Fault included angle angle value determination method, device, equipment, medium and product

Abstract

The application discloses a fault included angle angle value determination method, device, equipment, medium and product. The method comprises the following steps: obtaining wellhead production data and bottom hole flowing pressure data of a first oil well; normalizing the bottom hole flowing pressure data according to the wellhead production data to obtain normalized pressure data; calculating a pressure derivative curve corresponding to a pressure curve of the normalized pressure data; performing dimensionless processing on the pressure derivative curve according to characteristic parameters of an oil reservoir to obtain a dimensionless pressure derivative curve; and calculating a first fault included angle angle value of a fault area based on the dimensionless pressure derivative curve according to an unsteady seepage theory. The technical scheme of the application solves the problem that a well needs to be shut down for production to calculate a fault included angle, can convert variable production in historical data into fixed production, normalizes actual pressure of the oil well, and then calculates the fault included angle according to the normalized data, so that the well does not need to be shut down for production, the calculation accuracy is ensured, and oil well production loss is avoided.

Description

Technical Field

[0001] The embodiments of the present invention relate to the field of oil and gas reservoir development technology, and in particular to a method, apparatus, equipment, medium and product for determining fault angle values. Background Technology

[0002] Currently, according to reservoir engineering knowledge, fault angle calculations are typically based on conventional or modern well test interpretation analysis. Well test interpretation requires shutting down the well to test pressure recovery data. Based on this, well test interpretation can be performed on the downhole pressure record data from the pressure recovery process to calculate the fault angle.

[0003] It is evident that the most important prerequisite for conventional methods to calculate the fault angle is well shut-in testing, and well shut-in directly leads to a decrease in oil well production rate and production loss. Summary of the Invention

[0004] This invention provides a method, apparatus, equipment, medium, and product for determining fault angle values, which solves the current problem of needing to shut down wells and stop production to calculate fault angles. It can convert variable production rates in historical data into constant production rates, normalize the actual pressure of the oil well, and then calculate the fault angle based on the normalized data, without shutting down wells and stopping production. This ensures the accuracy of the calculation while avoiding oil well production losses.

[0005] In a first aspect, embodiments of the present invention provide a method for determining the angle value of a fault, the method comprising: Obtain wellhead production data and bottomhole flowing pressure data of the first oil well in the first time period; the first oil well is an oil well associated with the fault zone of the reservoir; The bottom hole flow pressure data is normalized based on the wellhead production data to obtain normalized pressure data. Calculate the pressure derivative curve corresponding to the pressure curve of the normalized pressure data; Based on the characteristic parameters of the reservoir, the pressure derivative curve is dimensionless to obtain the dimensionless pressure derivative curve. The first fault angle of the fault region is calculated based on the dimensionless pressure derivative curve using the unsteady flow theory.

[0006] Secondly, embodiments of the present invention also provide a device for determining the angle value of a fault, the device comprising: The data acquisition module is used to acquire the wellhead production data and bottom hole flowing pressure data of the first oil well in the first time period; the first oil well is an oil well associated with the fault zone of the oil reservoir; The pressure normalization module is used to normalize the bottom hole flow pressure data based on the wellhead production data to obtain normalized pressure data. The pressure derivative module is used to calculate the pressure derivative curve corresponding to the pressure curve of normalized pressure data. The pressure derivative dimensionless module is used to dimensionless the pressure derivative curve based on the reservoir's characteristic parameters, thus obtaining a dimensionless pressure derivative curve. The angle calculation module is used to calculate the first fault angle of the fault region based on the dimensionless pressure derivative curve according to the unsteady flow theory.

[0007] Thirdly, embodiments of the present invention also provide an electronic device, the electronic device comprising: At least one processor; and A memory communicatively connected to the at least one processor; wherein, The memory stores a computer program that can be executed by the at least one processor, which enables the at least one processor to perform the fault angle determination method according to any embodiment of the present invention.

[0008] Fourthly, embodiments of the present invention also provide a computer-readable storage medium storing computer instructions, which are used to cause a processor to execute the method for determining the fault angle value according to any embodiment of the present invention.

