CN112685970B - Quantitative characterization method and system for seepage interface of flow unit of water-drive reservoir - Google Patents
Quantitative characterization method and system for seepage interface of flow unit of water-drive reservoir Download PDFInfo
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Abstract
The invention discloses a method and a system for quantitatively characterizing a seepage interface of a flow unit of a water-drive oil reservoir, which relate to the technical field of oil field exploitation and comprise the following steps: establishing an oil reservoir model for an oil reservoir to be predicted; the oil reservoir model comprises a two-dimensional oil reservoir model and a three-dimensional oil reservoir model; determining a velocity field and a saturation field of oil-water two phases in the oil reservoir model according to an oil-water two-phase seepage equation; determining a plurality of flow lines which are emitted by the water injection well and converged on the oil production well according to a Pollock flow line tracking method and the speed field; determining a seepage interface according to all the flow lines; the seepage interface comprises a speed difference interface and a saturation difference interface; dividing flow units according to the seepage interface; and determining the oil-water distribution condition according to the divided flow units. The method can quantitatively represent the dynamic seepage interface in the water-drive reservoir oil displacement process and quantitatively depict the evolution process of the seepage interface of the flow unit of the water-drive reservoir oil displacement, thereby accurately determining the oil-water distribution condition.
Description
Technical Field
The invention relates to the technical field of oilfield exploitation, in particular to a method and a system for quantitatively characterizing a seepage interface of a flow unit of a water-drive reservoir.
Background
In the development stage of ultrahigh water content, the stratum is washed by water injection for a long time, the heterogeneity of the stratum structure is enhanced, the geological conditions are extremely complex, so that different movement laws of injected water, water flooding characteristics and displacement degrees can be formed in the oil layer, the phenomena of oil-water flow difference and residual oil dispersion and enrichment in the oil reservoir become severe day by day, and finally the difficulty of residual oil exploitation is increased, so that the deep research on the distribution law of residual oil and the seepage law of oil-water two phases is needed, the flow process of the oil-water two phases in the stratum is finely depicted, and the important theoretical basis can be provided for the residual oil exploitation.
In essence, the flow cells are reservoir cells with similar seepage characteristics, different cells have different seepage characteristics, and the interfaces between cells are seepage barrier interfaces that are separated into several connected bodies within the reservoir and seepage differential interfaces within the connected bodies. At present, the static research viewpoint is more than the dynamic viewpoint in the research of the flow cell, but during the development process, the pore structure and permeability of the reservoir, the water injection rate, the bottom hole pressure, etc. may change dynamically, so the seepage difference of the reservoir communication body also changes correspondingly, and the type of the flow cell also changes. Therefore, the flow cell can be regarded as a dynamic concept, and it is difficult to recognize and research the flow cell with a static view corresponding to the dynamic development practice of the oil field, because the static view characterizes the seepage interface and divides the flow cell according to the difference of geological parameters such as permeability, porosity, etc., and the seepage interface is not changed. However, during the development process, the pore structure and permeability, the water injection rate, the bottom hole pressure, etc. may change dynamically, so the seepage difference of the reservoir communication bodies may also change correspondingly, and the types of the flow units may also change.
In summary, the existing method focuses on dividing the flow unit by using static parameters, does not consider the change of the flow field speed and the saturation along with time, cannot represent the changed seepage interface of the flow unit at different moments, can only be used for predicting the residual oil, and cannot be used for researching the underground oil-water distribution rule and the residual oil distribution prediction. In order to make reservoir development adjustment based on a flow unit, a quantitative characterization method for a water-drive reservoir flow unit seepage interface is urgently needed in the field, a dynamic seepage interface in a water-drive reservoir process is quantitatively characterized, and an evolution process of the water-drive reservoir flow unit seepage interface is quantitatively depicted, so that the underground oil-water distribution condition is accurately determined, and the distribution condition of residual oil is accurately predicted.
Disclosure of Invention
The invention aims to provide a method and a system for quantitatively characterizing a seepage interface of a flow unit of a water-drive reservoir, which can quantitatively characterize a dynamic seepage interface of a water-drive reservoir process and quantitatively depict an evolution process of the seepage interface of the flow unit of the water-drive reservoir, thereby accurately determining the oil-water distribution condition.
In order to achieve the purpose, the invention provides the following scheme:
a method for quantitatively characterizing a seepage interface of a flow unit of a water-flooding reservoir, which comprises the following steps:
establishing an oil reservoir model for an oil reservoir to be predicted; the oil reservoir model comprises a two-dimensional oil reservoir model and a three-dimensional oil reservoir model;
determining a velocity field and a saturation field of oil-water two phases in the oil reservoir model according to an oil-water two-phase seepage equation;
determining a plurality of flow lines which are emitted by the water injection well and converged on the oil production well according to a Pollock flow line tracking method and the speed field;
determining a seepage interface according to all the flow lines; the seepage interface comprises a speed difference interface and a saturation difference interface;
dividing flow units according to the seepage interface;
and determining the oil-water distribution condition according to the divided flow units.
Optionally, the determining a seepage interface according to all the flow lines specifically includes:
when the oil reservoir model is a two-dimensional oil reservoir model, calculating the average value of positive direction velocity gradients and the average value of negative direction velocity gradients on each streamline;
taking the streamline corresponding to the maximum positive direction speed gradient average value as a first streamline;
taking the streamline corresponding to the maximum negative direction speed gradient average value as a second streamline;
taking a closed curve formed by the first flow line and the second flow line as a speed difference interface;
calculating the positive direction saturation gradient average value and the negative direction saturation gradient average value on each streamline;
taking the streamline corresponding to the maximum positive direction saturation gradient average value as a third streamline;
taking the streamline corresponding to the maximum negative direction saturation gradient average value as a fourth streamline;
and taking a closed curve formed by the third streamline and the fourth streamline as a saturation difference interface.
