Method and device for determining volume coefficient of crude oil, electronic equipment and medium

Abstract

The invention discloses a crude oil volume coefficient determination method and device, electronic equipment and a medium. The method comprises the steps that parameter sequences of different single wells under the original formation pressure condition are obtained according to test data; establishing a crude oil volume coefficient prediction model under the original formation pressure condition according to the parameter sequence; according to the parameter sequence and a crude oil volume coefficient prediction model, the crude oil volume coefficient of the to-be-predicted well under the original formation pressure condition is determined; and according to the parameter sequence, constructing a relational expression of the crude oil volume coefficients and the formation pressure of different single wells, and according to the relational expression, determining the crude oil volume coefficients of the to-be-predicted well under different formation pressure conditions. According to the method, the crude oil volume coefficient and the formation pressure relational expression of the to-be-predicted well under different formation pressure conditions are determined, a method for calculating the crude oil volume coefficient under different formation pressure conditions by adopting test data is supplemented, and the accuracy of calculating the crude oil volume coefficient is improved.

Description

Technical Field

[0001] The invention relates to the field of reservoir parameter calculation, and in particular to a method, device, electronic equipment and medium for determining a crude oil volume coefficient. Background Art

[0002] In the middle and late stages of reservoir development, evaluating the available reserves and finding the law of remaining oil distribution are important prerequisites for increasing crude oil production and obtaining maximum benefits. Therefore, it becomes very important to accurately calculate the dynamic address reserves within the control range of a single well / well group. Without considering the morphology of the reservoir body and the easy acquisition of dynamic production data, the calculation method of geological reserves within the well control range based on the principle of reservoir material balance is widely used in the calculation of dynamic geological reserves. However, in the calculation process of dynamic geological reserves, the crude oil volume coefficient and the related crude oil compression coefficient have a great influence on the accuracy of reserve calculation. Therefore, how to more accurately determine the crude oil volume coefficient under different pressure conditions is very critical.

[0003] Most of the existing technologies use existing PVT test data or refer to PVT test parameters of similar blocks to carry out calculations. However, since the crude oil volume coefficient varies greatly in different regions, at different well depths and under different pressure conditions, the results of calculating the crude oil volume coefficient and related crude oil compression coefficient by referring to the PVT data of similar blocks are often quite different from the actual situation.

[0004] In summary, the crude oil volume coefficient cannot be accurately calculated according to current technology, and there is a lack of a method to obtain the crude oil volume coefficient under different formation pressure conditions using existing PVT analysis data. Summary of the invention

[0005] The present invention provides a method, device, electronic equipment and medium for determining crude oil volume coefficient, so as to solve the problems of inaccurate calculation of crude oil volume coefficient and lack of method for calculating crude oil volume coefficient under different formation pressure conditions using PVT data.

[0006] According to one aspect of the present invention, a method for determining a volume coefficient of crude oil is provided, the method comprising:

[0007] Obtaining parameter sequences under original formation pressure conditions of different single wells based on test data, the parameter sequences include: production gasoline ratio, formation pressure, crude oil volume coefficient, compression coefficient, formation degassed crude oil density and natural gas relative density;

[0008] Establishing a crude oil volume coefficient prediction model under original formation pressure conditions according to the parameter sequence;

[0009] Determining the crude oil volume coefficient under the original formation pressure condition of the well to be predicted based on the parameter sequence and the crude oil volume coefficient prediction model;

[0010] A relationship between the crude oil volume coefficient and formation pressure of different single wells is constructed according to the parameter sequence, and the crude oil volume coefficient of the well to be predicted under different formation pressure conditions is determined according to the relationship.

[0011] According to another aspect of the present invention, there is provided a device for determining a volume coefficient of crude oil, the device comprising:

[0012] A parameter sequence acquisition module is used to obtain parameter sequences under original formation pressure conditions of different single wells based on test data;

[0013] A prediction model building module, used to build a crude oil volume coefficient prediction model under original formation pressure conditions according to the parameter sequence;

[0014] A crude oil volume coefficient determination module is used to determine the crude oil volume coefficient under the original formation pressure condition of the well to be predicted based on the parameter sequence and the crude oil volume coefficient prediction model;

[0015] The relationship determination module constructs a relationship between the crude oil volume coefficient and the formation pressure of different single wells according to the parameter sequence, and determines the crude oil volume coefficient of the well to be predicted under different formation pressure conditions according to the relationship.

[0016] According to another aspect of the present invention, an electronic device is provided, the electronic device comprising:

[0017] at least one processor; and

[0018] a memory communicatively connected to the at least one processor; wherein,

[0019] The memory stores a computer program executable by the at least one processor, and the computer program is executed by the at least one processor so that the at least one processor can execute the method for determining the crude oil volume coefficient described in any embodiment of the present invention.

[0020] According to another aspect of the present invention, a computer-readable storage medium is provided, wherein the computer-readable storage medium stores computer instructions, and the computer instructions are used to enable a processor to implement the method for determining the crude oil volume coefficient described in any embodiment of the present invention when executed.

[0021] The technical solution of the embodiment of the present invention obtains the parameter sequence under the original formation pressure conditions of different single wells through test data, establishes the crude oil volume coefficient prediction model under the original formation pressure conditions according to the parameter sequence, determines the crude oil volume coefficient under the original formation pressure conditions of the well to be predicted according to the parameter sequence and the crude oil volume coefficient prediction model, constructs the relationship between the crude oil volume coefficient and the formation pressure of different single wells according to the parameter sequence, and determines the crude oil volume coefficient of the well to be predicted under different formation pressure conditions according to the relationship. This method complements the method of calculating the crude oil volume coefficient under different formation pressure conditions using test data by determining the relationship between the crude oil volume coefficient and the formation pressure of the well to be predicted under different formation pressure conditions, and improves the accuracy of calculating the crude oil volume coefficient.

[0022] It should be understood that the contents described in this section are not intended to identify the key or important features of the embodiments of the present invention, nor are they intended to limit the scope of the present invention. Other features of the present invention will become easily understood through the following description. BRIEF DESCRIPTION OF THE DRAWINGS

[0023] In order to more clearly illustrate the technical solutions in the embodiments of the present invention, the following briefly introduces the drawings required for use in the description of the embodiments. Obviously, the drawings described below are only some embodiments of the present invention. For ordinary technicians in this field, other drawings can be obtained based on these drawings without creative work.

