CN107944126B - Method and device for determining water content of water-drive reservoir - Google Patents
Method and device for determining water content of water-drive reservoir Download PDFInfo
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Abstract
The embodiment of the application discloses a method and a device for determining water content of a water-drive reservoir. The method comprises the following steps: performing linear regression fitting on a plurality of data points with the designated parameter as a vertical coordinate and the extraction degree as a horizontal coordinate to obtain a linear relation curve graph of the designated parameter and the extraction degree; determining the final recovery ratio of the target oil reservoir according to the linear relation curve graph; determining a water drive characteristic curve type corresponding to historical production data, and determining an association relation between the extraction degree and the water content of the target oil reservoir according to the water drive characteristic curve type; determining an initial mining degree history value and an initial water content history value of a target oil reservoir; and determining the water content of the target oil reservoir under different extraction degrees according to the initial historical extraction degree value, the initial historical water content value and the incidence relation between the extraction degree and the water content. The technical scheme provided by the embodiment of the application can accurately determine the water content of the water-drive oil reservoir.
Description
Technical Field
The application relates to the technical field of oilfield development, in particular to a method and a device for determining water content of a water-drive reservoir.
Background
Research on water-drive curves and statistics of actual production data of oil fields prove that a certain relation exists between the water content and the extraction degree of any water-drive oil reservoir, the specific relation is the comprehensive reflection of the oil-water flow rule under the combined action of a plurality of factors in oil field development, and the change condition of the water content along with the extraction degree can be determined by using a relational expression of the water content and the extraction degree. The relationship is not only dependent on reservoir parameters such as heterogeneity of reservoir, fluid property, water body size and fluid distribution, but also dependent on artificial factors such as well pattern development, mining mode and working system. The parameters of each oil reservoir in an actual oil field are different, and the well pattern development and the exploitation mode are also characterized, so that the relationship between the water content and the extraction degree of different oil fields is different. In order to better clarify the change of the water content of the oil field, a reasonable relational expression between the water content and the extraction degree needs to be determined.
In 1981, the child constitution courier establishes the extraction degree R and the final recovery E based on the water-drive curve B and the data of 25 medium-high-permeability oil reservoirs at home and abroadRWith the water content fwThe relation of (1):
in the formula: f. ofwIs the reservoir water content, f; r is the oil reservoir production degree, f; eRAnd f, final oil recovery rate of the oil reservoir. The change rule of the water content and the extraction degree of the medium-high permeability oil field under different final recovery efficiencies can be obtained by using the formula. Taking the extraction degree R as the abscissa and the water content as the ordinate to obtain different ERA series of f can be made on the coordinate systemw-family of R relation curves. The Tong's chart is a chart of relation between water content and extraction degree, is a statistical rule obtained based on development data of medium-high permeability oil fields 30 years ago, and is widely applied in China. However, in recent years, the application of practical oil fields shows that the prediction error of the tongshi water content and the extraction degree is large, and even the prediction error cannot be applied, and the reason is that: in any oil field actually developed, the exploitation mode is continuously changed from the initial stage of exploitation of the oil field to years later, so that the extraction degree and the water content are changed, and the production data of one oil field for many years is difficult to fit by using a Tong's chart.
Aiming at the problems of the water drive plate of the constitution badge of children, Yi Da Qing proposed a correction plate in 2014, the expression of which is:
in the formula: f. ofwIs the reservoir water content, f; r is the oil reservoir production degree, f; eRF, oil reservoir ultimate recovery factor; a is a constant. And (4) obtaining a coefficient a by utilizing the regression of the actual production data of the oil field based on the formula, and drawing a curve chart of the relation between the water content and the extraction degree under different ultimate recovery ratios. However, the formula does not have any theoretical derivation, but is only assumed, while the constant a has no physical meaning.
The existing chart of the relation curve between the water content and the extraction degree mainly has the following two problems, namely that the Tong's chart obtained 30 years ago based on a statistical rule cannot be well applied to the existing water drive oil reservoir, the predicted water content is often greatly different from the actual water content, and certain limitation is realized; secondly, the corrected plate formula only artificially modifies the coefficient 7.5 and the like in the Tong's plate relational expression into other constants, and is lack of scientificity.
Disclosure of Invention
The embodiment of the application aims to provide a method and a device for determining the water content of a water-drive oil reservoir, so that the change of the water content of the water-drive oil reservoir along with the extraction degree can be accurately predicted, the recovery ratio and the recoverable reserve of the oil field can be predicted, the understanding of the effect of the oil field can be guided, and the economic benefit of water-drive oil field development can be improved.
In order to solve the above technical problem, an embodiment of the present application provides a method and an apparatus for determining water-drive reservoir water content, which are implemented as follows:
a method for determining water content of a water-drive reservoir provides historical production data of a purposeful reservoir; the historical production data comprises extraction degree data and water content data of sample points in the target oil reservoir; the method comprises the following steps:
performing linear regression fitting on a plurality of data points with the designated parameter as a vertical coordinate and the extraction degree as a horizontal coordinate to obtain a linear relation curve graph of the designated parameter and the extraction degree; determining the ultimate recovery ratio of the target oil reservoir according to the linear relation curve graph; wherein the specified parameter is associated with a water cut;
determining a water drive characteristic curve type corresponding to the historical production data, and determining the association relationship between the extraction degree and the water content of the target oil reservoir according to the water drive characteristic curve type;
determining the historical initial value of the extraction degree and the historical initial value of the water content of the target oil reservoir based on the linear relation curve graph, the final recovery ratio and the correlation between the extraction degree and the water content;
and determining the water content of the target oil reservoir under different extraction degrees according to the historical initial values of the extraction degrees, the historical initial values of the water content and the incidence relation between the extraction degrees and the water content.