Optionally, the determining a seepage interface according to all the flow lines specifically includes:
when the oil reservoir model is a three-dimensional oil reservoir model, determining a midpoint of a connecting line of the water injection well and the oil production well;
determining a section passing through the midpoint and perpendicular to the line;
calculating a first flux through the cross section;
determining a plurality of velocity contours from the velocity field; each of said velocity contours forming a first closed region;
calculating a second flux flowing through each of the first closed regions; the first flux and the second flux each comprise two fluids, oil and water, the amounts of the two fluids being unequal;
calculating the ratio of the second flux to the first flux to obtain a flux ratio;
calculating the flux ratio variable quantity corresponding to each speed contour line according to the flux ratio;
taking the speed contour corresponding to the maximum flux ratio variation as a first speed contour;
taking a curved surface formed by extending the first speed contour line along the flow line as a speed difference interface;
calculating a first water cut through the cross-section;
determining a plurality of saturation contours according to the saturation field; each saturation contour constitutes a second closed area;
calculating a second moisture content flowing through each of the second enclosed regions;
calculating the ratio of the second water content to the first water content to obtain a water content ratio;
calculating the variation of the water cut ratio corresponding to each saturation contour according to the water cut ratio;
taking the saturation contour corresponding to the maximum moisture ratio variation as a first saturation contour;
and taking a curved surface formed by extending the first saturation contour line along the flow line as a saturation difference interface.
Optionally, the dividing the flow unit according to the seepage interface specifically includes:
determining an area within the velocity difference interface and within the saturation difference interface as a first flow cell;
determining a region outside the velocity difference interface and within the saturation difference interface as a second flow cell;
determining a region within the velocity difference interface and outside the saturation difference interface as a third flow cell;
determining a region outside the velocity difference interface and outside the saturation difference interface as a fourth flow cell.
The invention also provides the following scheme:
a system for quantitatively characterizing a water drive reservoir flow cell seepage interface, the system comprising:
the reservoir model establishing module is used for establishing a reservoir model for the reservoir to be predicted; the oil reservoir model comprises a two-dimensional oil reservoir model and a three-dimensional oil reservoir model;
the velocity field and saturation field determining module is used for determining the velocity field and the saturation field of the oil-water two-phase in the oil reservoir model according to an oil-water two-phase seepage equation;
the flow line determining module is used for determining a plurality of flow lines which are sent out by the water injection well and converged to the oil production well according to the Pollock flow line tracking method and the speed field;
the seepage interface determining module is used for determining seepage interfaces according to all the flow lines; the seepage interface comprises a speed difference interface and a saturation difference interface;
the flow unit dividing module is used for dividing flow units according to the seepage interface;
and the oil-water distribution condition determining module is used for determining the oil-water distribution condition according to the divided flow units.
Optionally, the seepage interface determining module specifically includes:
the speed gradient average value calculating unit is used for calculating a positive direction speed gradient average value and a negative direction speed gradient average value on each streamline when the oil reservoir model is a two-dimensional oil reservoir model;
the first streamline determining unit is used for taking the streamline corresponding to the maximum positive direction speed gradient average value as a first streamline;
the second streamline determining unit is used for taking the streamline corresponding to the maximum negative direction speed gradient average value as a second streamline;
a speed difference interface determining unit, configured to use a closed curve formed by the first flow line and the second flow line as a speed difference interface;
the saturation gradient average value calculating unit is used for calculating a positive direction saturation gradient average value and a negative direction saturation gradient average value on each streamline;
the third flow line determining unit is used for taking the flow line corresponding to the maximum positive direction saturation gradient average value as a third flow line;
the fourth streamline determining unit is used for taking the streamline corresponding to the maximum negative direction saturation gradient average value as a fourth streamline;
and the saturation difference interface determining unit is used for taking a closed curve formed by the third streamline and the fourth streamline as a saturation difference interface.
Optionally, the seepage interface determining module specifically includes:
the connecting line midpoint determining unit is used for determining the midpoint of the connecting line of the water injection well and the oil production well when the oil reservoir model is a three-dimensional oil reservoir model;
a section determining unit for determining a section passing through the midpoint and perpendicular to the connection line;
a first flux calculating unit for calculating a first flux flowing through the cross section;
a velocity contour determination unit for determining a plurality of velocity contours from the velocity field; each of said velocity contours forming a first closed region;
a second flux calculation unit for calculating a second flux flowing through each of the first closed regions; the first flux and the second flux each comprise two fluids, oil and water, the amounts of the two fluids being unequal;
the flux ratio calculating unit is used for calculating the ratio of the second flux to the first flux to obtain a flux ratio;
the flux ratio variation calculating unit is used for calculating the flux ratio variation corresponding to each speed contour according to the flux ratio;
a first speed contour determining unit for taking a speed contour corresponding to the maximum flux ratio variation as a first speed contour;
the speed difference interface determining unit is used for taking a curved surface formed by extending the first speed contour line along the flow line as a speed difference interface;
a first water content calculation unit for calculating a first water content flowing through the cross section;
a saturation contour determining unit for determining a plurality of saturation contours according to the saturation field; each saturation contour constitutes a second closed area;
a second water content calculation unit for calculating a second water content flowing through each of the second closed regions;
the water content ratio calculating unit is used for calculating the ratio of the second water content to the first water content to obtain the water content ratio;
the water cut ratio variation calculating unit is used for calculating the water cut ratio variation corresponding to each saturation contour according to the water cut ratio;
a first saturation contour determining unit configured to take a saturation contour corresponding to the maximum moisture ratio variation as a first saturation contour;
and the saturation difference interface determining unit is used for taking a curved surface formed by extending the first saturation contour line along the flow line as a saturation difference interface.