[0024] Figure 1 is a flow chart of a method for determining a crude oil volume coefficient provided in accordance with an embodiment of the present invention;

[0025] Figure 2 is a flow chart of a method for determining a crude oil volume coefficient provided in accordance with an embodiment of the present invention;

[0026] Figure 3 is a graph showing the relationship between the crude oil volume coefficient and the formation pressure of a typical well provided in an embodiment of the present invention;

[0027] Figure 4 It is a relationship chart between crude oil volume coefficient and formation pressure of a medium oil type single well provided in an embodiment of the present invention;

[0028] Figure 5 It is a relationship chart between crude oil volume coefficient and formation pressure of a light oil type single well provided in an embodiment of the present invention;

[0029] Figure 6 is a flow chart of a method for determining a crude oil volume coefficient provided in accordance with an embodiment of the present invention;

[0030] Figure 7It is a chart showing the relationship between the gasoline production ratio and the crude oil volume coefficient drawn based on various existing prediction models;

[0031] Figure 8 is a schematic structural diagram of a device for determining a crude oil volume coefficient provided according to a second embodiment of the present invention;

[0032] Fig. 9 It is a schematic diagram of the structure of an electronic device for implementing the method for determining the crude oil volume coefficient according to an embodiment of the present invention. DETAILED DESCRIPTION

[0033] In order to enable those skilled in the art to better understand the scheme of the present invention, the technical scheme in the embodiments of the present invention will be clearly and completely described below in conjunction with the drawings in the embodiments of the present invention. Obviously, the described embodiments are only part of the embodiments of the present invention, not all of the embodiments. Based on the embodiments of the present invention, all other embodiments obtained by ordinary technicians in this field without creative work should fall within the scope of protection of the present invention.

[0034] It should be noted that the terms "first", "second", etc. in the specification and claims of the present invention and the above-mentioned drawings are used to distinguish similar objects, and are not necessarily used to describe a specific order or sequence. It should be understood that the data used in this way can be interchanged where appropriate, so that the embodiments of the present invention described herein can be implemented in an order other than those illustrated or described herein. In addition, the terms "including" and "having" and any variations thereof are intended to cover non-exclusive inclusions, for example, a process, method, system, product or device that includes a series of steps or units is not necessarily limited to those steps or units that are clearly listed, but may include other steps or units that are not clearly listed or inherent to these processes, methods, products or devices.

[0035] Embodiment 1

[0036] Figure 1 A flowchart of a method for determining a crude oil volume coefficient is provided for the first embodiment of the present invention. This embodiment is applicable to the case of determining a crude oil volume coefficient. The method can be executed by a device for determining a crude oil volume coefficient. The device for determining a crude oil volume coefficient can be implemented in the form of hardware and / or software. The device for determining a crude oil volume coefficient can be configured in any electronic device with a network communication function. Figure 1 As shown, the method may include:

[0037] S110, obtaining a parameter sequence under original formation pressure conditions of different single wells according to the test data, wherein the parameter sequence includes: production gasoline ratio, formation pressure, crude oil volume coefficient, compression coefficient, formation degassed crude oil density and natural gas relative density.

[0038] Specifically, test data are obtained based on experimental analysis, and parameters such as production gasoline ratio, formation pressure, crude oil volume coefficient, compression coefficient, formation degassed crude oil density and natural gas relative density of different wells under original formation pressure conditions are obtained from the existing test data.

[0039] Exemplarily, test data is obtained through experimental analysis, and parameter sequences of different wells are obtained from the test data. The parameter sequence may include the contents shown in the following table.

[0040] Table 1: Parameter sequence summary table

[0041]

[0042]

[0043] S120. Establishing a crude oil volume coefficient prediction model under original formation pressure conditions according to the parameter sequence.

[0044] Specifically, the above steps obtain parameter sequences of different single wells testing the same type of formation, and establish the correlation between the crude oil volume coefficient and the production gasoline ratio, the ground degassed crude oil density and the relative density of natural gas under the original formation pressure conditions according to the prediction model analysis method based on statistical principles. The crude oil volume coefficient predicted by each prediction model analysis method for different single wells is compared with the crude oil volume coefficient obtained by the experimental test method, and the prediction model analysis method with the smallest difference between the crude oil volume coefficients obtained by the two methods is determined as the crude oil volume coefficient prediction model, wherein the prediction model analysis methods based on statistical principles include: least squares method, stepwise regression method, partial least squares regression method, Lasso method and ridge regression method.

[0045] Exemplarily, the crude oil volume coefficient obtained by each prediction model analysis method is compared with the crude oil volume coefficient obtained by the experimental test method, and the prediction model analysis method that is closest to the crude oil volume coefficient obtained by the experimental test method is used as the prediction model of the crude oil volume coefficient. The crude oil volume coefficients of different single wells under the original pressure conditions in Table 1 are predicted according to the prediction model of the crude oil volume coefficient. The results predicted by the prediction model of the crude oil volume coefficient are shown in Table 2.

[0046] Table 2: Summary of prediction results of crude oil volume coefficient prediction model

[0047]

[0048]

[0049] S130, determining the crude oil volume coefficient under the original formation pressure condition of the well to be predicted according to the parameter sequence and the crude oil volume coefficient prediction model.

[0050] Specifically, according to the parameter sequence obtained in S110, the parameter sequence of the well to be predicted under the original formation pressure conditions is determined, and the production gasoline ratio, ground degassed crude oil density and natural gas relative density parameters of the parameter sequence are input into the crude oil volume coefficient prediction model to determine the crude oil volume coefficient of the well to be predicted under the original formation pressure conditions.

[0051] S140, constructing a relationship between the crude oil volume coefficient and the formation pressure of different single wells according to the parameter sequence, and determining the crude oil volume coefficient of the well to be predicted under different formation pressure conditions according to the relationship.

[0052] Specifically, before determining the relationship between the crude oil volume coefficient and the formation pressure of different single wells, it is necessary to determine the crude oil compressibility coefficient of different single wells under different formation pressure conditions and different formation pressure values ​​according to the parameter sequence, and calculate the crude oil volume coefficient of different single wells under different formation pressure conditions according to the following formula.