In a preferred embodiment, the historical production data further includes: cumulative water production W of sample points in the target oil reservoirpData, cumulative oil production NpData and cumulative fluid production LpData; the determining of the type of the water flooding characteristic curve corresponding to the historical production data comprises:
pair with lgWpAs ordinate, cumulative oil production NpLinear fitting was performed for multiple data points on the abscissa to obtain lgWpAnd cumulative oil production NpThe first measured fitted straight line of (a); and to lgLpAs ordinate, cumulative oil production NpLinear fitting was performed for multiple data points on the abscissa to obtain lgLpAnd cumulative fluid production amount NpFitting a straight line by the second actual measurement;
respectively calculating linear correlation coefficients corresponding to the first actually measured fitting straight line and the second actually measured fitting straight line;
when the absolute value of the linear correlation coefficient corresponding to the first actually-measured fitting straight line is greater than or equal to a preset correlation coefficient threshold value, determining that the type of the water flooding characteristic curve corresponding to the historical production data is a type A water flooding characteristic curve type; and when the absolute value of the linear correlation coefficient corresponding to the second actually-measured fitting straight line is greater than or equal to a preset correlation coefficient threshold, determining that the water flooding characteristic curve type corresponding to the historical production data is the water flooding characteristic curve type of the B type.
In a preferred embodiment, the pairs are represented by lgWpAs ordinate, cumulative oil production NpPerforming a linear fitting process for a plurality of data points on the abscissa, comprising:
and fitting the accumulated water yield data and the accumulated oil yield data of the sample points in the historical production data by adopting a least square method.
In an optimal scheme, the determining the association relationship between the extraction degree and the water content of the target oil reservoir according to the type of the water flooding characteristic curve comprises the following steps:
when the water flooding characteristic curve type is a type A water flooding characteristic curve type, representing the incidence relation between the extraction degree and the water content by adopting the following formula:
wherein R is the extraction degree; f. ofwThe water content is obtained; f. ofwLPresetting economic limit water content for the target oil reservoir; r0The initial value of the mining degree history of the target oil reservoir is obtained; f. ofw0The historical initial value of the water content of the target oil reservoir is taken as the initial value; eRAnd the ultimate recovery factor of the target oil reservoir.
In an optimal scheme, the determining the association relationship between the extraction degree and the water content of the target oil reservoir according to the type of the water flooding characteristic curve comprises the following steps:
when the water flooding characteristic curve type is the water flooding characteristic curve type B, the incidence relation between the extraction degree and the water content is represented by the following formula:
wherein R is the extraction degree; f. ofwThe water content is obtained; f. ofwLPresetting economic limit water content for the target oil reservoir; r0The initial value of the mining degree history of the target oil reservoir is obtained; f. ofw0For the initial water content history of the target reservoirA value; eRAnd the ultimate recovery factor of the target oil reservoir.
In a preferred embodiment, the determining the ultimate recovery factor of the target reservoir according to the linear relationship graph includes:
and obtaining the final recovery ratio of the target oil reservoir when the water content is the preset economic limit water content by adopting a mapping method based on the linear relation curve graph.
In a preferred embodiment, the specified parameter is expressed by an expression
Characterizing; wherein f iswRepresenting the water content; the method of mapping comprising:
in the linear relation curve graph, the ordinate is taken as
Making a horizontal line parallel to the abscissa, simultaneously prolonging the intersection of a straight line obtained by the linear fitting regression to a specified data point, and taking the abscissa corresponding to the specified data point as the final recovery efficiency E of the target oil reservoirR(ii) a Wherein f iswLAnd representing the preset economic limit water content.
In a preferable scheme, the preset economic limit water content value is 0.98.
In a preferred embodiment, the determining the historical initial value of the extraction degree and the historical initial value of the water content of the target oil reservoir based on the linear relationship graph, the ultimate recovery ratio and the correlation between the extraction degree and the water content includes:
respectively corresponding a slope term and an intercept term of the incidence relation between the extraction degree and the water content to a slope value and an intercept value in the linear relation curve graph, and establishing the incidence relation between the historical initial value of the extraction degree and the historical initial value of the water content;
and calculating the historical initial value of the mining degree and the historical initial value of the water content of the target oil reservoir according to the incidence relation between the historical initial value of the mining degree and the historical initial value of the water content.
An apparatus for determining water cut of a water-drive reservoir, the apparatus providing historical production data of a target reservoir; wherein the historical production data comprises the extraction degree R data and the water content f of the sample points in the target oil reservoirwData; the device comprises: the system comprises a final recovery ratio determining module, an incidence relation determining module, an initial historical value determining module and a water content determining module; wherein the content of the first and second substances,
the final recovery ratio determining module is used for performing linear regression fitting on a plurality of data points with the designated parameter as a vertical coordinate and the extraction degree as a horizontal coordinate to obtain a linear relation curve graph of the designated parameter and the extraction degree; determining the ultimate recovery ratio of the target oil reservoir according to the linear relation curve graph; wherein the specified parameters are expressed by expressions
Characterizing;
the incidence relation determining module is used for determining the type of a water drive characteristic curve corresponding to the historical production data and determining the incidence relation between the extraction degree and the water content of the target oil reservoir according to the type of the water drive characteristic curve;
the historical initial value determining module is used for determining the historical initial value of the extraction degree and the historical initial value of the water content of the target oil reservoir based on the linear relation curve graph, the final recovery ratio and the correlation between the extraction degree and the water content;
and the water content determining module is used for determining the water content of the target oil reservoir under different extraction degrees according to the historical initial values of the extraction degree, the historical initial values of the water content and the incidence relation between the extraction degree and the water content.