Optionally, the flow cell dividing module specifically includes:
a first flow cell determination unit for determining an area within the speed difference interface and within the saturation difference interface as a first flow cell;
a second flow cell determination unit for determining a region outside the speed difference interface and within the saturation difference interface as a second flow cell;
a third flow cell determination unit for determining an area within the velocity difference interface and outside the saturation difference interface as a third flow cell;
a fourth flow cell determination unit for determining a region outside the velocity difference interface and outside the saturation difference interface as a fourth flow cell.
According to the specific embodiment provided by the invention, the invention discloses the following technical effects:
the invention discloses a method and a system for quantitatively characterizing a seepage interface of a flow unit of a water-drive oil reservoir. The method has the advantages that the flow line is determined through an oil-water two-phase seepage equation and a Pollock flow line tracking method, the seepage interface is determined through the flow line, the dynamic seepage interface in the water flooding process can be quantitatively represented, the evolution process of the seepage interface of a flow unit of the water flooding reservoir is quantitatively depicted, and therefore the oil-water distribution condition is accurately determined, and the method has great practical significance for researching the underground oil-water distribution rule and the distribution prediction of residual oil.
Drawings
In order to more clearly illustrate the embodiments of the present invention or the technical solutions in the prior art, the drawings needed to be used in the embodiments will be briefly described below, and it is obvious that the drawings in the following description are only some embodiments of the present invention, and it is obvious for those skilled in the art to obtain other drawings without inventive exercise.
FIG. 1 is a flow chart of an embodiment of a method for quantitatively characterizing a seepage interface of a flow unit of a water-drive reservoir according to the present invention;
FIG. 2 is a schematic diagram of a quantitative characterization method for reservoir flow lines and seepage interfaces of a two-dimensional two-point well pattern according to the present invention;
FIG. 3 is a schematic diagram of a quantitative characterization method for a three-dimensional two-point well pattern reservoir streamline and a seepage interface according to the present invention;
FIG. 4 is a schematic diagram of the method for quantitatively characterizing the seepage interface of the flow unit of the water-drive reservoir according to the present invention;
FIG. 5 is a structural diagram of an embodiment of a seepage interface quantitative characterization system of a flow unit of a water-drive reservoir according to the present invention.
Detailed Description
The technical solutions in the embodiments of the present invention will be clearly and completely described below with reference to the drawings in the embodiments of the present invention, and it is obvious that the described embodiments are only a part of the embodiments of the present invention, and not all of the embodiments. All other embodiments, which can be obtained by a person skilled in the art without making any creative effort based on the embodiments in the present invention, belong to the protection scope of the present invention.
The invention aims to provide a method and a system for quantitatively characterizing a seepage interface of a flow unit of a water-drive reservoir, which can quantitatively characterize a dynamic seepage interface of a water-drive reservoir process and quantitatively depict an evolution process of the seepage interface of the flow unit of the water-drive reservoir, thereby accurately determining the oil-water distribution condition.
In order to make the aforementioned objects, features and advantages of the present invention more comprehensible, the present invention is described in detail with reference to the accompanying drawings and the detailed description thereof.
FIG. 1 is a flowchart of an embodiment of a method for quantitatively characterizing a seepage interface of a flow unit of a water-drive reservoir according to the present invention. FIG. 4 is a schematic diagram of the method for quantitatively characterizing the seepage interface of the flow unit of the water-drive reservoir. Referring to fig. 1 and 4, the method for quantitatively characterizing the seepage interface of the flow unit of the water-drive reservoir comprises the following steps:
step 101: establishing an oil reservoir model for an oil reservoir to be predicted; the reservoir model comprises a two-dimensional reservoir model and a three-dimensional reservoir model.
Step 102: and determining the velocity field and the saturation field of the oil-water two-phase in the oil reservoir model according to the oil-water two-phase seepage equation.
According to the process shown in fig. 4, in step 102, a two-dimensional oil-water two-phase seepage equation is used to determine a two-dimensional oil-water two-phase velocity field and a two-dimensional saturation field in the oil reservoir corresponding to the two-dimensional oil reservoir model, and a three-dimensional oil-water two-phase seepage equation is used to determine a three-dimensional oil reservoir model. An oil-water two-phase seepage equation is an oil-water two-phase seepage numerical model, and a speed field and a saturation field are solved by applying the oil-water two-phase seepage numerical model. The velocity field and saturation field are used to resolve streamlines, velocity and saturation distributions within the reservoir and thus the differential interface. The saturation field comprises an aqueous saturation field.
In step 102, the two-dimensional oil-water two-phase seepage equation and the three-dimensional oil-water two-phase seepage equation are both the existing oil-water two-phase model seepage control equation (oil-water two-phase seepage numerical model), and the oil phase:
wherein k is the absolute permeability (md), k ro Is the relative permeability of the oil phase, p o Is the density of oil phase (g/cm) 3 )，μ o As the viscosity of the oil phase (mPas), p o Is the oil phase pressure (Mp), γ o ＝ρ o g, g is acceleration of gravity (m/s) 2 ) D is the distance (m) from the reference plane, phi is the porosity, S o Is the degree of oil saturation, q o The oil phase flow rate. Water phase:
wherein k is the absolute permeability (md), k rw Is the relative permeability of the aqueous phase, p w As density of aqueous phase (g/cm) 3 )，μ w As aqueous phase viscosity (mPas), p w As the pressure of the aqueous phase (Mp), γ w ＝ρ w g, g is acceleration of gravity (m/s) 2 ) D is the distance (m) from the reference plane, phi is the porosity, S w Is the water saturation, q w Is the water phase flow rate, v means gradient.
Step 103: determining a plurality of flow lines emanating from the injection well and converging on the production well according to Pollock flow line tracking method and the velocity field.