[0053] B o =B oi *[1-C o *(PP i )]

[0054] Among them, B o It indicates the volume coefficient of crude oil under different formation pressure conditions above saturation pressure, and the unit is m3 / m3; C o It indicates the compression coefficient of crude oil under different formation pressure conditions above the saturation pressure; P indicates the values ​​of different formation pressures above the saturation pressure.

[0055] Specifically, according to the corresponding relationship between the crude oil volume coefficient and the formation pressure value of different single wells under different formation pressure conditions, a relationship chart of the crude oil volume coefficient and the formation pressure value of different single wells is drawn, and based on the power exponential regression method, the relationship formula between the crude oil volume coefficient and the formation pressure value of different single wells is determined.

[0056] Specifically, a single well whose crude oil volume coefficient difference with that of the well to be predicted under the same formation pressure conditions meets a preset difference threshold is selected as a similar single well, and a relationship is reconstructed according to the relationship between the crude oil volume coefficient and the formation pressure value of the similar single well to determine the relationship between the crude oil volume coefficient and the formation pressure value of the well to be predicted, and the formation pressure value of the well to be predicted is input into the relationship between the crude oil volume coefficient and the formation pressure value to determine the crude oil volume coefficient of the well to be predicted.

[0057] The embodiment of the present application proposes a method for determining the crude oil volume coefficient, which obtains a parameter sequence under the original formation pressure conditions of different single wells through test data, establishes a crude oil volume coefficient prediction model under the original formation pressure conditions according to the parameter sequence, determines the crude oil volume coefficient under the original formation pressure conditions of the well to be predicted according to the parameter sequence and the crude oil volume coefficient prediction model, constructs a relationship between the crude oil volume coefficient and the formation pressure of different single wells according to the parameter sequence, and determines the crude oil volume coefficient of the well to be predicted under different formation pressure conditions according to the relationship. This method complements the method of calculating the crude oil volume coefficient under different formation pressure conditions using test data by determining the relationship between the crude oil volume coefficient and the formation pressure of the well to be predicted under different formation pressure conditions, and improves the accuracy of calculating the crude oil volume coefficient.

[0058] Figure 2 A flowchart of a method for determining a crude oil volume coefficient provided in an embodiment of the present invention is provided. This embodiment is based on the above embodiment and describes in detail the process of constructing a relationship between the crude oil volume coefficient and formation pressure of different single wells according to the parameter sequence, and determining the crude oil volume coefficient of the well to be predicted under different formation pressure conditions according to the relationship. Figure 2 As shown, the method may include:

[0059] S210. Obtain parameter sequences under original formation pressure conditions of different single wells based on test data, wherein the parameter sequences include: production gasoline ratio, formation pressure, crude oil volume coefficient, compression coefficient, formation degassed crude oil density and natural gas relative density.

[0060] S220. Establishing a crude oil volume coefficient prediction model under original formation pressure conditions according to the parameter sequence.

[0061] S230, determining the crude oil volume coefficient under the original formation pressure condition of the well to be predicted according to the parameter sequence and the crude oil volume coefficient prediction model.

[0062] S240. Determine the crude oil volume coefficients of different single wells under different formation pressure conditions according to the parameter sequence, and draw a chart of different formation pressures and crude oil volume coefficients.

[0063] Specifically, the crude oil compressibility coefficients of different single wells under different formation pressure conditions and different formation pressure values ​​are determined according to the parameter sequence, and the crude oil volume coefficients of different single wells under different formation pressure conditions are calculated according to the following formula.

[0064] B o =B oi *[1-C o *(PP i )]

[0065] Among them, B oIt indicates the volume coefficient of crude oil under different formation pressure conditions above saturation pressure, and the unit is m3 / m3; C o It indicates the compression coefficient of crude oil under different formation pressure conditions above the saturation pressure; P indicates the values ​​of different formation pressures above the saturation pressure.

[0066] Specifically, for each single well, there are different formation pressure values ​​and crude oil volume coefficients corresponding to the formation pressure values. According to the corresponding relationship between the different formation pressure values ​​and crude oil volume coefficients of each single well, a chart of different formation pressures and crude oil volume coefficients is drawn for each single well. For example, Figure 3 To draw a graph of the relationship between the crude oil volume coefficient and the formation pressure of a typical well, Figure 4 To draw the relationship between crude oil volume coefficient and formation pressure for a single medium oil well, Figure 5 In order to draw a relationship chart between the crude oil volume coefficient and the formation pressure of a light oil single well, the relationship formula between the crude oil volume coefficient and the formation pressure of different single wells can be determined according to the charts of different formation pressures and crude oil volume coefficients.

[0067] S250. According to the charts of different formation pressures and crude oil volume coefficients, a relationship between the crude oil volume coefficients and formation pressures of the different single wells is constructed based on a power exponential regression method.

[0068] Specifically, graphs of different formation pressures and crude oil volume coefficients are drawn for different single wells of different types, and the relationship between the crude oil volume coefficient and formation pressure of different single wells is established based on the power exponential regression method according to the graphs of different formation pressures and crude oil volume coefficients of different single wells.

[0069] For example, the relationship between the crude oil volume coefficient and the formation pressure of different single wells is as follows:

[0070] B o =aP b

[0071] Wherein, a represents the coefficient of the relationship between the crude oil volume coefficient and the formation pressure; b represents the power exponent of the relationship between the crude oil volume coefficient and the formation pressure.

[0072] For example, the relationship between the crude oil volume coefficient and the formation pressure of different single wells obtained by the power exponential regression method is shown in Table 3.

[0073] Table 3: Summary of the relationship between crude oil volume coefficient and formation pressure for different single wells

[0074]

[0075] S260, selecting a single well whose crude oil volume coefficient difference with the well to be predicted under the same pressure conditions meets a preset difference threshold as a similar single well.

[0076] Among them, the same pressure condition can be understood as different types of single wells with the same formation pressure value as the well to be tested, and the preset difference threshold can be used to screen different types of single wells with the same pressure conditions as the well to be tested as the judgment condition for similar single wells.