The embodiment of the application provides a method and a device for determining water-drive reservoir water content, and the type of a water-drive characteristic curve of an oil field can be determined according to actual historical production data of the oil field. Based on the theory that the relation between the water content and the extraction degree can reflect the flowing rule of oil field underground oil water, the water content calculation relational expression which accords with the actual oil field is obtained by utilizing the actual historical production data of the oil field and the type of the water drive characteristic curve, so that the actual water drive characteristic rule of the oil field can be explained and analyzed more accurately in theory, and the oil field development index can be predicted more accurately.
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In order to more clearly illustrate the embodiments of the present application or the technical solutions in the prior art, the drawings needed to be used in the description of the embodiments or the prior art will be briefly introduced below, it is obvious that the drawings in the following description are only some embodiments described in the present application, and for those skilled in the art, other drawings can be obtained according to the drawings without any creative effort.
FIG. 1 is a flow chart of a method of determining water-drive reservoir water cut according to the present application;
FIG. 2 shows fitting regression using grandpa mansion oilfield production data in the examples of the present application
A linear relationship curve graph with the extraction degree;
FIG. 3 is a regression fit using Hassakestein J-2C oilfield production data in the examples of the present application
A linear relationship curve graph with the extraction degree;
FIG. 4 is a graph comparing the water content and extraction degree relation curve of the grand house oil field and the actual data of the grand house oil field obtained by the method of the present application in the embodiment of the present application;
FIG. 5 is a comparison of conventional Tong's water drive characteristic curve chart and actual grand house oil field production data;
FIG. 6 is a graph showing the relationship between the water content and the extraction degree of a Kazakhstan J-2C oil field obtained by the method of the present application in the embodiment of the present application, and the actual data of the Kazakhstan J-2C oil field;
FIG. 7 is a graph of conventional Tongshi water flooding characteristic curves and a comparison of actual Kazakhstan J-2C oilfield production data;
FIG. 8 is a block diagram illustrating the components of an embodiment of the apparatus for determining water cut in a water drive reservoir according to the present application.
Detailed Description
The embodiment of the application provides a method and a device for determining water-drive reservoir water content.
In order to make those skilled in the art better understand the technical solutions in the present application, the technical solutions in the embodiments of the present application will be clearly and completely described below with reference to the drawings in the embodiments of the present application, and it is obvious that the described embodiments are only a part of the embodiments of the present application, and not all of the embodiments. All other embodiments, which can be derived by a person skilled in the art from the embodiments given herein without making any creative effort, shall fall within the protection scope of the present application.
The application provides a method for determining water-drive reservoir water content. The method for determining the water-drive reservoir water content provides historical production data of the purposeful reservoir.
In this embodiment, the reservoir of interest may be a water-flooding reservoir.
In this embodiment, the production data of the target oil reservoir in the past development, that is, the historical production data, can be obtained by examining the geology and the exploitation condition of the target oil reservoir.
In this embodiment, the historical production data may include data of the extraction degree R and the water content f of the sample point in the target reservoirwData, cumulative water yield WpData, cumulative oil production NpData and cumulative fluid production LpAnd (4) data.
For example, the grand house oil field belongs to a low permeability oil field, and a 250m well spacing reverse nine-point method is adopted in 1994 and a set of layer water injection is put into development, and 41.6 square kilometers (km) of oil-bearing area is used2) Geological reserve 2026 × 104Ton (t), nominal recoverable reserve 256.5X 104Ton (t), recovery ratio 12.7 percent (%), initial water content 39.5%, and 11-year production data table of grand house oil field are shown in table 1.
TABLE 1 grandpa mansion oilfield production data sheet
| Development time/year | Degree of extraction/f | Water content/f | lg((1-fw)/fw) |
| 1 | 0.004 | 0.395 | 0.185 |
| 2 | 0.020 | 0.672 | -0.311 |
| 3 | 0.031 | 0.755 | -0.489 |
| 4 | 0.038 | 0.798 | -0.597 |
| 5 | 0.045 | 0.784 | -0.560 |
| 6 | 0.051 | 0.799 | -0.599 |
| 7 | 0.056 | 0.807 | -0.621 |
| 8 | 0.061 | 0.829 | -0.686 |
| 9 | 0.066 | 0.870 | -0.826 |
| 10 | 0.071 | 0.900 | -0.954 |
| 11 | 0.077 | 0.902 | -0.964 |
The Kazakhstan J-2C oil field belongs to a high-permeability sandstone oil field, and is developed by adopting a 400-meter well spacing reverse nine-point method water injection in 1992, so that the geological reserve6232×104The 25-year production data table of the Kazakhstan J-2C oil field is shown in a table 2, the first-year extraction degree is 0.003%, the water content is 0, the 25-year extraction degree reaches 8.37%, and the water content reaches 80.4%.
TABLE 2 Kazakhstan J-2C oilfield production data sheet
FIG. 1 is a flow chart of a method of determining water-drive reservoir water cut according to the present application. As shown in FIG. 1, the method for determining the water-drive reservoir water content comprises the following steps.