The step 103 determines a flow line by a flow line tracking method, determines a two-dimensional flow line which is emitted by the water injection well and converged to the production well according to a Pollock flow line tracking method, and determines a three-dimensional flow line which is emitted by the water injection well and converged to the production well according to the Pollock flow line tracking method. And describing the oil-water two-phase displacement process by using a Pollock flow line tracking method.
Step 104: determining a seepage interface according to all the flow lines; the percolation interface includes a velocity difference interface and a saturation difference interface.
In step 104, a dynamic interface capture method is applied to quantitatively represent the seepage interface of the flow unit on the basis of the former two method models, namely an oil-water two-phase seepage numerical model (an oil-water two-phase seepage equation) and a streamline tracing method (a pollock streamline tracing method). FIG. 2 is a schematic diagram of a quantitative characterization method for two-dimensional two-point well pattern reservoir flow lines and seepage interfaces. FIG. 3 is a schematic diagram of a quantitative characterization method for a three-dimensional two-point well pattern reservoir streamline and a seepage interface.
Referring to fig. 2 and 3, the step 104 specifically includes a two-dimensional reservoir flow unit seepage interface quantitative characterization method and a three-dimensional reservoir flow unit seepage interface quantitative characterization method. The quantitative characterization of the seepage interface of the two-dimensional reservoir flow unit is realized on the basis of a two-dimensional streamline, and the quantitative characterization of the seepage interface of the three-dimensional reservoir flow unit is realized on the basis of a three-dimensional streamline.
The quantitative characterization method of the seepage interface of the two-dimensional oil reservoir flow unit specifically comprises the following steps:
and when the oil reservoir model is a two-dimensional oil reservoir model, calculating the average value of the positive direction velocity gradient and the average value of the negative direction velocity gradient on each streamline. As shown in fig. 2, according to the characteristic of large difference of flow velocities at two sides of the velocity difference interface, the average value of velocity gradients in the positive direction on each streamline between the injection and production wells is obtained
And negative direction velocity gradient mean on each streamline
Wherein: s i Representing any flow line between the injection and production wells; u is speed, unit m/s; n is + Is a positive normal distance, in m; n is a radical of an alkyl radical - Is the negative normal distance, in m.
And taking the streamline corresponding to the maximum positive direction speed gradient average value as a first streamline. The maximum value of the average positive direction velocity gradient of each streamline is calculated and compared, and the interface C in figure 2 1 One of the streamlines S 1 Mean value of positive direction velocity gradient
Is composed of
Maximum value of (1), S 1 The streamline with the maximum positive direction speed gradient average value is the streamline S 1 Is the first flow line.
And taking the streamline corresponding to the maximum negative direction speed gradient average value as a second streamline. The average negative direction velocity gradient maxima for each streamline are compared, another streamline S of interface C1 in FIG. 2 2 Average value of velocity gradient in negative direction of
Is composed of
Maximum value of (1), S 2 The streamline with the maximum average value of the velocity gradient in the negative direction is the streamline S 2 Is the second flow line.
And taking a closed curve formed by the first flow line and the second flow line as a speed difference interface. Interface C in FIG. 2 1 I.e. a speed difference interface, interface C 1 Internal high velocity flow cell, interface C 1 The outside is a low-speed flow unit.
Calculate each of saidPositive direction saturation gradient mean and negative direction saturation gradient mean on the flow line. According to the characteristic of large difference of water saturation on two sides of the saturation difference interface, solving the mean value of saturation gradient in the positive direction on each streamline between the injection and production wells
And negative direction saturation gradient mean on each streamline
Wherein: s w The water saturation.
And taking the streamline corresponding to the maximum positive direction saturation gradient average value as a third streamline. The maximum value of the saturation gradient in the average positive direction of each streamline is calculated and compared, and the interface C in FIG. 2 2 One of the streamlines S 3 Mean value of saturation gradient in upward positive direction
Is composed of
Maximum value of (1), S 3 The streamline S is the streamline with the maximum mean value of saturation gradients in the positive direction 3 Is the third flow line.
And taking the streamline corresponding to the maximum negative direction saturation gradient average value as a fourth streamline. The average negative direction saturation gradient maximum value of each streamline is compared, and the interface C in figure 2 2 Another streamline S of 4 Mean value of saturation gradient in negative direction of
Is composed of
Maximum value of (1), S 4 The streamline S is the streamline with the maximum average value of the saturation gradient in the negative direction 4 Is the fourth flow line.
Taking a closed curve formed by the third streamline and the fourth streamline as saturationAnd a degree difference interface. Interface C in FIG. 2 2 I.e. saturation difference interface, interface C 2 Internal high water content flow cell, interface C 2 The outside is a high oil (low water) flow cell.
The quantitative characterization method of the seepage interface of the three-dimensional oil reservoir flow unit specifically comprises the following steps:
and when the oil reservoir model is a three-dimensional oil reservoir model, determining the midpoint of a connecting line of the water injection well and the oil production well.
A cross-section through the midpoint and perpendicular to the line is determined. And drawing a section perpendicular to the connecting line of the injection and production wells through the midpoint of the connecting line of the injection and production wells, wherein the section is a main section. Plane 5 in fig. 3 is the main section through the midpoint of the injection-production well line and perpendicular to the injection-production well line.
A first flux flowing through the cross section is calculated.
Determining a plurality of velocity contours from the velocity field; each of the velocity contours constitutes a first closed region.
Calculating a second flux flowing through each of the first closed regions; the first flux and the second flux each comprise two fluids, oil and water, the amounts of the two fluids being unequal.
And calculating the ratio of the second flux to the first flux to obtain a flux ratio.