[0077] Specifically, the crude oil volume coefficient of the well to be predicted obtained in S230 is compared with different types of single wells with the same pressure conditions as the well to be predicted, the difference in crude oil volume coefficient between the well to be predicted and the different types of single wells is calculated, and the single well whose difference meets the preset difference threshold is selected as a similar single well.

[0078] Exemplarily, by comparing the crude oil volume coefficients of different single wells with the well to be predicted, it is determined that the well number of the single well similar to the well to be predicted is P312, and the parameter values ​​of the similar single well and the well to be predicted are shown in the following table.

[0079] Table 4: Key parameter values ​​of the well to be predicted and similar single wells

[0080]

[0081] S270. Determine the relationship between the crude oil volume coefficient and formation pressure of the well to be predicted under different formation pressure conditions based on the relationship between the crude oil volume coefficient and formation pressure of the similar single well, the crude oil volume coefficient of the well to be predicted, and the formation pressure of the well to be predicted.

[0082] As an optional but not limiting implementation, the relationship between the crude oil volume coefficient and the formation pressure of the well to be predicted under different formation pressure conditions is determined according to the relationship between the crude oil volume coefficient and the formation pressure of the similar single well, the crude oil volume coefficient of the well to be predicted, and the formation pressure of the well to be predicted, including steps A1-A3:

[0083] Step A1: Determine the power exponent of the relationship between the crude oil volume coefficient and the formation pressure of the similar single well as the power exponent of the relationship between the crude oil volume coefficient and the formation pressure of the well to be predicted.

[0084] Specifically, the power exponent in the relationship between the crude oil volume coefficient and the formation pressure of similar single wells is obtained, and the relationship is reconstructed according to the relationship between the crude oil volume coefficient and the formation pressure of similar single wells. Therefore, the power exponent is used as the power exponent of the relationship between the crude oil volume coefficient and the formation pressure of the well to be predicted.

[0085] For example, according to the key parameters of similar single wells recorded in Table 4, the power exponent b in the relationship between the crude oil volume coefficient and the formation pressure of the similar single well is -0.105, and this power exponent is used as the power exponent of the relationship between the crude oil volume coefficient and the formation pressure of the well to be predicted.

[0086] Step A2: the ratio of the crude oil volume coefficient under the original formation pressure condition to the power exponent of the crude oil volume coefficient corresponding to the formation pressure is used as the correlation coefficient of the relationship between the crude oil volume coefficient and the formation pressure of the well to be predicted.

[0087] Specifically, the relationship between the crude oil volume coefficient and formation pressure of different single wells is:

[0088] B o =aP b

[0089] Wherein, a represents the coefficient of the relationship between the crude oil volume coefficient and the formation pressure; b represents the power exponent of the relationship between the crude oil volume coefficient and the formation pressure.

[0090] Specifically, from the relationship between the crude oil volume coefficient and the formation pressure of different single wells, it can be deduced that the coefficient of the relationship between the crude oil volume coefficient and the formation pressure can be expressed as:

[0091]

[0092] For example, according to Table 4, the crude oil volume coefficient calculated according to the empirical formula method is 1.3990, the formation pressure value of the well to be predicted is 86.62, and the power exponent in the relationship between the crude oil volume coefficient and the formation pressure is -0.105. Substituting the above three parameters into the above formula, the coefficient of the relationship between the crude oil volume coefficient and the formation pressure of the well to be predicted is 2.2349.

[0093] Step A3: reconstructing the relationship between the crude oil volume coefficient and the formation pressure of the well to be predicted under different pressure conditions according to the crude oil volume coefficient under the original formation pressure condition, the power index and the correlation coefficient.

[0094] Specifically, the crude oil volume coefficient, formation pressure value and power exponent of the well to be predicted under the original formation pressure conditions are obtained, and the coefficients of the relationship between the crude oil volume coefficient and the formation pressure of the well to be predicted are assigned according to the coefficients of the relationship determined in step A2, and the relationship between the crude oil volume coefficient and the formation pressure of the well to be predicted is reconstructed according to the power exponent determined in step A1 and the coefficient determined in step A3.

[0095] Exemplarily, the parameters determined in step A1 and step A2 are reconstructed to obtain a relationship formula capable of calculating the crude oil volume coefficient of the well to be predicted under different pressure conditions, as shown below:

[0096] Bo=2.2349P -0.105

[0097] S280, determining the crude oil volume coefficient of the well to be predicted under different formation pressure conditions according to the relationship between the crude oil volume coefficient and formation pressure of the well to be predicted.

[0098] As an optional but not limiting implementation, the crude oil volume coefficient of the well to be predicted under different formation pressure conditions is determined according to the relationship between the crude oil volume coefficient and formation pressure of the well to be predicted, including steps B1-B2:

[0099] Step B1, determining the formation pressure value of the well to be predicted under different formation pressure conditions;

[0100] Specifically, a parameter sequence is extracted according to the real data of the experimental test data, and different formation pressure values ​​of the well to be predicted are obtained according to the parameter sequence.

[0101] Step B2: input the formation pressure values ​​under the different formation pressure conditions into the relationship between the crude oil volume coefficient and formation pressure of the well to be predicted, so as to obtain the crude oil volume coefficient of the well to be predicted under different formation pressure conditions.

[0102] Specifically, by experimentally testing the formation pressure values ​​of the wells to be predicted on different dates under different formation pressure conditions, the formation pressure values ​​are input into the relationship between the crude oil volume coefficient and formation pressure of the wells to be predicted, and the crude oil volume coefficient of the wells to be predicted under different formation pressure conditions can be obtained.

[0103] For example, different formation pressure values ​​of the wells to be predicted on different dates are obtained through experiments, and the different formation pressure values ​​are substituted into the relationship between the crude oil volume coefficient and formation pressure of the wells to be predicted, so as to obtain the crude oil volume coefficient of the wells to be predicted under different formation pressure conditions, as shown in Table 5.

