using an embedded discrete fracture model, the flow between the matrix and the natural fracture being defined by a dual-media model.
5. The continuous medium mixing numerical simulation method of claim 1, wherein the step (4) constructs an oil-water two-phase flow numerical simulation model for embedded discrete fracture and continuous medium model mixing numerical simulation, oil-water seepage mathematical models in different media are dispersed by a finite volume method, time terms are processed by backward first-order Euler difference, and after a nonlinear solving system is constructed, solving is performed, and solving variables comprise pressure and water saturation of a matrix grid, a natural fracture grid, a hydraulic fracture grid and well yield.
6. The continuous medium mixed numerical simulation method of claim 1, wherein different reservoir reconstruction geological models are established in the step (5), including a multi-stage fractured horizontal well model with double-wing fractures and a complex fractured horizontal well model, and the models are solved through the steps (1) to (4), so that a yield change curve of a well is obtained; and analyzing the distribution characteristics of the residual oil at different moments by using the simulation result.
7. The continuous-media mixing numerical simulation method of claim 2, wherein the flow capacities in different media are the strongest in the hydraulic fracture and the weakest in the matrix; and (4) performing explicit treatment on the hydraulic fracture, and defining the fracture length, the fracture morphology and the fracture conductivity of the hydraulic fracture.
8. The continuous media mixing numerical simulation method of claim 3, wherein the percolation mathematical model has the following assumptions:
(1) the fluid flows through the matrix, the natural fracture, the hydraulic fracture and the shaft in sequence, and the non-transformation area supplies liquid to the transformation area;
(2) the flow is carried out under isothermal conditions;
(3) the flow of fluid in different media all follows Darcy's law;
(4) the channeling between the matrix and the natural fracture is unsteady channeling;
(5) the flow conductivity of the hydraulic fracture is far greater than that of a natural fracture;
(6) oil or water is a slightly compressible fluid and the production conditions of the well are constant pressure, or constant production.
9. The continuous medium mixing numerical simulation method of claim 4, wherein the matrix-natural fracture-hydraulic fracture is spatially dispersed, a set of grid systems are applied to the matrix grid and the natural fracture grid in the dispersion process, and the hydraulic fracture is automatically dispersed according to the boundary of the natural fracture grid;
five types of link relationships need to be defined in the calculation process: a linkage of the matrix mesh and the natural fracture mesh; natural fracture grids and links between the natural fracture grids; the hydraulic fracture units in the same natural fracture grid are linked with each other; the hydraulic fracture units in different natural fracture grids are linked with each other; a link between the natural fracture grid and the hydraulic fracture cells; a complete discrete numerical simulation model can be obtained by adding links to the discrete equations.
10. The continuous-media mixing numerical simulation method of claim 9, wherein a continuity equation of fluid flow in the matrix, the natural fracture, and the hydraulic fracture in the modified zone is established based on the assumptions, and a flow equation for the hydraulic fracture and the wellbore is established; meanwhile, establishing a flow continuity equation of the matrix and the natural fracture in the non-transformation area; and establishing a flow exchange equation between the matrix and the natural fracture by defining an unsteady flow channeling factor.
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