And calculating the flux ratio variable quantity corresponding to each speed contour line according to the flux ratio. As shown in FIG. 3, the velocity field is determined on the main section (the range of velocity field is different from one example to another, generally 10) -7 -10 -5 m/s), the ratio of the flux in the speed contour line to the total flux of the section, the speed contour line is uniformly valued from small to large, and the variation of the flux ratio is solved
Wherein: a. the i Representing any one velocity contour; u is the speed, i.e. the value of the speed contour: the total oil-water velocity is in m/s; q is the flux ratio. The velocity contour can be obtained by obtaining the velocity field of the cross section, and the value of the velocity contour is obtained from the minimum value of the velocity field and is uniformly increased. The velocity contour being closedAnd in the curve, a small-value speed contour line is close to the outer side of the section, a large-value speed contour line is close to the inner side of the section, and the contour lines are equally spaced from the minimum value to the maximum value of the speed field on the section. The flux flowing through the speed contour line on the section is smaller than the flow of the water injection well flowing to the production well.
And taking the speed contour corresponding to the maximum flux ratio variation as a first speed contour. The flux ratio in the isoline with a small speed value is large, the isoline value is uniformly increased, the flux ratio is reduced, the variable quantity of the flux ratio surrounded by the two adjacent speed isolines with the values is solved until the speed with the largest section is obtained, the maximum value of the variable quantity of the flux ratio is found, and the isoline after the change is obtained. Contour line A in FIG. 3 1 Flux ratio variation of
Is composed of
Maximum value of (1), A 1 Is the velocity contour, contour A, of maximum flux ratio variation across the section 1 I.e. the first velocity contour.
And taking a curved surface formed by extending the first speed contour line along the flow line as a speed difference interface. Contour line A in FIG. 3 1 Extend along the streamline to form a three-dimensional speed difference interface C 1 Interface C 1 Inner high velocity flow cell, interface C 1 The outside is a low-speed flow unit. The speed difference interface C in the three-dimensional oil reservoir model 1 Is a velocity contour line A on a main section between injection wells and production wells 1 And the curved surface extends along the streamline.
A first moisture content is calculated for flow through the cross-section. And multiplying the water saturation of the cross section by the area of the cross section to obtain the water content. And the water saturation of the section is calculated according to an oil-water two-phase seepage equation.
Determining a plurality of saturation contours according to the saturation field; each of the saturation contours constitutes a second closed area. And (4) solving a water saturation field of the section to obtain a water saturation contour, wherein the value of the water saturation contour is obtained from the minimum value of the water saturation field and is uniformly increased.
Calculating a second moisture content flowing through each of the second enclosed regions.
And calculating the ratio of the second water content to the first water content to obtain the water content ratio.
And calculating the water cut ratio variation corresponding to each saturation contour according to the water cut ratio. By calculating the saturation field (different calculation examples have different ranges of the water content saturation field, generally 0.2-0.8) on the main section, the ratio of the water content in the saturation contour line to the total water content of the section, the saturation contour line uniformly takes values from small to large, and the variation of the water content ratio is calculated
Wherein: r w Is a water content ratio, S w Is the value of the water saturation, namely the isoline of the water saturation. The water saturation contour is a closed curve, the water saturation contour with small value is close to the outer side of the section, the water saturation contour with large value is close to the inner side of the section, and the contour is taken from the minimum value of the water saturation field on the section to the maximum value at equal intervals.
And taking the saturation contour corresponding to the maximum water ratio variation as a first saturation contour. The water content ratio in the isoline with small water saturation value is large, the isoline value is uniformly increased, the water content ratio is reduced, the variation quantity of the water content ratio surrounded by the isolines with adjacent water saturation values is calculated until the water saturation with the largest section is obtained, the maximum value of the variation quantity of the water content ratio is found, and the isoline after variation is obtained. Contour line A in FIG. 3 2 Change in water ratio of (2)
Is composed of
Maximum value of (1), A 2 Is a saturation contour with maximum water ratio variation on the section, contour A 2 I.e. the first saturation contour.
And taking a curved surface formed by extending the first saturation contour line along the flow line as a saturation difference interface. Contour line A in FIG. 3 2 Extend along the streamline to form a three-dimensional saturation difference interface C 2 Interface C 2 Internal high water content flow cell, interface C 2 The outside is a high oil (low water) flow cell. A saturation difference interface C in the three-dimensional oil reservoir model 2 Is a saturation contour line A on a main section between injection wells and production wells 2 And the curved surface extends along the streamline.
Step 105: and dividing the flow unit according to the seepage interface.
The step 105 specifically includes:
determining an area within the speed difference interface and within the saturation difference interface as a first flow cell.
Determining an area outside the velocity difference interface and within the saturation difference interface as a second flow cell.
Determining a region within the velocity difference interface and outside the saturation difference interface as a third flow cell.
Determining a region outside the velocity difference interface and outside the saturation difference interface as a fourth flow cell.