[0009] Fifthly, embodiments of the present invention also provide a computer program product, including a computer program that, when executed by a processor, implements the method for determining the fault angle value as described in any of the embodiments of the present invention.

[0010] In this embodiment of the invention, wellhead production data and bottomhole flowing pressure data of a first oil well in a first time period are acquired. The first oil well is associated with a fault region in the reservoir. The bottomhole flowing pressure data is normalized based on the wellhead production data to obtain normalized pressure data. The pressure derivative curve corresponding to the pressure curve of the normalized pressure data is calculated. The pressure derivative curve is dimensionless based on the reservoir's characteristic parameters to obtain a dimensionless pressure derivative curve. Based on the unsteady flow theory, the first fault angle of the fault region is calculated according to the dimensionless pressure derivative curve. The technical solution of this embodiment of the invention solves the problem that currently requires shutting down the well to calculate the fault angle. By converting the variable production rate in historical data into a constant production rate, the actual pressure of the oil well is normalized, and the fault angle is calculated based on the normalized data, without shutting down the well, thus ensuring the accuracy of the calculation and avoiding oil well production losses. Attached Figure Description

[0011] To more clearly illustrate the technical solutions of the embodiments of the present invention, the accompanying drawings used in the embodiments will be briefly introduced below. It should be understood that the following drawings only show some embodiments of the present invention and should not be regarded as a limitation on the scope. For those skilled in the art, other related drawings can be obtained based on these drawings without creative effort.

[0012] Figure 1 A flowchart illustrating a method for determining the angle of a fault according to an embodiment of the present invention; Figure 2 A flowchart illustrating another method for determining the fault angle value provided in an embodiment of the present invention; Figure 3 A schematic diagram of a software interface for determining fault angle values ​​provided in an embodiment of the present invention; Figure 4 A schematic diagram of a software interface for determining the fault angle value provided in an embodiment of the present invention; Figure 5 A schematic diagram of a software interface for determining the fault angle value provided in an embodiment of the present invention; Figure 6 This is a schematic diagram of a fault angle determination device provided in an embodiment of the present invention; Figure 7 This is a schematic diagram of the structure of an electronic device provided in an embodiment of the present invention. Detailed Implementation

[0013] The present invention will now be described in further detail with reference to the accompanying drawings and embodiments. It should be understood that the specific embodiments described herein are merely illustrative of the invention and not intended to limit it. Furthermore, it should be noted that, for ease of description, the accompanying drawings show only the parts relevant to the present invention, and not all of the structures.

[0014] It should be noted that similar reference numerals and letters in the following figures indicate similar items; therefore, once an item is defined in one figure, it does not need to be further defined and explained in subsequent figures. Furthermore, in the description of this invention, terms such as "first," "second," etc., are used only for distinguishing descriptions and should not be construed as indicating or implying relative importance. The acquisition, storage, use, and processing of data in the technical solutions of this application all comply with the relevant provisions of national laws and regulations.

[0015] It should be noted that in the embodiments of this application, certain software, components, models and other existing solutions in the industry may be mentioned. These should be regarded as exemplary and are only intended to illustrate the feasibility of implementing the technical solution of this application. However, it does not mean that the applicant has used or necessarily used the relevant content of the solution.

[0016] Figure 1 This is a flowchart illustrating a method for determining fault angle values ​​according to an embodiment of the present invention. This embodiment is applicable to scenarios involving the determination of fault angle values. The method can be executed by a fault angle value determining device, which can be implemented in software and / or hardware and integrated into an electronic device.

[0017] like Figure 1 As shown, the method for determining the fault angle includes the following steps: S110. Obtain wellhead production data and bottomhole flow pressure data of the first oil well during the first time period.

[0018] The first oil well is an oil well associated with the fault region of the reservoir. Specifically, it can be a production well that is spatially associated with the fault region of the reservoir. Its production dynamics can directly reflect the seepage characteristics of the fault region and provide data support for subsequent fault angle calculations.