Step S101: performing linear regression fitting on a plurality of data points with the designated parameter as a vertical coordinate and the extraction degree as a horizontal coordinate to obtain a linear relation curve graph of the designated parameter and the extraction degree; and determining the ultimate recovery factor of the target oil reservoir according to the linear relation curve graph.
In this embodiment, the specified parameter may be expressed by an expression
And (5) characterizing. Can be paired with
Taking a plurality of data points with the vertical coordinate and the horizontal coordinate as the extraction degree to perform linear regression fitting to obtain
Linear with the extent of production.
In this embodiment, determining the ultimate recovery factor of the target oil reservoir according to the linear relationship graph may specifically include obtaining the ultimate recovery factor of the target oil reservoir when the water content is the preset economic limit water content by using a mapping method based on the linear relationship graph.
In this embodiment, the plotting method may specifically include that a vertical coordinate is taken as a value in the linear relation graph
And making a horizontal line parallel to the abscissa, and simultaneously prolonging the intersection of the straight line obtained by the linear fitting regression to the specified data point, wherein the abscissa corresponding to the specified data point can be used as the final recovery factor E of the target oil reservoirR. Wherein f iswLAnd representing the preset economic limit water content.
In this embodiment, the value of the preset economic limit water content may be generally 0.98.
For example, take the production data of grandpa mansion oilfield in Table 1 as an example, and take the extraction degree as the abscissa and take
As a vertical coordinate, drawing the data points of the actual water content and the extraction degree into a coordinate system, and performing linear regression fitting to obtain
Linear with the degree of production (see line AB in figure 2). The preset economic limit water content fwLA value of 0.98 can be calculated
The value of (b) is-1.69. Can take the ordinate as
And making a horizontal line (a straight line CB in figure 2) parallel to the abscissa, simultaneously prolonging the intersection point of a straight line obtained by linear fitting regression of the water content and the extraction degree (a point B in figure 2), wherein the abscissa corresponding to the intersection point (the intersection point of the straight line BD and the abscissa in figure 2) is the recovery ratio of the grandERI.e. ERThe value is 0.128.
Taking the Hassakestein J-2C oilfield production data in Table 2 as an example, the extraction degree is taken as the abscissa and
as a vertical coordinate, drawing the data points of the actual water content and the extraction degree into a coordinate system, and performing linear regression fitting to obtain
Linear with the degree of production (see line AB in figure 3). The preset economic limit water content fwLA value of 0.98 can be calculated
The value of (b) is-1.69. Can take the ordinate as
And making a horizontal line (a straight line CB in figure 3) parallel to the abscissa, simultaneously prolonging the intersection point of a straight line obtained by linear fitting regression of the water content and the extraction degree (a point B in figure 3), wherein the abscissa (the intersection point of the straight line BD and the abscissa in figure 3) corresponding to the intersection point is the recovery factor E of the Kazakhstan J-2C oil field under the economic limit conditionRI.e. ERThe value was 0.159.
Step S102: determining the type of a water drive characteristic curve corresponding to the historical production data, and determining the association relationship between the extraction degree and the water content of the target oil reservoir according to the type of the water drive characteristic curve.
In this embodiment, determining the type of the water drive characteristic curve corresponding to the historical production data may specifically include, for example, lgWpAs ordinate, cumulative oil production NpLinear fitting was performed for multiple data points on the abscissa to obtain lgWpAnd cumulative oil production NpIs measured to fit the line. Can also be used for lgLpAs ordinate, cumulative oil production NpFor a plurality of data points on the abscissaLine fitting process to obtain lgLpAnd cumulative fluid production amount NpIs measured to fit the line. Linear correlation coefficients corresponding to the first measured fitted straight line and the second measured fitted straight line may be calculated, respectively. When the absolute value of the linear correlation coefficient corresponding to the first actually-measured fitted straight line is greater than or equal to a preset correlation coefficient threshold, it can be determined that the type of the water flooding characteristic curve corresponding to the historical production data is the type A water flooding characteristic curve. When the absolute value of the linear correlation coefficient corresponding to the second actually-measured fitting straight line is greater than or equal to a preset correlation coefficient threshold, the water drive characteristic curve type corresponding to the historical production data can be determined to be the water drive characteristic curve type of the B type.
In this embodiment, the linear correlation coefficient corresponding to the first actually measured fitted straight line may be used to represent the lgWpAnd cumulative oil production NpThe degree of linear correlation between them. Similarly, the corresponding linear correlation of the second measured fitted line can be used to represent lgLpAnd cumulative fluid production amount NpThe degree of linear correlation between them. Specifically, for example, the following formula may be adopted to calculate the linear correlation coefficient corresponding to the first measured fitted straight line:
wherein R represents a linear correlation coefficient corresponding to the first actually measured fitted straight line, xilgW representing the ith sample point in the reservoir of interestp，yiRepresenting the cumulative oil production N of the ith sample point in the target oil reservoirpAnd n represents the number of sample points. The method of calculating the linear correlation coefficient corresponding to the first measured fitted straight line may also be applied to calculating the linear correlation coefficient corresponding to the second measured fitted straight line.
In this embodiment, the preset correlation coefficient threshold may have a value range of 0.1 to 0.6.