[0104] Table 5: Crude oil volume coefficient of Well T1 under different formation pressure conditions

[0105]

[0106]

[0107] The embodiment of the present application proposes a method for determining the crude oil volume coefficient, which obtains a parameter sequence under the original formation pressure conditions of different single wells through test data, establishes a crude oil volume coefficient prediction model under the original formation pressure conditions according to the parameter sequence, determines the crude oil volume coefficient under the original formation pressure conditions of the well to be predicted according to the parameter sequence and the crude oil volume coefficient prediction model, constructs a relationship between the crude oil volume coefficient and the formation pressure of different single wells according to the parameter sequence, and determines the crude oil volume coefficient of the well to be predicted under different formation pressure conditions according to the relationship. This method complements the method of calculating the crude oil volume coefficient under different formation pressure conditions using test data by determining the relationship between the crude oil volume coefficient and the formation pressure of the well to be predicted under different formation pressure conditions, and improves the accuracy of calculating the crude oil volume coefficient.

[0108] Figure 6The present invention provides a flowchart of a method for determining the crude oil volume coefficient. This embodiment is based on the above embodiment and describes in detail how to determine the crude oil volume coefficient under the original formation pressure of the well to be predicted based on the parameter sequence and the crude oil volume coefficient prediction model. Figure 6 As shown, the method may include:

[0109] S310. Obtain parameter sequences under original formation pressure conditions of different single wells based on test data, wherein the parameter sequences include: production gasoline ratio, formation pressure, crude oil volume coefficient, compression coefficient, formation degassed crude oil density and natural gas relative density.

[0110] S320. Perform correlation analysis on various parameters in the parameter sequences of different single wells through the existing prediction model to predict the crude oil volume coefficients of different single wells.

[0111] Specifically, based on the parameter sequences of different single wells, the production gasoline ratio, formation degassed crude oil density, natural gas relative density and formation pressure of different single wells are extracted, and the correlation between the crude oil volume coefficient of different single wells and the above parameters is established through a statistical prediction model, and the crude oil volume coefficient of different single wells is predicted based on the correlation analysis results.

[0112] Optionally, the existing prediction models include: least squares method, stepwise regression method, partial least squares regression method, Lasso method and ridge regression method.

[0113] Exemplarily, the existing statistical prediction models, including least squares method, stepwise regression method, partial least squares regression method, Lasso method and ridge regression method, are used to predict the formation crude oil volume coefficient of different single wells as shown in the following table.

[0114] Table 6: Comparison of crude oil volume coefficients obtained by experimental testing and prediction model

[0115]

[0116]

[0117] S330. Determine the crude oil volume coefficient of different single wells through experimental testing.

[0118] For example, the crude oil volume coefficients of different single wells tested in the experiment are shown in the second column of Table 6.

[0119] S340, respectively comparing the differences between the crude oil volume coefficients obtained from different single wells predicted by various existing prediction models and the crude oil volume coefficients determined by experimental tests.

[0120] Specifically, by comparing and analyzing the prediction results of the crude oil volume coefficient of each existing prediction model and the crude oil volume coefficient obtained by experimental testing, the difference between the two methods in obtaining the crude oil volume coefficient is determined.

[0121] S350: Determine the existing prediction model with the smallest gap as the crude oil volume coefficient prediction model under the original formation pressure condition.

[0122] Specifically, by looking at Table 6, it can be found that the least squares prediction model has the smallest difference from the crude oil volume coefficient obtained by the experimental test, and referring to Figure 7 According to the relationship chart between the production gasoline ratio and the crude oil volume coefficient drawn by various existing prediction models, it can be found that the least squares prediction model has the highest fit with the experimental test results, so the prediction model of the crude oil volume coefficient established by the least squares prediction model is as follows:

[0123] B oi =f(P i ,GOR,ρ o ,ρ g )=M+N*GOR-F*P i -L*ρ o +T*ρ g

[0124] Among them, P i represents the original formation pressure, in MPa; GOR represents the production gas-oil ratio during the test sampling period, in m3 / m3; ρ o Indicates the density of ground degassed crude oil, in g / cm3; ρ g Represents the relative density of natural gas, the unit is g / cm3; where M=2.672; N=0.003; F=0.003; L=1.823; T=192.882.

[0125] S360, obtaining the original formation pressure, surface degassed crude oil density, natural gas relative density and production gas-oil ratio parameters of the well to be predicted in the parameter sequence.

[0126] Specifically, a parameter list is obtained from the test data, and the original formation pressure, surface degassed crude oil density, natural gas relative density and production gas-oil ratio of the well to be predicted are obtained from the parameter list, such as Table 1.

[0127] S370, input the original formation pressure, surface degassed crude oil density, natural gas relative density and production gas-oil ratio parameters of the well to be predicted into the function corresponding to the crude oil volume coefficient prediction model to determine the crude oil volume coefficient under the original formation pressure conditions of the well to be predicted.

[0128] Specifically, the original formation pressure, surface degassed crude oil density, natural gas relative density and production gas-oil ratio parameters of the well to be predicted are input into the function corresponding to the crude oil volume coefficient prediction model, so that the crude oil volume coefficient under the original formation pressure of the well to be predicted can be determined. The function corresponding to the crude oil volume coefficient prediction model can be expressed as:

[0129] B oi =f(P i ,GOR,ρ o ,ρ g )=2.672+0.003*GOR-0.003*P i -1.823*ρ o +192.882*ρ g

[0130] S380, constructing a relationship between the crude oil volume coefficient and formation pressure of different single wells according to the parameter sequence, and determining the crude oil volume coefficient of the well to be predicted under different formation pressure conditions according to the relationship.

[0131] Specifically, according to S370, the crude oil volume coefficient of the well to be predicted is obtained, and the relationship between the crude oil volume coefficient and the formation pressure value is determined according to the relationship chart of the crude oil volume coefficient and the formation pressure value of different single wells, and the power exponent in the relationship is determined as the power exponent of the relationship between the crude oil volume coefficient and the formation pressure of the well to be predicted. The coefficient of the relationship between the crude oil volume coefficient and the formation pressure of the well to be predicted can be determined by the first two known parameters. The relationship between the crude oil volume coefficient and the formation pressure of the well to be predicted can be reconstructed according to the above three parameters. The crude oil volume coefficient of the well to be predicted under different formation pressure conditions is determined according to the relationship. The prediction accuracy of the original volume coefficient of the well to be predicted can be improved by reconstructing the relationship.