[0019] The wellhead production data and bottomhole flowing pressure data of the first oil well associated with the reservoir fault region were obtained within the first historical time period. Both the wellhead production data and bottomhole flowing pressure data were acquired using a non-shutdown testing method, during which the first oil well maintained normal production conditions.

[0020] The first time period can be a continuous time interval defined according to the reservoir production monitoring needs. The interval length must meet the validity requirements of the seepage dynamic data under non-shutdown testing. It is understandable that due to various process fluctuations, well operating procedures, and operational influences, even within a short period, the actual wellhead production data obtained from the field is generally difficult to maintain stability and falls into the category of variable production data, requiring reprocessing before use. In this embodiment, the bottomhole flowing pressure data does not need to be several months or years. On the one hand, bottomhole flowing pressure fluctuations are too large and the data is unstable; on the other hand, it is sufficient that the pressure wave from the pressure drop funnel reaches the boundary, meaning the pressure drop funnel already reflects the response of the outer boundary. Therefore, the first time period can be a time interval of a preset number of days for production to meet the production stability index. The preset number of days can be 5 days or less, or up to 10 days, to meet the analysis requirements.

[0021] Wellhead production data can be the continuously monitored variable production data of crude oil production at the wellhead of the first oil well within the first time period; bottomhole flow pressure data can be the continuously monitored fluid flow pressure data at the bottom of the first oil well within the first time period, which can be obtained through wellhead pressure conversion, direct measurement by downhole pressure gauges, etc., and is the pressure data that truly reflects the formation seepage.

[0022] S120. Normalize the bottom hole flow pressure data based on the wellhead production data to obtain normalized pressure data.

[0023] The bottom hole flow pressure data can be reprocessed by taking the average production or unit production of the first time period as the constant production. Based on the constant production, the original bottom hole flow pressure data can be converted into the reconstructed normalized constant production bottom hole flow pressure data corresponding to the virtual constant production, that is, the normalized pressure data.

[0024] S130. Calculate the pressure derivative curve corresponding to the pressure curve of the normalized pressure data.

[0025] A normalized pressure curve is generated based on normalized pressure data, and the corresponding pressure derivative curve is obtained by solving the normalized pressure curve. In the process of solving the pressure derivative curve, either the forward difference method or the central difference method is selected as the numerical calculation method for the time step. Based on the selected numerical calculation method, the pressure data points on the normalized pressure curve are calculated one by one to obtain the corrected pressure derivative data corresponding to each pressure data point. The pressure derivative curve is constructed from all the corrected pressure derivative data.

[0026] In the numerical calculation methods for time steps, the forward difference method is suitable for calculating the derivative of the data points at the front end of the time series of the normalized pressure curve, while the central difference method is suitable for calculating the derivative of the data points at the middle and rear ends of the time series of the normalized pressure curve. The corrected pressure derivative data is the effective derivative data obtained after correcting the deviation of the original derivative data calculated by the difference method. The correction process eliminates the truncation error and discretization error in the numerical calculation, ensuring the smoothness and accuracy of the pressure derivative curve.

[0027] S140. Based on the characteristic parameters of the reservoir, the pressure derivative curve is dimensionless to obtain the dimensionless pressure derivative curve.

[0028] Based on the characteristic parameters of the reservoir, the pressure derivative curve is dimensionless to eliminate the influence of dimensions on the curve shape, thus obtaining a dimensionless pressure derivative curve that characterizes the seepage law of the reservoir.

[0029] The characteristic parameters of an oil reservoir may include, but are not limited to, reservoir permeability, effective formation thickness, crude oil viscosity, formation compressibility, and wellbore radius. Dimensionless processing involves normalizing the time and pressure dimensions of the pressure derivative curve with the characteristic parameters to obtain dimensionless time and pressure, and thus a dimensionless pressure derivative curve. This provides a benchmark for subsequent fault angle fitting calculations.

[0030] S150. Based on the theory of unsteady flow, the angle of the first fault in the fault region is calculated according to the dimensionless pressure derivative curve.