Whereby the flow cell is divided by a velocity difference interface and a saturation difference interface, at interface C 1 In and at interface C 2 The inner zone (first flow cell) is a high-speed high-water-content flow cell (e.g. zone 1 in FIG. 2), at the interface C 1 Outside and at the interface C 2 The inner zone (second flow cell) is a low velocity high water containing flow cell (e.g. zone 2 in fig. 2), at interface C 1 In and at the interface C 2 The outer zone (third flow cell) is a high velocity high oil (low water) flow cell (e.g., zone 3 in FIG. 2), at interface C 1 Outside and at interface C 2 The outer zone (fourth flow element) is a low velocity high oil (low water) flow element (as in zone 4 of fig. 2). The method for dividing the flow cells in step 105 is written as wuman and zhuyiweyiwei according to the name "effective flow cell dividing method and flow field dynamic change characteristicsThe method for dividing the flow units is described in the prior publications of the stony patent and the leaf-root, as shown in fig. 9 in the effective flow unit dividing method and the dynamic change characteristics of the flow field, four types of flow units are divided according to streamlines, namely, when the oil reservoir model is a two-dimensional oil reservoir model, an interface C consisting of a first streamline and a second streamline is determined according to the first streamline and the second streamline 1 Internal high velocity flow cell, interface C 1 The outside is a low-speed flow unit. Similarly, the interface C formed by the third streamline and the fourth streamline is determined according to the third streamline and the fourth streamline 2 Internal high water content flow cell, interface C 2 The outside is a high oil (low water) flow cell. The reservoir model is a three-dimensional reservoir model and the same. According to the common knowledge in the art, the velocities and the water saturations of the two sides in the water flooding process are necessarily lower than those of the middle part, the velocity difference interface is the interface with the largest velocity difference (low velocity and high velocity difference), and the saturation difference interface is the interface with the largest water saturation difference (low water content and high water content difference), so that the flow units are divided based on the above basis to obtain the first flow unit, the second flow unit, the third flow unit and the fourth flow unit.
The dynamic interface capturing method, that is, the method in step 104, characterizes the seepage interface and divides the flow units according to the enlightenment of the Level Set symbolic distance function, and the function expression is:
in the formula, C is a seepage interface, in the two-dimensional oil reservoir model, the seepage interface C is a curve, and in the three-dimensional oil reservoir model, the seepage interface C is a curved surface; d is the distance from coordinate point (x, y) to interface C.
The seepage interface C is composed of a speed difference interface C 1 And saturation difference interface C 2 Common composition (control), at interface C 1 In and at the interface C 2 The inner zone is a high-speed high-water-content flow unit at the interface C 1 Outside and in the worldNoodle C 2 The inner zone is a low-speed high-water-content flow unit at the interface C 1 In and at interface C 2 The outer region is a high-speed high-oil-content flow unit at an interface C 1 Outside and at the interface C 2 The outer zone is a low velocity high oil containing flow cell. The velocity difference interface C1 in the two-dimensional reservoir model is two flow lines between injection wells (selected from all flow lines between injection wells) and the saturation difference interface C2 in the two-dimensional reservoir model is two flow lines between injection wells (selected from all flow lines between injection wells).
Step 106: and determining the oil-water distribution condition according to the divided flow units.
The method comprises an oil-water two-phase seepage numerical model, a streamline tracing method and a dynamic interface capturing method, can quantitatively represent the dynamic seepage interface in the water flooding process, and has great practical significance for researching the underground oil-water distribution rule and the distribution prediction of residual oil. In order to guide the formulation of an oil reservoir dynamic high-efficiency development strategy, the invention has important engineering significance in the research of the seepage interface dynamic representation and the seepage rule based on the flow unit on the macro scale. By combining a dynamic streamline tracing equation on the basis of a classical black oil model and introducing an interface reconstruction idea in a multiphase interface tracing method, a flow unit seepage interface quantitative characterization method comprehensively considering dynamic and static factors is established, and a reservoir is successfully divided into four types of flow units: the high-speed high-water-content flow unit, the high-speed high-oil-content flow unit, the low-speed high-water-content flow unit and the low-speed high-oil-content flow unit. Meanwhile, the method tracks the dynamic evolution law of the seepage interface of the two-dimensional and three-dimensional flow units, and the feasibility of the seepage interface is verified by developing strategy application tests.
The invention has the following effects:
the method for quantitatively characterizing the dynamic seepage interface obtains the streamline with the maximum value by solving the average velocity gradient of the streamline; solving the average saturation gradient of the streamline, and taking the streamline with the maximum value; the ratio of the flux in the velocity field and the velocity contour line to the total flux of the section is calculated on the main section, and the velocity contour line with the maximum value is taken; calculating the ratio of the water content in the saturation field and the water saturation contour line to the total water content of the section on the main section, and taking the maximum value of the water saturation contour line; the method overcomes the defects that the existing method focuses on dividing a flow unit by using static parameters and is only used for predicting the residual oil, can comprehensively consider the influence of dynamic and static parameters on the evolution of a seepage interface, can quantitatively represent the dynamic seepage interface in the water flooding process, and has great practical significance for researching the underground oil-water distribution rule and the residual oil distribution prediction.
FIG. 5 is a structural diagram of an embodiment of a seepage interface quantitative characterization system of a flow unit of a water-drive reservoir according to the present invention. Referring to fig. 5, the system for quantitatively characterizing the seepage interface of the flow unit of the water-drive reservoir comprises:
the reservoir model building module 501 is used for building a reservoir model for a reservoir to be predicted; the reservoir model comprises a two-dimensional reservoir model and a three-dimensional reservoir model.
A velocity field and saturation field determining module 502, configured to determine a velocity field and a saturation field of oil-water two-phase in the reservoir model according to an oil-water two-phase seepage equation.
A flow line determination module 503 for determining a plurality of flow lines emanating from the injection well and converging on the production well according to Pollock flow line tracking method and the velocity field.
A seepage interface determining module 504, configured to determine a seepage interface according to all the streamlines; the percolation interface includes a velocity difference interface and a saturation difference interface.
The seepage interface determining module 504 specifically includes:
and the speed gradient average value calculating unit is used for calculating the positive direction speed gradient average value and the negative direction speed gradient average value on each streamline when the oil reservoir model is a two-dimensional oil reservoir model.
And the first flow line determining unit is used for taking the flow line corresponding to the maximum positive direction speed gradient average value as the first flow line.
And the second streamline determination unit is used for taking the streamline corresponding to the maximum negative direction speed gradient average value as the second streamline.
And the speed difference interface determining unit is used for taking a closed curve formed by the first streamline and the second streamline as a speed difference interface.