[0132] The embodiment of the present application proposes a method for determining the crude oil volume coefficient, which obtains a parameter sequence under the original formation pressure conditions of different single wells through test data, establishes a crude oil volume coefficient prediction model under the original formation pressure conditions according to the parameter sequence, determines the crude oil volume coefficient under the original formation pressure conditions of the well to be predicted according to the parameter sequence and the crude oil volume coefficient prediction model, constructs a relationship between the crude oil volume coefficient and the formation pressure of different single wells according to the parameter sequence, and determines the crude oil volume coefficient of the well to be predicted under different formation pressure conditions according to the relationship. This method complements the method of calculating the crude oil volume coefficient under different formation pressure conditions using test data by determining the relationship between the crude oil volume coefficient and the formation pressure of the well to be predicted under different formation pressure conditions, and improves the accuracy of calculating the crude oil volume coefficient.

[0133] Embodiment 2

[0134] Figure 8This is a schematic diagram of the structure of a crude oil volume coefficient determination device provided in the third embodiment of the present invention. The device can execute the crude oil volume coefficient determination method provided in any embodiment of the present application, and has the corresponding functional modules and beneficial effects of the execution method. Figure 8 As shown, the device may include:

[0135] The parameter sequence acquisition module 410 is used to acquire the parameter sequence under the original formation pressure conditions of different single wells according to the test data;

[0136] A prediction model building module 420 is used to build a crude oil volume coefficient prediction model under the original formation pressure condition according to the parameter sequence;

[0137] A crude oil volume coefficient determination module 430 is used to determine the crude oil volume coefficient under the original formation pressure condition of the well to be predicted based on the parameter sequence and the crude oil volume coefficient prediction model;

[0138] The relationship determination module 440 constructs a relationship between the crude oil volume coefficient and the formation pressure of different single wells according to the parameter sequence, and determines the crude oil volume coefficient of the well to be predicted under different formation pressure conditions according to the relationship.

[0139] Further, the relationship determination module 440 includes:

[0140] A chart drawing unit, used to determine the crude oil volume coefficients of different single wells under different formation pressure conditions according to the parameter sequence, and draw charts of different formation pressures and crude oil volume coefficients;

[0141] A first relationship determination unit is used to construct a relationship between the crude oil volume coefficient and the formation pressure of the different single wells based on the power exponential regression method according to the charts of different formation pressures and crude oil volume coefficients;

[0142] A similar single well selection unit is used to select a single well whose crude oil volume coefficient difference with the well to be predicted under the same pressure conditions meets a preset difference threshold as a similar single well;

[0143] a second relationship determination unit, configured to determine the relationship between the crude oil volume coefficient and the formation pressure of the well to be predicted under different formation pressure conditions according to the relationship between the crude oil volume coefficient and the formation pressure of the similar single well, the crude oil volume coefficient of the well to be predicted, and the formation pressure of the well to be predicted;

[0144] The crude oil volume coefficient determination unit is used to determine the crude oil volume coefficient of the well to be predicted under different formation pressure conditions according to the relationship between the crude oil volume coefficient of the well to be predicted and the formation pressure.

[0145] Further, the relationship formula second determining unit is specifically used for:

[0146] Determine the power exponent of the relationship between the crude oil volume coefficient and the formation pressure of the similar single well as the power exponent of the relationship between the crude oil volume coefficient and the formation pressure of the well to be predicted;

[0147] The ratio of the crude oil volume coefficient under the original formation pressure condition to the power exponent of the crude oil volume coefficient corresponding to the formation pressure is used as the correlation coefficient of the relationship between the crude oil volume coefficient and the formation pressure of the well to be predicted;

[0148] The relationship between the crude oil volume coefficient and the formation pressure of the well to be predicted under different pressure conditions is reconstructed according to the crude oil volume coefficient under the original formation pressure condition, the power index and the correlation coefficient.

[0149] Furthermore, the crude oil volume coefficient determination unit is specifically used for:

[0150] Determine the formation pressure value of the well to be predicted under different formation pressure conditions;

[0151] The formation pressure values ​​under the different formation pressure conditions are input into the relationship between the crude oil volume coefficient and the formation pressure of the well to be predicted, so as to obtain the crude oil volume coefficient of the well to be predicted under the different formation pressure conditions.

[0152] Furthermore, the prediction model building module 420 includes:

[0153] The crude oil volume coefficient prediction unit is used to perform correlation analysis on various parameters in the parameter sequences of different single wells through the existing prediction model, and predict the crude oil volume coefficients of different single wells;

[0154] A first crude oil volume coefficient determination unit is used to determine the crude oil volume coefficients of different single wells through experimental tests;

[0155] A gap value acquisition unit is used to compare the gaps between the crude oil volume coefficients obtained from different single wells predicted by various existing prediction models and the crude oil volume coefficients determined by experimental tests;

[0156] The crude oil volume coefficient prediction model is used to determine the existing prediction model with the smallest gap as the crude oil volume coefficient prediction model under the original formation pressure condition.

[0157] Furthermore, the crude oil volume coefficient determination module 430 includes:

[0158] A parameter acquisition unit for the well to be predicted, used to acquire the original formation pressure, surface degassed crude oil density, natural gas relative density and production gas-oil ratio parameters of the well to be predicted in the parameter sequence;

[0159] The second determination unit of the crude oil volume coefficient is used to input the original formation pressure, ground degassed crude oil density, natural gas relative density and production gas-oil ratio parameters of the well to be predicted into the function corresponding to the crude oil volume coefficient prediction model to determine the crude oil volume coefficient under the original formation pressure conditions of the well to be predicted.

[0160] Furthermore, the existing prediction models include: least squares method, stepwise regression method, partial least squares regression method, Lasso method and ridge regression method.

[0161] The crude oil volume coefficient determination device provided in the embodiment of the present invention can execute the crude oil volume coefficient determination method provided in any embodiment of the present invention, and has the corresponding functions and beneficial effects of executing the crude oil volume coefficient determination method. For detailed process, please refer to the relevant operations of the crude oil volume coefficient determination method in the aforementioned embodiment.

[0162] Embodiment 4

[0163] Fig. 9 A schematic diagram of the structure of an electronic device 10 that can be used to implement an embodiment of the present invention is shown. The electronic device is intended to represent various forms of digital computers, such as laptop computers, desktop computers, workstations, personal digital assistants, servers, blade servers, mainframe computers, and other suitable computers. The electronic device can also represent various forms of mobile devices, such as personal digital processing, cellular phones, smart phones, wearable devices (such as helmets, glasses, watches, etc.) and other similar computing devices. The components shown herein, their connections and relationships, and their functions are merely examples and are not intended to limit the implementation of the present invention described and / or required herein.