[0031] Based on the theory of unsteady flow and combined with the obtained dimensionless pressure derivative curves, the angle of the first fault in the reservoir fault region was calculated through theoretical fitting and comparison.

[0032] Specifically, based on geological exploration data of the fault area, fault geometric constraints, and engineering experience, a reasonable range of values ​​for the included angle of the candidate faults is defined. The candidate angle set is generated by discretization and serves as the basis for fitting.

[0033] Based on the theory of unsteady flow, a seepage equation adapted to the fault region is constructed. The corresponding outer boundary constraint conditions are determined according to each candidate angle. These conditions, combined with the fault sealing setting, limit the seepage behavior of the boundary fluid to provide the boundary conditions for the seepage equation.

[0034] Subsequently, the constraints were substituted into the seepage equation to solve for the formation pressure distribution, and the theoretical bottom-hole pressure curve was derived. After differentiation and dimensionless transformation, the theoretical pressure derivative curve was obtained. Finally, the theoretical curve was fitted and compared with the actual dimensionless pressure derivative curve, and the candidate angle with the highest matching degree was selected, which is the first fault angle value.

[0035] This embodiment is based on the classical seepage theory of porous media reservoirs. First, the variable production rate is converted into a constant production rate. Then, the dynamic data of actual oil well production is normalized and reconstructed into a full pressure history. Next, the normalized pressure data is differentiated into a full pressure history. Finally, a dimensionless transformation is introduced to quickly obtain the fault angle. The entire process is completed automatically, eliminating the influence of human subjective consciousness and improving the accuracy, scientificity and efficiency of information analysis.

[0036] The technical solution of this embodiment involves acquiring wellhead production data and bottomhole flowing pressure data of a first oil well during a first time period. The first oil well is associated with a fault zone in the reservoir. The bottomhole flowing pressure data is normalized based on the wellhead production data to obtain normalized pressure data. The pressure derivative curve corresponding to the pressure curve of the normalized pressure data is calculated. The pressure derivative curve is dimensionless based on the reservoir's characteristic parameters to obtain a dimensionless pressure derivative curve. The first fault angle of the fault zone is calculated based on the dimensionless pressure derivative curve using the unsteady flow theory. This embodiment solves the problem of needing to shut down the well to calculate the fault angle. It converts variable production data in historical data into constant production data, normalizes the actual well pressure, and then calculates the fault angle based on the normalized data, eliminating the need for well shutdown and ensuring calculation accuracy while avoiding well production losses.

[0037] Figure 2 This is a flowchart illustrating a method for determining fault angle values ​​according to an embodiment of the present invention. This embodiment belongs to the same inventive concept as the fault angle value determination method described in the above embodiments, and further describes the angle value calculation process. This method can be executed by a fault angle value determination device, which can be implemented in software and / or hardware and integrated into an electronic device with application development capabilities.

[0038] like Figure 2As shown, the method for determining the fault angle value in this embodiment includes the following steps: S210. Obtain wellhead production data and bottomhole flow pressure data of the first oil well during the first time period.

[0039] The first oil well is associated with a fault zone in the reservoir.

[0040] S220. Calculate the pressure difference between the first bottom hole flow pressure and the second bottom hole flow pressure at the first time point in the first time period.

[0041] The first time point is any time point in the first period, and the second bottom hole flow pressure is the bottom hole flow pressure of the first oil well when the reservoir is in an unexploited state, which is also the initial reservoir pressure.

[0042] S230. Calculate the ratio of the pressure difference to the first wellhead production at the first time point to obtain the first normalized pressure data at the first time point.

[0043] The first normalized pressure data for each first time point can be calculated using the following formula, with unit output as the fixed output.

[0044] ; In the above formula, This represents the reconstructed constant production pressure, which is also the first normalized pressure at time point n, in MPa. Initial reservoir pressure, in MPa; The bottom-hole flow pressure at the nth time point, in MPa; The first wellhead production rate at the nth time point, in meters. 3 / d.

[0045] S240. Calculate the pressure derivative curve corresponding to the pressure curve of the normalized pressure data.