In the present embodiment, the pair is lgWpIs a vertical coordinate of the main body of the device,cumulative oil production NpThe linear fitting process is performed on the plurality of data points on the abscissa, and may specifically include performing a fitting process on the cumulative water yield data and the cumulative oil yield data of the sample points in the historical production data by using a least square method. Also, a least squares pair of lgL can be usedpAs ordinate, cumulative oil production NpA linear fitting process is performed for a plurality of data points on the abscissa.
In this embodiment, determining the association relationship between the extraction degree and the water content of the target oil reservoir according to the water drive characteristic curve type may specifically include, when the water drive characteristic curve type is a type a water drive characteristic curve type, characterizing the association relationship between the extraction degree and the water content by using the following formula:
wherein R is the extraction degree; f. ofwThe water content is obtained; f. ofwLPresetting economic limit water content for the target oil reservoir; r0The initial value of the mining degree history of the target oil reservoir is obtained; f. ofw0The historical initial value of the water content of the target oil reservoir is taken as the initial value; eRAnd the ultimate recovery factor of the target oil reservoir.
In this embodiment, determining the association relationship between the extraction degree and the water content of the target oil reservoir according to the water drive characteristic curve type may specifically include, when the water drive characteristic curve type is a water drive characteristic curve type b, characterizing the association relationship between the extraction degree and the water content by using the following formula:
wherein R is the extraction degree; f. ofwThe water content is obtained; f. ofwLPresetting economic limit water content for the target oil reservoir; r0The initial value of the mining degree history of the target oil reservoir is obtained; f. ofw0The reservoir for said purpose containingHistorical initial values of water rate; eRAnd the ultimate recovery factor of the target oil reservoir.
For example, taking the production data of the grandpa prefecture oil field in table 1 as an example, the method of this embodiment can determine that the water drive characteristic curve type corresponding to the historical production data of the grandpa prefecture oil field is a type a water drive characteristic curve type. Similarly, taking the production data of the hassaxostat J-2C oil field in table 2 as an example, the method of the embodiment can determine that the water drive characteristic curve type corresponding to the historical production data of the hassaxostat J-2C oil field is the water drive characteristic curve type of type b. Thus, the correlation between the extraction degree and the water content of the grand house oil field can be determined to be formula (2), and the correlation between the extraction degree and the water content of the Hassakestein J-2C oil field can be determined to be formula (3).
Step S103: and determining the historical initial value of the extraction degree and the historical initial value of the water content of the target oil reservoir based on the linear relation curve graph, the final recovery ratio and the correlation between the extraction degree and the water content.
In this embodiment, based on the linear relationship graph, the ultimate recovery ratio, and the correlation between the extraction degree and the water content, the extraction degree historical initial value and the water content historical initial value of the target oil reservoir are determined, and specifically, the method may include respectively corresponding a slope term and an intercept term of the correlation between the extraction degree and the water content to a slope value and an intercept value in the linear relationship graph, and establishing the correlation between the extraction degree historical initial value and the water content historical initial value. And calculating the historical initial mining degree value and the historical initial water content value of the target oil reservoir according to the incidence relation between the historical initial mining degree value and the historical initial water content value.
For example, taking the production data of the grand house oil field in table 1 as an example, the second term on the right side of formula (2) may be equal to the intercept value of the linear relation curve graph, the coefficient of the extraction degree R of the first term on the right side of formula (2) may be equal to the slope value of the linear relation curve graph, and the extraction degree historical initial value R may be obtained by solving the linear equation of two-dimensional equation0And historical initial value f of water contentw0(ii) a Calculated, the parameter R of the grand house oil field0And f w00 and 0.52, respectively.
Taking the hassaxosteinj-2C oilfield production data in table 2 as an example, the second term on the right side of the formula (3) can be equal to the intercept value of the linear relation curve graph, the coefficient of the first term extraction degree R on the right side of the formula (3) is equal to the slope value of the linear relation curve graph, and the extraction degree historical initial value R is obtained by solving a linear equation of two-dimensional0And historical initial value f of water contentw0(ii) a Calculated, the parameter R of the grand house oil field0And f w00 and 0.02, respectively.
Step S104: and determining the water content of the target oil reservoir under different extraction degrees according to the historical initial values of the extraction degrees, the historical initial values of the water content and the incidence relation between the extraction degrees and the water content.
In this embodiment, the water content of the target oil reservoir under different mining degrees can be determined according to the historical initial mining degree value, the historical initial water content value and the incidence relation between the mining degree and the water content.
For example, taking the production data of the grand house oil field in table 1 as an example, the historical initial value of the extraction degree, the historical initial value of the water content and the final recovery factor of the grand house oil field are substituted into formula (2), the water content of the grand house oil field obtained by formula (2) at different extraction degrees and the actual production data of the grand house oil field are plotted in fig. 4, and the water content of the Tong version and the actual production data of the grand; the water content data obtained by calculating the water content and the relative error of the water content are shown in Table 3.
TABLE 3 data sheet of production degree and water content of great grandpa mansion oil field
As can be seen from the data in fig. 4, fig. 5 and table 3, the water content curve and the actual point fitting degree of the grandpa mansion oilfield obtained by the method of the present embodiment are very high, and the relative errors of the remaining data points are less than 5% except for the first actual point and the calculated value, which illustrates the accuracy of the method of the present application; the goodness of fit between the curve in the Tong's chart and the actual data point is poor, the difference between the predicted water content and the actual value is large, and the maximum relative error is 114.7%.