[0164] like Fig. 9 As shown, the electronic device 10 includes at least one processor 11, and a memory connected to the at least one processor 11, such as a read-only memory (ROM) 12, a random access memory (RAM) 13, etc., wherein the memory stores a computer program that can be executed by at least one processor, and the processor 11 can perform various appropriate actions and processes according to the computer program stored in the read-only memory (ROM) 12 or the computer program loaded from the storage unit 18 to the random access memory (RAM) 13. In the RAM 13, various programs and data required for the operation of the electronic device 10 can also be stored. The processor 11, the ROM 12, and the RAM 13 are connected to each other through a bus 14. An input / output (I / O) interface 15 is also connected to the bus 14.

[0165] A number of components in the electronic device 10 are connected to the I / O interface 15, including: an input unit 16, such as a keyboard, a mouse, etc.; an output unit 17, such as various types of displays, speakers, etc.; a storage unit 18, such as a disk, an optical disk, etc.; and a communication unit 19, such as a network card, a modem, a wireless communication transceiver, etc. The communication unit 19 allows the electronic device 10 to exchange information / data with other devices through a computer network such as the Internet and / or various telecommunication networks.

[0166] The processor 11 may be a variety of general and / or special processing components with processing and computing capabilities. Some examples of the processor 11 include, but are not limited to, a central processing unit (CPU), a graphics processing unit (GPU), various special artificial intelligence (AI) computing chips, various processors running machine learning model algorithms, a digital signal processor (DSP), and any appropriate processor, controller, microcontroller, etc. The processor 11 executes the various methods and processes described above, such as a method for determining a crude oil volume coefficient.

[0167] In some embodiments, the method for determining the crude oil volume coefficient may be implemented as a computer program, which is tangibly contained in a computer-readable storage medium, such as a storage unit 18. In some embodiments, part or all of the computer program may be loaded and / or installed on the electronic device 10 via the ROM 12 and / or the communication unit 19. When the computer program is loaded into the RAM 13 and executed by the processor 11, one or more steps of the method for determining the crude oil volume coefficient described above may be performed. Alternatively, in other embodiments, the processor 11 may be configured to perform the method for determining the crude oil volume coefficient in any other appropriate manner (e.g., by means of firmware).

[0168] Various implementations of the systems and techniques described above herein can be implemented in digital electronic circuit systems, integrated circuit systems, field programmable gate arrays (FPGAs), application specific integrated circuits (ASICs), application specific standard products (ASSPs), systems on chips (SOCs), load programmable logic devices (CPLDs), computer hardware, firmware, software, and / or combinations thereof. These various implementations can include: being implemented in one or more computer programs that can be executed and / or interpreted on a programmable system including at least one programmable processor, which can be a special purpose or general purpose programmable processor that can receive data and instructions from a storage system, at least one input device, and at least one output device, and transmit data and instructions to the storage system, the at least one input device, and the at least one output device.

[0169] Computer programs for implementing the methods of the present invention may be written in any combination of one or more programming languages. These computer programs may be provided to a processor of a general-purpose computer, a special-purpose computer, or other programmable data processing device, so that when the computer program is executed by the processor, the functions / operations specified in the flow chart and / or block diagram are implemented. The computer program may be executed entirely on the machine, partially on the machine, partially on the machine and partially on a remote machine as a stand-alone software package, or entirely on a remote machine or server.

[0170] In the context of the present invention, a computer-readable storage medium may be a tangible medium that may contain or store a computer program for use by or in combination with an instruction execution system, device or equipment. A computer-readable storage medium may include, but is not limited to, electronic, magnetic, optical, electromagnetic, infrared, or semiconductor systems, devices or equipment, or any suitable combination of the foregoing. Alternatively, a computer-readable storage medium may be a machine-readable signal medium. A more specific example of a machine-readable storage medium may include an electrical connection based on one or more lines, a portable computer disk, a hard disk, a random access memory (RAM), a read-only memory (ROM), an erasable programmable read-only memory (EPROM or flash memory), an optical fiber, a portable compact disk read-only memory (CD-ROM), an optical storage device, a magnetic storage device, or any suitable combination of the foregoing.

[0171] To provide interaction with a user, the systems and techniques described herein may be implemented on an electronic device having: a display device (e.g., a CRT (cathode ray tube) or LCD (liquid crystal display) monitor) for displaying information to the user; and a keyboard and a pointing device (e.g., a mouse or trackball) through which the user can provide input to the electronic device. Other types of devices may also be used to provide interaction with the user; for example, the feedback provided to the user may be any form of sensory feedback (e.g., visual feedback, auditory feedback, or tactile feedback); and input from the user may be received in any form (including acoustic input, voice input, or tactile input).

[0172] The systems and techniques described herein may be implemented in a computing system that includes backend components (e.g., as a data server), or a computing system that includes middleware components (e.g., an application server), or a computing system that includes frontend components (e.g., a user computer with a graphical user interface or a web browser through which a user can interact with implementations of the systems and techniques described herein), or a computing system that includes any combination of such backend components, middleware components, or frontend components. The components of the system may be interconnected by any form or medium of digital data communication (e.g., a communication network). Examples of communication networks include: a local area network (LAN), a wide area network (WAN), a blockchain network, and the Internet.

[0173] A computing system may include a client and a server. The client and the server are generally remote from each other and usually interact through a communication network. The client and server relationship is generated by computer programs running on the corresponding computers and having a client-server relationship with each other. The server may be a cloud server, also known as a cloud computing server or cloud host, which is a host product in the cloud computing service system to solve the defects of difficult management and weak business scalability in traditional physical hosts and VPS services.

[0174] It should be understood that the various forms of processes shown above can be used to reorder, add or delete steps. For example, the steps described in the present invention can be executed in parallel, sequentially or in different orders, as long as the desired results of the technical solution of the present invention can be achieved, and this document does not limit this.

[0175] The above specific implementations do not constitute a limitation on the protection scope of the present invention. It should be understood by those skilled in the art that various modifications, combinations, sub-combinations and substitutions can be made according to design requirements and other factors. Any modification, equivalent substitution and improvement made within the spirit and principle of the present invention should be included in the protection scope of the present invention.