[0046] Based on step S230, the first normalized pressure data corresponding to the normalized constant output is reconstructed. The time step adopts the forward difference or central difference method to calculate the corrected pressure derivative data at each time point, and obtains the pressure derivative curve corresponding to the pressure curve of the normalized pressure data.

[0047] The calculation process for correcting the pressure derivative data is as follows: ; In the above formula This represents the bottom hole pressure derivative, in MPa / h. , , These represent the bottom hole flow pressures at time points n-1, n, and n+1, respectively, in MPa. , , Δt represents the time corresponding to the (n-1), n, and n+1th time points, respectively, in hours (h); Δt represents the time step, in hours (h).

[0048] S250. Based on the characteristic parameters of the reservoir, the pressure derivative curve is dimensionless to obtain the dimensionless pressure derivative curve.

[0049] Based on the reservoir's characteristic parameters, the time and pressure of the pressure derivative curves are dimensionless to obtain dimensionless time and dimensionless pressure, and thus the dimensionless pressure derivative curves are obtained.

[0050] In one optional embodiment, based on the reservoir's characteristic parameters, the pressure and time of the pressure derivative curve are dimensionless to obtain dimensionless pressure and dimensionless time; the logarithm of the dimensionless time is calculated, and the logarithmic derivative of the dimensionless pressure is calculated using the numerical difference method to obtain the dimensionless pressure derivative curve; wherein, the vertical axis of the dimensionless pressure derivative curve is the logarithmic derivative of the dimensionless pressure, and the horizontal axis of the dimensionless pressure derivative curve is the logarithm of the dimensionless time.

[0051] Based on the characteristic parameters of the reservoir, the pressure and time parameters in the obtained pressure derivative curves are dimensionless. The dimensionless pressure and dimensionless time are obtained by eliminating the influence of dimensions through normalization.

[0052] Logarithmic operations are performed on the obtained dimensionless time to obtain the logarithm of the dimensionless time. Simultaneously, the numerical difference method is used to differentiate the dimensionless pressure to obtain the logarithmic derivative of the dimensionless pressure. Finally, a dimensionless pressure derivative curve is constructed with the logarithm of the dimensionless time as the horizontal axis and the logarithmic derivative of the dimensionless pressure as the vertical axis.

[0053] In one alternative implementation, the characteristic parameters include at least one of reservoir thickness, porosity, formation crude oil viscosity, and overall compressibility.

[0054] Specifically, characteristic parameters may include reservoir parameters such as reservoir thickness, permeability, porosity, formation crude oil viscosity, crude oil volume factor, comprehensive compressibility factor, and well radius.

[0055] S260. Determine the candidate fault angle value according to the preset fault angle value range and the preset step size.

[0056] The preset range of fault angle values ​​can be a range of possible fault angle values ​​defined in advance based on the geological characteristics of the reservoir fault, engineering experience, and geometric constraints, such as 0 degrees to 90 degrees.

[0057] The preset step size can be a fixed interval, such as 1 degree. The step size is determined by the calculation accuracy and efficiency requirements. If the accuracy requirement is high, the step size should be small, and if the efficiency requirement is high, the step size can be appropriately increased.

[0058] Based on a preset range, starting from the initial value of the range, values ​​are taken sequentially according to a preset step size until the entire preset range is covered. All the extracted discrete angle values ​​together constitute a set of candidate fault angle values.

[0059] S270. Substitute the angle value of the candidate fault into the seepage equation constructed based on the unsteady seepage theory to obtain the theoretical pressure derivative curve corresponding to the angle value of the candidate fault.

[0060] ; In the above formula: p, These represent formation pressure and initial static pressure, respectively, in MPa; q represents production rate, in MPa. ; K represents the viscosity of the formation crude oil, in mPas; K represents the permeability, in mPas. (millidarcy); B is the volume factor, which is dimensionless; h is the thickness, in meters; t is the time, in hours; r is the distance from the well, which is the radial distance between any calculation point in the formation and the center of the wellbore, in meters; The radius of the well is in meters. The pressure conductivity coefficient is expressed in units of 1000 kJ / m². The above equation can be solved numerically or analytically using the principle of superposition of potentials.