And the saturation gradient average value calculating unit is used for calculating the positive direction saturation gradient average value and the negative direction saturation gradient average value on each streamline.
And the third flow line determining unit is used for taking the flow line corresponding to the maximum positive direction saturation gradient average value as a third flow line.
And the fourth streamline determining unit is used for taking the streamline corresponding to the maximum negative direction saturation gradient average value as the fourth streamline.
And the saturation difference interface determining unit is used for taking a closed curve formed by the third streamline and the fourth streamline as a saturation difference interface.
And the connecting line midpoint determining unit is used for determining the midpoint of the connecting line between the water injection well and the oil production well when the oil reservoir model is the three-dimensional oil reservoir model.
And the section determining unit is used for determining a section which passes through the midpoint and is perpendicular to the connecting line.
A first flux calculation unit for calculating a first flux flowing through the cross section.
A velocity contour determination unit for determining a plurality of velocity contours from the velocity field; each of the velocity contours constitutes a first closed region.
A second flux calculation unit for calculating a second flux flowing through each of the first closed regions; the first flux and the second flux each comprise two fluids, oil and water, the amounts of the two fluids being unequal.
And the flux ratio calculating unit is used for calculating the ratio of the second flux to the first flux to obtain a flux ratio.
And the flux ratio variation calculating unit is used for calculating the flux ratio variation corresponding to each speed contour according to the flux ratio.
A first speed contour determination unit for taking the speed contour corresponding to the largest said flux ratio variation as a first speed contour.
And the speed difference interface determining unit is used for taking a curved surface formed by extending the first speed contour line along the flow line as a speed difference interface.
A first water cut calculation unit for calculating a first water cut flowing through the cross section.
A saturation contour determining unit for determining a plurality of saturation contours from the saturation field; each of the saturation contours constitutes a second closed area.
A second water cut calculating unit for calculating a second water cut flowing through each of the second closed regions.
And the water content ratio calculating unit is used for calculating the ratio of the second water content to the first water content to obtain the water content ratio.
And the water cut ratio variation calculating unit is used for calculating the water cut ratio variation corresponding to each saturation contour according to the water cut ratio.
And the first saturation contour determining unit is used for taking the saturation contour corresponding to the maximum moisture ratio variation as the first saturation contour.
And the saturation difference interface determining unit is used for taking a curved surface formed by extending the first saturation contour line along the flow line as a saturation difference interface.
A flow cell dividing module 505 for dividing the flow cells according to the seepage interface.
The flow cell dividing module 505 specifically includes:
a first flow cell determination unit for determining an area within the speed difference interface and within the saturation difference interface as a first flow cell.
A second flow cell determination unit for determining an area outside the speed difference interface and within the saturation difference interface as a second flow cell.
A third flow cell determination unit for determining an area within the velocity difference interface and outside the saturation difference interface as a third flow cell.
A fourth flow cell determination unit for determining an area outside the velocity difference interface and outside the saturation difference interface as a fourth flow cell.
And an oil-water distribution condition determining module 506, configured to determine an oil-water distribution condition according to the divided flow units.
The embodiments in the present description are described in a progressive manner, each embodiment focuses on differences from other embodiments, and the same and similar parts among the embodiments are referred to each other. For the system disclosed by the embodiment, the description is relatively simple because the system corresponds to the method disclosed by the embodiment, and the relevant points can be referred to the method part for description.
The principles and embodiments of the present invention have been described herein using specific examples, which are provided only to help understand the method and the core concept of the present invention; meanwhile, for a person skilled in the art, according to the idea of the present invention, the specific embodiments and the application range may be changed. In view of the above, the present disclosure should not be construed as limiting the invention.
Claims (4)
1. A method for quantitatively characterizing a seepage interface of a flow unit of a water-drive reservoir is characterized by comprising the following steps:
establishing an oil reservoir model for an oil reservoir to be predicted; the oil reservoir model comprises a two-dimensional oil reservoir model and a three-dimensional oil reservoir model;
determining a velocity field and a saturation field of oil-water two phases in the oil reservoir model according to an oil-water two-phase seepage equation;
determining a plurality of flow lines which are emitted by the water injection well and converged on the oil production well according to a Pollock flow line tracking method and the speed field;
determining a seepage interface according to all the flow lines; the seepage interface comprises a speed difference interface and a saturation difference interface;
dividing flow units according to the seepage interface;
determining the oil-water distribution condition according to the divided flow units;
the determining of the seepage interface according to all the flow lines specifically comprises:
when the oil reservoir model is a two-dimensional oil reservoir model, calculating the average value of positive direction velocity gradients and the average value of negative direction velocity gradients on each streamline;
taking the streamline corresponding to the maximum positive direction speed gradient average value as a first streamline;
taking the streamline corresponding to the maximum negative direction speed gradient average value as a second streamline;
taking a closed curve formed by the first flow line and the second flow line as a speed difference interface;
calculating the positive direction saturation gradient average value and the negative direction saturation gradient average value on each streamline;
taking the streamline corresponding to the maximum positive direction saturation gradient average value as a third streamline;
taking the streamline corresponding to the maximum negative direction saturation gradient average value as a fourth streamline;
taking a closed curve formed by the third streamline and the fourth streamline as a saturation difference interface;
when the oil reservoir model is a three-dimensional oil reservoir model, determining a midpoint of a connecting line of the water injection well and the oil production well;
determining a section passing through the midpoint and perpendicular to the line;
calculating a first flux through the cross section;
determining a plurality of velocity contours from the velocity field; each of said velocity contours forming a first closed region;
calculating a second flux flowing through each of the first closed regions; the first flux and the second flux each comprise two fluids, oil and water, the amounts of the two fluids being unequal;
calculating the ratio of the second flux to the first flux to obtain a flux ratio;
calculating flux ratio variation corresponding to each speed contour line according to the flux ratio;
taking the speed contour corresponding to the maximum flux ratio variation as a first speed contour;
taking a curved surface formed by extending the first speed contour line along the flow line as a speed difference interface;
calculating a first water cut through the cross-section;
determining a plurality of saturation contours from the saturation field; each saturation contour line forms a second closed area;
calculating a second moisture content flowing through each of the second enclosed regions;
calculating the ratio of the second water content to the first water content to obtain a water content ratio;
calculating the variation of the water cut ratio corresponding to each saturation contour according to the water cut ratio;
taking the saturation contour corresponding to the maximum moisture ratio variation as a first saturation contour;
and taking a curved surface formed by extending the first saturation contour line along the flow line as a saturation difference interface.