Taking the production data of the Hassaxostat J-2C oil field in the table 2 as an example, the historical initial value of the extraction degree, the historical initial value of the water content and the final recovery factor of the Hassaxostat J-2C oil field are substituted into a formula (3), the water content of the Hassaxostat J-2C oil field obtained by the formula (3) under different extraction degrees and the actual production data of the Hassaxostat J-2C oil field are drawn in a graph 6, and the water content obtained by a Tong's chart and the actual Hassaxostat J-2C oil field is drawn in a graph 7; the water cut data obtained by the calculation of the both and the relative error of the water cut are shown in Table 4.
TABLE 4 Kazakhstan J-2C oilfield extraction degree and water content data sheet
As can be seen from the data in FIG. 6, FIG. 7 and Table 4, the water content curve and the actual point fitting degree of the Hassakestein J-2C oil field obtained by the method of the embodiment are very high, and the relative errors of the other data points are less than 5% except that the differences between some actual data points and calculated values which are unstable in early production, thereby illustrating the accuracy of the method of the present application; the goodness of fit between the curve in the Tong's chart and the actual data point is poor, the difference between the predicted water content and the actual value is large, and the relative error is 11152.7% at most.
FIG. 8 is a block diagram illustrating the components of an embodiment of the apparatus for determining water cut in a water drive reservoir according to the present application. Device for determining water content of water-drive reservoirHistorical production data for the target reservoir; wherein the historical production data comprises the extraction degree R data and the water content f of the sample points in the target oil reservoirwAnd (4) data. As shown in fig. 8, the apparatus for determining water cut of a water-drive reservoir may include: an ultimate recovery factor determination module 100, an incidence relation determination module 200, an initial historical value determination module 300, and a water cut determination module 400.
The ultimate recovery ratio determining module 100 may be configured to perform linear regression fitting on a plurality of data points with the specified parameter as a vertical coordinate and the extraction degree as a horizontal coordinate to obtain a linear relationship curve of the specified parameter and the extraction degree; determining the ultimate recovery ratio of the target oil reservoir according to the linear relation curve graph; wherein the specified parameters are expressed by expressions
And (5) characterizing.
The association relation determining module 200 may be configured to determine a type of a water drive characteristic curve corresponding to the historical production data, and determine an association relation between the extraction degree and the water content of the target oil reservoir according to the type of the water drive characteristic curve.
The initial historical value determining module 300 may be configured to determine an initial historical value of the extraction degree and an initial historical value of the water content of the target oil reservoir based on the linear relationship graph, the ultimate recovery ratio, and the correlation between the extraction degree and the water content.
The water content determining module 400 may be configured to determine the water content of the target oil reservoir in different mining degrees according to the historical initial mining degree value, the historical initial water content value, and the association relationship between the mining degree and the water content.
The embodiment of the device for determining the water-drive reservoir water content corresponds to the embodiment of the method for determining the water-drive reservoir water content, so that the technical scheme of the embodiment of the method for determining the water-drive reservoir water content can be realized, and the technical effect of the embodiment of the method can be obtained.
In the 90 s of the 20 th century, improvements in a technology could clearly distinguish between improvements in hardware (e.g., improvements in circuit structures such as diodes, transistors, switches, etc.) and improvements in software (improvements in process flow). However, as technology advances, many of today's process flow improvements have been seen as direct improvements in hardware circuit architecture. Designers almost always obtain the corresponding hardware circuit structure by programming an improved method flow into the hardware circuit. Thus, it cannot be said that an improvement in the process flow cannot be realized by hardware physical modules. For example, a Programmable Logic Device (PLD), such as a Field Programmable Gate Array (FPGA), is an integrated circuit whose Logic functions are determined by programming the Device by a user. A digital system is "integrated" on a PLD by the designer's own programming without requiring the chip manufacturer to design and fabricate application-specific integrated circuit chips. Furthermore, nowadays, instead of manually making an Integrated Circuit chip, such Programming is often implemented by "logic compiler" software, which is similar to a software compiler used in program development and writing, but the original code before compiling is also written by a specific Programming Language, which is called Hardware Description Language (HDL), and HDL is not only one but many, such as abel (advanced Boolean Expression Language), ahdl (alternate Language Description Language), traffic, pl (core unified Programming Language), HDCal, JHDL (Java Hardware Description Language), langue, Lola, HDL, laspam, hardbyscript Description Language (vhr Description Language), and the like, which are currently used by Hardware compiler-software (Hardware Description Language-software). It will also be apparent to those skilled in the art that hardware circuitry that implements the logical method flows can be readily obtained by merely slightly programming the method flows into an integrated circuit using the hardware description languages described above.
Those skilled in the art will also appreciate that, in addition to implementing the controller as pure computer readable program code, the same functionality can be implemented by logically programming method steps such that the controller is in the form of logic gates, switches, application specific integrated circuits, programmable logic controllers, embedded microcontrollers and the like. Such a controller may thus be considered a hardware component, and the means included therein for performing the various functions may also be considered as a structure within the hardware component. Or even means for performing the functions may be regarded as being both a software module for performing the method and a structure within a hardware component.
The apparatuses and modules illustrated in the above embodiments may be implemented by a computer chip or an entity, or by a product with certain functions.
For convenience of description, the above devices are described as being divided into various modules by functions, and are described separately. Of course, the functionality of the various modules may be implemented in the same one or more software and/or hardware implementations as the present application.