[0061] In one optional implementation, the candidate fault angle value is substituted into the seepage equation constructed based on the unsteady flow theory to obtain the theoretical pressure derivative curve corresponding to the candidate fault angle value. This can be achieved by determining the outer boundary constraint conditions corresponding to the candidate fault angle value; substituting the outer boundary constraint conditions into the seepage equation constructed based on the unsteady flow theory to obtain the formation pressure distribution; determining the theoretical bottom-hole pressure curve based on the formation pressure distribution; solving the theoretical bottom-hole pressure derivative curve of the theoretical bottom-hole pressure curve; and dimensionlessly transforming the theoretical bottom-hole pressure derivative curve to obtain the theoretical pressure derivative curve.

[0062] The default external boundary conditions for the seepage equation are: , representing the constant pressure at the infinite boundary, but when there are faults in the actual oil reservoir, the faults will form a finite, angled outer boundary.

[0063] The angle of the candidate fault directly determines the geometry of the seepage zone. Combined with the fault sealing property, the default infinite boundary is replaced with an angled closed outer boundary to obtain the outer boundary constraint conditions corresponding to the angle of the candidate fault.

[0064] The new outer boundary constraints are combined with the existing initial conditions of the seepage equation. Internal boundary conditions Together, these conditions are substituted into the seepage equation, which is also the governing equation for radially unsteady seepage: .

[0065] By using the principle of superposition of potentials for numerical or analytical solutions, the formation pressure distribution p(r,t) at any location and time in the formation under the included angle of the candidate fault can be obtained.

[0066] Extract the bottom hole location from the formation pressure distribution p(r,t). By analyzing the relationship between pressure and time, the theoretical bottom-hole pressure curve is obtained. The theoretical bottom-hole pressure derivative curve is then obtained by numerically differentiating the theoretical bottom-hole pressure curve.

[0067] Based on reservoir characteristic parameters, the pressure and time of the theoretical bottom hole pressure derivative curve are dimensionless to eliminate the influence of dimensions, and finally the theoretical pressure derivative curve corresponding to the angle value of the candidate fault is obtained.

[0068] S280. Fit and compare the dimensionless pressure derivative curve and the theoretical pressure derivative curve to obtain the first fault angle value. The first fault angle value is the candidate fault angle value that makes the dimensionless pressure derivative curve and the theoretical pressure derivative curve match the most.

[0069] The dimensionless pressure derivative curves obtained by processing the actual reservoir wellhead production and bottom hole flowing pressure are fitted and compared one by one with the theoretical pressure derivative curves corresponding to the angle values ​​of each candidate fault. By quantitatively calculating the morphological matching degree of the two curves, such as the mean square error and correlation coefficient, the candidate fault angle value that makes the matching degree of the two curves the highest is selected. This angle value is the first fault angle value, which can accurately reflect the actual geometric characteristics of the reservoir fault area.

[0070] The technical solution of this embodiment involves acquiring wellhead production data and bottomhole flowing pressure data of a first oil well during a first time period; the first oil well is an oil well associated with a fault zone in the reservoir; calculating the pressure difference between the first bottomhole flowing pressure and the second bottomhole flowing pressure at a first time point in the first time period; the first time point can be any time point in the first time period, and the second bottomhole flowing pressure is the bottomhole flowing pressure of the first oil well when the reservoir is in an unexploited state; calculating the ratio of the pressure difference to the first wellhead production at the first time point to obtain the first normalized pressure data at the first time point; calculating the pressure derivative curve corresponding to the pressure curve of the normalized pressure data; and dimensionlessly transforming the pressure derivative curve according to the characteristic parameters of the reservoir to obtain the dimensionless pressure derivative curve. Candidate fault angles are determined according to a preset range of fault angle values ​​and a preset step size. These candidate fault angles are then substituted into a seepage equation constructed based on unsteady flow theory to obtain a theoretical pressure derivative curve corresponding to the candidate fault angle. The dimensionless pressure derivative curve and the theoretical pressure derivative curve are fitted and compared to obtain a first fault angle value. This first fault angle value is the candidate fault angle value that achieves the highest matching degree between the dimensionless pressure derivative curve and the theoretical pressure derivative curve. This invention solves the problem of currently requiring well shut-in and production shutdown to calculate fault angles. By substituting candidate fault angles into the seepage equation to generate a corresponding theoretical pressure derivative curve, and then fitting and comparing it with the actual dimensionless curve, the angle with the highest matching degree can be selected. This allows for precise quantification of fault geometric characteristics, providing a reliable technical basis for reservoir seepage law analysis, development scheme optimization, and remaining oil potential tapping.