2. The method for quantitatively characterizing the seepage interface of the flow unit of the water-drive reservoir according to claim 1, wherein dividing the flow unit according to the seepage interface specifically comprises:
determining an area within the velocity difference interface and within the saturation difference interface as a first flow cell;
determining a region outside the velocity difference interface and within the saturation difference interface as a second flow cell;
determining a region within the velocity difference interface and outside of the saturation difference interface as a third flow cell;
determining a region outside the velocity difference interface and outside the saturation difference interface as a fourth flow cell.
3. A system for quantitatively characterizing a seepage interface of a flow unit of a water-drive reservoir, the system comprising:
the reservoir model establishing module is used for establishing a reservoir model for the reservoir to be predicted; the oil reservoir model comprises a two-dimensional oil reservoir model and a three-dimensional oil reservoir model;
the velocity field and saturation field determining module is used for determining the velocity field and the saturation field of the oil-water two-phase in the oil reservoir model according to an oil-water two-phase seepage equation;
the flow line determining module is used for determining a plurality of flow lines which are sent out by the water injection well and converged to the oil production well according to the Pollock flow line tracking method and the speed field;
the seepage interface determining module is used for determining a seepage interface according to all the flow lines; the seepage interface comprises a speed difference interface and a saturation difference interface;
the flow unit dividing module is used for dividing flow units according to the seepage interface;
the oil-water distribution condition determining module is used for determining the oil-water distribution condition according to the divided flow units;
the seepage interface determining module specifically comprises:
the speed gradient average value calculating unit is used for calculating a positive direction speed gradient average value and a negative direction speed gradient average value on each streamline when the oil reservoir model is a two-dimensional oil reservoir model;
the first flow line determining unit is used for taking the flow line corresponding to the maximum positive direction speed gradient average value as a first flow line;
the second streamline determining unit is used for taking a streamline corresponding to the maximum negative direction speed gradient average value as a second streamline;
a speed difference interface determining unit, configured to use a closed curve formed by the first flow line and the second flow line as a speed difference interface;
the saturation gradient average value calculating unit is used for calculating a positive direction saturation gradient average value and a negative direction saturation gradient average value on each streamline;
the third flow line determining unit is used for taking the flow line corresponding to the maximum positive direction saturation gradient average value as a third flow line;
the fourth streamline determining unit is used for taking the streamline corresponding to the maximum negative direction saturation gradient average value as a fourth streamline;
a saturation difference interface determining unit, configured to use a closed curve formed by the third flow line and the fourth flow line as a saturation difference interface;
the connecting line midpoint determining unit is used for determining the midpoint of the connecting line of the water injection well and the oil production well when the oil reservoir model is a three-dimensional oil reservoir model;
a section determining unit for determining a section passing through the midpoint and perpendicular to the connection line;
a first flux calculating unit for calculating a first flux flowing through the cross section;
a velocity contour determination unit for determining a plurality of velocity contours from the velocity field; each of said velocity contours forming a first closed region;
a second flux calculation unit for calculating a second flux flowing through each of the first closed areas; the first and second fluxes each comprise two fluids, oil and water, in different amounts;
the flux ratio calculating unit is used for calculating the ratio of the second flux to the first flux to obtain a flux ratio;
the flux ratio variable quantity calculating unit is used for calculating the flux ratio variable quantity corresponding to each speed contour line according to the flux ratio;
a first speed contour determining unit configured to take a speed contour corresponding to the largest flux ratio variation as a first speed contour;
the speed difference interface determining unit is used for taking a curved surface formed by extending the first speed contour line along the flow line as a speed difference interface;
a first water content calculation unit for calculating a first water content flowing through the cross section;
a saturation contour determining unit for determining a plurality of saturation contours according to the saturation field; each saturation contour line forms a second closed area;
a second water content calculation unit for calculating a second water content flowing through each of the second closed regions;
the water content ratio calculating unit is used for calculating the ratio of the second water content to the first water content to obtain the water content ratio;
the water cut ratio variation calculating unit is used for calculating the water cut ratio variation corresponding to each saturation contour according to the water cut ratio;
a first saturation contour determining unit configured to take a saturation contour corresponding to the maximum moisture ratio variation as a first saturation contour;
and the saturation difference interface determining unit is used for taking a curved surface formed by extending the first saturation contour line along the flow line as a saturation difference interface.
4. The system for quantitatively characterizing the seepage interface of the flow unit of the water-drive reservoir according to claim 3, wherein the flow unit dividing module specifically comprises:
a first flow cell determination unit for determining an area within the speed difference interface and within the saturation difference interface as a first flow cell;
a second flow cell determination unit for determining an area outside the speed difference interface and within the saturation difference interface as a second flow cell;
a third flow cell determination unit for determining an area within the velocity difference interface and outside the saturation difference interface as a third flow cell;
a fourth flow cell determination unit for determining an area outside the velocity difference interface and outside the saturation difference interface as a fourth flow cell.
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