From the above description of the embodiments, it is clear to those skilled in the art that the present application can be implemented by software plus necessary general hardware platform. With this understanding in mind, the present solution, or portions thereof that contribute to the prior art, may be embodied in the form of a software product, which in a typical configuration includes one or more processors (CPUs), input/output interfaces, network interfaces, and memory. The computer software product may include instructions for causing a computing device (which may be a personal computer, a server, or a network device, etc.) to perform the methods described in the various embodiments or portions of embodiments of the present application. The computer software product may be stored in a memory, which may include forms of volatile memory in a computer readable medium, Random Access Memory (RAM) and/or non-volatile memory, such as Read Only Memory (ROM) or flash memory (flash RAM). Memory is an example of a computer-readable medium. Computer-readable media, including both non-transitory and non-transitory, removable and non-removable media, may implement information storage by any method or technology. The information may be computer readable instructions, data structures, modules of a program, or other data. Examples of computer storage media include, but are not limited to, phase change memory (PRAM), Static Random Access Memory (SRAM), Dynamic Random Access Memory (DRAM), other types of Random Access Memory (RAM), Read Only Memory (ROM), Electrically Erasable Programmable Read Only Memory (EEPROM), flash memory or other memory technology, compact disc read only memory (CD-ROM), Digital Versatile Discs (DVD) or other optical storage, magnetic cassettes, magnetic tape magnetic disk storage or other magnetic storage devices, or any other non-transmission medium that can be used to store information that can be accessed by a computing device. As defined herein, computer readable media does not include transitory computer readable media (transient media), such as modulated data signals and carrier waves.
The embodiments in the present specification are described in a progressive manner, and the same and similar parts among the embodiments are referred to each other, and each embodiment focuses on the differences from the other embodiments. In particular, as for the apparatus embodiment, since it is substantially similar to the method embodiment, the description is relatively simple, and for the relevant points, reference may be made to the partial description of the method embodiment.
The application is operational with numerous general purpose or special purpose computing system environments or configurations. For example: personal computers, server computers, hand-held or portable devices, tablet-type devices, multiprocessor systems, microprocessor-based systems, set top boxes, programmable consumer electronics, network PCs, minicomputers, mainframe computers, distributed computing environments that include any of the above systems or devices, and the like.
The application may be described in the general context of computer-executable instructions, such as program modules, being executed by a computer. Generally, program modules include routines, programs, objects, components, data structures, etc. that perform particular tasks or implement particular abstract data types. The application may also be practiced in distributed computing environments where tasks are performed by remote processing devices that are linked through a communications network. In a distributed computing environment, program modules may be located in both local and remote computer storage media including memory storage devices.
While the present application has been described with examples, those of ordinary skill in the art will appreciate that there are numerous variations and permutations of the present application without departing from the spirit of the application, and it is intended that the appended claims encompass such variations and permutations without departing from the spirit of the application.
Claims (8)
1. A method for determining water-drive reservoir water content is characterized in that historical production data of a destination reservoir are provided; the historical production data comprises extraction degree data and water content data of sample points in the target oil reservoir; the method comprises the following steps:
performing linear regression fitting on a plurality of data points with the designated parameter as a vertical coordinate and the extraction degree as a horizontal coordinate to obtain a linear relation curve graph of the designated parameter and the extraction degree; determining the ultimate recovery ratio of the target oil reservoir according to the linear relation curve graph; wherein the specified parameter is associated with a water cut;
determining a water drive characteristic curve type corresponding to the historical production data, and determining the association relationship between the extraction degree and the water content of the target oil reservoir according to the water drive characteristic curve type, wherein the association relationship comprises the following steps: when the determined water flooding characteristic curve type is the type A water flooding characteristic curve type, representing the incidence relation between the extraction degree and the water content by adopting the following formula:
wherein R is the extraction degree; f. ofwThe water content is obtained; f. ofwLPresetting economic limit water content for the target oil reservoir; r0The initial value of the mining degree history of the target oil reservoir is obtained; f. ofw0The historical initial value of the water content of the target oil reservoir is taken as the initial value; eR(ii) ultimate recovery for the reservoir of interest; and when the determined water flooding characteristic curve type is the water flooding characteristic curve type B, adopting the following formula to represent the incidence relation between the extraction degree and the water content:
wherein R is the extraction degree; f. ofwThe water content is obtained; f. ofwLPresetting economic limit water content for the target oil reservoir; r0The initial value of the mining degree history of the target oil reservoir is obtained; f. ofw0The historical initial value of the water content of the target oil reservoir is taken as the initial value; eR(ii) ultimate recovery for the reservoir of interest;
determining the historical initial value of the extraction degree and the historical initial value of the water content of the target oil reservoir based on the linear relation curve graph, the final recovery ratio and the correlation between the extraction degree and the water content;
and determining the water content of the target oil reservoir under different extraction degrees according to the historical initial values of the extraction degrees, the historical initial values of the water content and the incidence relation between the extraction degrees and the water content.