[0071] In a specific example of determining the fault angle, the interface of the software system for determining the fault angle is as follows: Figure 3 , Figure 4 and Figure 5 As shown.

[0072] Figure 3 This is the interface for displaying the bottom-hole flow pressure curve after data import. For example... Figure 3 As shown, determining the fault angle includes steps 1-5: Step 1: Prepare the wellhead production corresponding to the long-term production of the target oil well, which is variable production data, the bottom hole flow pressure continuously changing over time data, and other reservoir-related parameters, such as oil layer thickness and formation crude oil viscosity.

[0073] Step 2: Construct wellbore flow pressure data for fixed production or unit production, and perform standardized calculations.

[0074] Step 3: Based on the normalized reconstructed bottom hole flow pressure historical data, calculate the pressure derivative for the entire pressure history period.

[0075] Step 4: Combine reservoir characteristic parameters to make the pressure derivative calculated in step 3 dimensionless.

[0076] Step 5 is to calculate the fault angle based on the theory of unsteady flow.

[0077] In step 1, collect continuous historical data on wellhead production and bottomhole flowing pressure of the target oil well over time (in the format of time-wellhead production-bottomhole flowing pressure), as well as reservoir parameters such as oil layer thickness, permeability, porosity, formation crude oil viscosity, crude oil volume factor, comprehensive compressibility factor, and well radius.

[0078] Click the first button on the left, "Import Production Dynamics Data (TQP)," to read and import reservoir basic parameters and historical data on wellhead production and bottomhole flowing pressure over time, displaying data such as... Figure 3 The curve showing the relationship between time and bottom hole flowing pressure is shown.

[0079] Before plotting the relationship between time and bottom hole pressure, a genetic algorithm can be used to automatically and intelligently search and judge the original input data one by one. If obvious anomalies are found, such as sudden sharp jumps in stable and continuously changing data, the genetic algorithm will automatically judge and remove them to ensure that the data quality meets the requirements and provides a good foundation for subsequent research.

[0080] In step 2, the unit production rate is selected as the constant production rate, and the original bottomhole flowing pressure data is converted into reconstructed normalized constant production rate bottomhole flowing pressure data corresponding to the virtual constant production rate. In the software, clicking the second button from the left, "Reconstruct Normalized Constant Production Rate Bottomhole Flow Pressure Data," will automatically complete the calculation and data plotting.

[0081] In step 3, based on the normalized constant production rate data reconstructed in step 2, the time step uses forward difference or central difference methods to calculate the corrected pressure derivative data for each pressure point.

[0082] Clicking the third button from the left, "Calculate Reconstructed Normalized Corrected Pressure Derivative," will automatically complete the calculation and data visualization, as shown below. Figure 4 The reconstructed normalized corrected pressure derivative curve is shown.

[0083] In step 4, clicking the fourth button on the left, "Pressure Derivative Dimensionless Reprocessing," will automatically complete the calculation and data plotting. Figure 5 The graph shows the dimensionless processing of the corrected pressure derivative.

[0084] In step 5, the fault angle can be calculated with a single click based on the unsteady flow theory, such as... Figure 5 Click the fifth button to calculate the fault angle value.

[0085] Figure 6 This is a schematic diagram of the fault angle determination device provided in an embodiment of the present invention. This embodiment is applicable to scenarios involving the determination of fault angle values. The device can be implemented in software and / or hardware and integrated into an electronic device.