Claims

1. A method for determining a crude oil volume coefficient, characterized in that: include: Obtaining parameter sequences under original formation pressure conditions of different single wells based on test data, the parameter sequences include: production gasoline ratio, formation pressure, crude oil volume coefficient, compression coefficient, formation degassed crude oil density and natural gas relative density; Establishing a crude oil volume coefficient prediction model under original formation pressure conditions according to the parameter sequence; Determining the crude oil volume coefficient under the original formation pressure condition of the well to be predicted based on the parameter sequence and the crude oil volume coefficient prediction model; A relationship between the crude oil volume coefficient and formation pressure of different single wells is constructed according to the parameter sequence, and the crude oil volume coefficient of the well to be predicted under different formation pressure conditions is determined according to the relationship.

2. The method according to claim 1, characterized in that Constructing a relationship between the crude oil volume coefficient and formation pressure of different single wells according to the parameter sequence, and determining the crude oil volume coefficient of the well to be predicted under different formation pressure conditions according to the relationship, including: Determine the crude oil volume coefficient of different single wells under different formation pressure conditions according to the parameter sequence, and draw a chart of different formation pressures and crude oil volume coefficients; According to the charts of different formation pressures and crude oil volume coefficients, a relationship between the crude oil volume coefficient and formation pressure of the different single wells is constructed based on the power exponential regression method; A single well whose crude oil volume coefficient difference with the well to be predicted under the same pressure conditions meets the preset difference threshold is selected as a similar single well; Determine the relationship between the crude oil volume coefficient and the formation pressure of the well to be predicted under different formation pressure conditions according to the relationship between the crude oil volume coefficient and the formation pressure of the similar single well, the crude oil volume coefficient of the well to be predicted, and the formation pressure of the well to be predicted; The crude oil volume coefficient of the well to be predicted under different formation pressure conditions is determined according to the relationship between the crude oil volume coefficient and the formation pressure of the well to be predicted.

3. The method according to claim 2, characterized in that Determining the relationship between the crude oil volume coefficient and the formation pressure of the well to be predicted under different formation pressure conditions according to the relationship between the crude oil volume coefficient and the formation pressure of the similar single well, the crude oil volume coefficient of the well to be predicted, and the formation pressure of the well to be predicted, includes: Determine the power exponent of the relationship between the crude oil volume coefficient and the formation pressure of the similar single well as the power exponent of the relationship between the crude oil volume coefficient and the formation pressure of the well to be predicted; The ratio of the crude oil volume coefficient under the original formation pressure condition to the power exponent of the crude oil volume coefficient corresponding to the formation pressure is used as the correlation coefficient of the relationship between the crude oil volume coefficient and the formation pressure of the well to be predicted; The relationship between the crude oil volume coefficient and the formation pressure of the well to be predicted under different pressure conditions is reconstructed according to the crude oil volume coefficient under the original formation pressure condition, the power index and the correlation coefficient.

4. The method according to claim 2, characterized in that: Determining the crude oil volume coefficient of the well to be predicted under different formation pressure conditions according to the relationship between the crude oil volume coefficient and formation pressure of the well to be predicted includes: Determine the formation pressure value of the well to be predicted under different formation pressure conditions; The formation pressure values ​​under the different formation pressure conditions are input into the relationship between the crude oil volume coefficient and the formation pressure of the well to be predicted, so as to obtain the crude oil volume coefficient of the well to be predicted under the different formation pressure conditions.

5. The method according to claim 1, characterized in that A crude oil volume coefficient prediction model under original formation pressure conditions is established according to the parameter sequence, including: Through the existing prediction model, the correlation analysis of each parameter in the parameter sequence of different single wells is carried out to predict the crude oil volume coefficient of different single wells; Determine the crude oil volume coefficient of different single wells through experimental tests; Compare the differences between the crude oil volume coefficients obtained from different single wells predicted by various existing prediction models and the crude oil volume coefficients determined by experimental tests; The existing prediction model with the smallest gap is determined as the crude oil volume coefficient prediction model under the original formation pressure condition.

6. The method according to claim 1, characterized in that Determining the crude oil volume coefficient under the original formation pressure condition of the well to be predicted based on the parameter sequence and the crude oil volume coefficient prediction model includes: Obtaining the original formation pressure, ground degassed crude oil density, natural gas relative density and production gas-oil ratio parameters of the well to be predicted in the parameter sequence; The original formation pressure, surface degassed crude oil density, natural gas relative density and production gas-oil ratio parameters of the well to be predicted are input into the function corresponding to the crude oil volume coefficient prediction model to determine the crude oil volume coefficient under the original formation pressure conditions of the well to be predicted.

7. The method according to claim 5, characterized in that The existing prediction model is used to perform correlation analysis on various parameters in the parameter sequences of different single wells, including: The existing prediction models include: least squares method, stepwise regression method, partial least squares regression method, Lasso method and ridge regression method.

8. A device for determining a crude oil volume coefficient, characterized in that: include: A parameter sequence acquisition module is used to obtain parameter sequences under original formation pressure conditions of different single wells based on test data; A prediction model building module, used to build a crude oil volume coefficient prediction model under original formation pressure conditions according to the parameter sequence; A crude oil volume coefficient determination module is used to determine the crude oil volume coefficient under the original formation pressure condition of the well to be predicted based on the parameter sequence and the crude oil volume coefficient prediction model; The relationship determination module constructs a relationship between the crude oil volume coefficient and the formation pressure of different single wells according to the parameter sequence, and determines the crude oil volume coefficient of the well to be predicted under different formation pressure conditions according to the relationship.

9. An electronic device, characterized in that: The electronic device comprises: at least one processor; and a memory communicatively connected to the at least one processor; wherein, The memory stores a computer program executable by the at least one processor, and the computer program is executed by the at least one processor so that the at least one processor can perform the method for determining the crude oil volume coefficient according to any one of claims 1-7.

10. A computer-readable storage medium, characterized in that: The computer-readable storage medium stores computer instructions, and the computer instructions are used to enable a processor to implement the method for determining the crude oil volume coefficient according to any one of claims 1 to 7 when executed.

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