2. The method of determining water-drive reservoir water cut of claim 1, wherein the historical production data further comprises: cumulative water production W of sample points in the target oil reservoirpData, cumulative oil production NpData and cumulative fluid production LpData; the determining of the type of the water flooding characteristic curve corresponding to the historical production data comprises:
pair with lgWpAs ordinate, cumulative oil production NpLinear fitting was performed for multiple data points on the abscissa to obtain lgWpAnd cumulative oil production NpThe first measured fitted straight line of (a); and to lgLpAs ordinate, cumulative oil production NpLinear fitting was performed for multiple data points on the abscissa to obtain lgLpAnd cumulative fluid production amount NpFitting a straight line by the second actual measurement;
respectively calculating linear correlation coefficients corresponding to the first actually measured fitting straight line and the second actually measured fitting straight line;
when the absolute value of the linear correlation coefficient corresponding to the first actually-measured fitting straight line is greater than or equal to a preset correlation coefficient threshold value, determining that the type of the water flooding characteristic curve corresponding to the historical production data is a type A water flooding characteristic curve type; and when the absolute value of the linear correlation coefficient corresponding to the second actually-measured fitting straight line is greater than or equal to a preset correlation coefficient threshold, determining that the water flooding characteristic curve type corresponding to the historical production data is the water flooding characteristic curve type of the B type.
3. The method of determining water-drive reservoir water cut of claim 2, wherein the pair is lgWpAs ordinate, cumulative oil production NpPerforming a linear fitting process for a plurality of data points on the abscissa, comprising:
and fitting the accumulated water yield data and the accumulated oil yield data of the sample points in the historical production data by adopting a least square method.
4. The method for determining the water cut of a water-drive reservoir according to claim 1, wherein the determining the ultimate recovery factor of the target reservoir according to the linear relationship graph comprises:
and obtaining the final recovery ratio of the target oil reservoir when the water content is the preset economic limit water content by adopting a mapping method based on the linear relation curve graph.
5. The method for determining the water-drive reservoir water content rate of claim 4, wherein the specified parameters are expressed by expressions
Characterizing; wherein f iswRepresenting the water content; the method of mapping comprising:
in the linear relation curve graph, the ordinate is taken as
Making a horizontal line parallel to the abscissa, simultaneously prolonging the intersection of the straight line obtained by the linear fitting regression to the specified data point, and taking the abscissa corresponding to the specified data point as the targetUltimate recovery of oil reservoir ER(ii) a Wherein f iswLAnd representing the preset economic limit water content.
6. The method for determining the water-drive reservoir water cut according to claim 4, wherein the preset economic limit water cut value is 0.98.
7. The method for determining the water cut of the water-flooding reservoir according to claim 1, wherein the step of determining the historical initial value of the extraction degree and the historical initial value of the water cut of the target reservoir based on the linear relation graph, the final recovery factor and the correlation between the extraction degree and the water cut comprises the following steps:
respectively corresponding a slope term and an intercept term of the incidence relation between the extraction degree and the water content to a slope value and an intercept value in the linear relation curve graph, and establishing the incidence relation between the historical initial value of the extraction degree and the historical initial value of the water content;
and calculating the historical initial value of the mining degree and the historical initial value of the water content of the target oil reservoir according to the incidence relation between the historical initial value of the mining degree and the historical initial value of the water content.
8. An apparatus for determining water cut of a water-drive reservoir, the apparatus providing historical production data of a target reservoir; wherein the historical production data comprises the extraction degree R data and the water content f of the sample points in the target oil reservoirwData; the device comprises: the system comprises a final recovery ratio determining module, an incidence relation determining module, an initial historical value determining module and a water content determining module; wherein the content of the first and second substances,
the final recovery ratio determining module is used for performing linear regression fitting on a plurality of data points with the designated parameter as a vertical coordinate and the extraction degree as a horizontal coordinate to obtain a linear relation curve graph of the designated parameter and the extraction degree; determining the ultimate recovery ratio of the target oil reservoir according to the linear relation curve graph; wherein the specified parameters are expressed by expressions
Characterizing;
the incidence relation determining module is used for determining the type of a water drive characteristic curve corresponding to the historical production data and determining the incidence relation between the extraction degree and the water content of the target oil reservoir according to the type of the water drive characteristic curve, and comprises the following steps: when the determined water flooding characteristic curve type is the type A water flooding characteristic curve type, representing the incidence relation between the extraction degree and the water content by adopting the following formula:
wherein R is the extraction degree; f. ofwThe water content is obtained; f. ofwLPresetting economic limit water content for the target oil reservoir; r0The initial value of the mining degree history of the target oil reservoir is obtained; f. ofw0The historical initial value of the water content of the target oil reservoir is taken as the initial value; eR(ii) ultimate recovery for the reservoir of interest; and when the determined water flooding characteristic curve type is the water flooding characteristic curve type B, adopting the following formula to represent the incidence relation between the extraction degree and the water content:
wherein R is the extraction degree; f. ofwThe water content is obtained; f. ofwLPresetting economic limit water content for the target oil reservoir; r0The initial value of the mining degree history of the target oil reservoir is obtained; f. ofw0The historical initial value of the water content of the target oil reservoir is taken as the initial value; eR(ii) ultimate recovery for the reservoir of interest;
the historical initial value determining module is used for determining the historical initial value of the extraction degree and the historical initial value of the water content of the target oil reservoir based on the linear relation curve graph, the final recovery ratio and the correlation between the extraction degree and the water content;
and the water content determining module is used for determining the water content of the target oil reservoir under different extraction degrees according to the historical initial values of the extraction degree, the historical initial values of the water content and the incidence relation between the extraction degree and the water content.
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| CN112049624B (en) * | 2019-06-06 | 2024-04-30 | 中国石油天然气股份有限公司 | Method, device, equipment and storage medium for predicting dynamic reserve of oil well |
| CN112446065A (en) * | 2019-09-03 | 2021-03-05 | 中国石油天然气集团有限公司 | Oil-water interface depth determination method and system |
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