[0086] like Figure 6 As shown, the fault angle determination device includes: a data acquisition module 310, a pressure normalization module 320, a pressure derivative module 330, a pressure derivative dimensionless conversion module 340, and an angle calculation module 350.

[0087] The data acquisition module 310 is used to acquire the wellhead production data and bottom hole flowing pressure data of the first oil well in the first time period; the first oil well is an oil well associated with the fault region of the reservoir; the pressure normalization module 320 is used to normalize the bottom hole flowing pressure data according to the wellhead production data to obtain normalized pressure data; the pressure derivative module 330 is used to calculate the pressure derivative curve corresponding to the pressure curve of the normalized pressure data; the pressure derivative dimensionless module 340 is used to dimensionless the pressure derivative curve according to the characteristic parameters of the reservoir to obtain the dimensionless pressure derivative curve; and the angle calculation module 350 is used to calculate the first fault angle value of the fault region based on the dimensionless pressure derivative curve according to the unsteady flow theory.

[0088] The technical solution of this invention involves acquiring wellhead production data and bottomhole flowing pressure data of a first oil well during a first time period. The first oil well is associated with a fault zone in the reservoir. The bottomhole flowing pressure data is normalized based on the wellhead production data to obtain normalized pressure data. The pressure derivative curve corresponding to the pressure curve of the normalized pressure data is calculated. The pressure derivative curve is dimensionlessly transformed based on the reservoir's characteristic parameters to obtain a dimensionless pressure derivative curve. The first fault angle of the fault zone is calculated based on the dimensionless pressure derivative curve using the unsteady flow theory. This invention solves the problem of currently requiring well shutdown to calculate the fault angle. It converts variable production data in historical data into constant production data, normalizes the actual well pressure, and then calculates the fault angle based on the normalized data, eliminating the need for well shutdown and ensuring calculation accuracy while avoiding well production losses.

[0089] In one alternative implementation, the pressure normalization module 320 is specifically used for: Calculate the pressure difference between the first bottom-hole flowing pressure and the second bottom-hole flowing pressure at the first time point in the first time period. The first time point is any time point in the first time period, and the second bottom-hole flowing pressure is the bottom-hole flowing pressure of the first oil well when the reservoir is in an unexploited state. Calculate the ratio of the pressure difference to the first wellhead production at the first time point to obtain the first normalized pressure data at the first time point.

[0090] In one alternative implementation, the angle value calculation module 350 is specifically used for: Candidate fault angle values ​​are determined according to a preset range of fault angle values ​​and a preset step size. The candidate fault angle values ​​are substituted into the seepage equation constructed based on the unsteady seepage theory to obtain the theoretical pressure derivative curve corresponding to the candidate fault angle values. The dimensionless pressure derivative curve and the theoretical pressure derivative curve are fitted and compared to obtain the first fault angle value. The first fault angle value is the candidate fault angle value that makes the dimensionless pressure derivative curve and the theoretical pressure derivative curve have the highest matching degree.

[0091] In an optional implementation, the angle value calculation module 350 is further configured to: The outer boundary constraints corresponding to the included angle values ​​of the candidate faults are determined. The outer boundary constraints are substituted into the seepage equation constructed based on the unsteady seepage theory to obtain the formation pressure distribution. The theoretical bottom-hole pressure curve is determined based on the formation pressure distribution, and the theoretical bottom-hole pressure derivative curve is solved. The theoretical bottom-hole pressure derivative curve is dimensionless to obtain the theoretical pressure derivative curve.

[0092] In one alternative implementation, the pressure derivative dimensionless module 340 is specifically used for: Based on the reservoir's characteristic parameters, the pressure and time of the pressure derivative curves are dimensionless to obtain dimensionless pressure and dimensionless time. The logarithm of the dimensionless time is calculated, and the logarithmic derivative of the dimensionless pressure is calculated using the numerical difference method to obtain the dimensionless pressure derivative curve. The vertical axis of the dimensionless pressure derivative curve represents the logarithmic derivative of the dimensionless pressure, and the horizontal axis represents the logarithm of the dimensionless time.

[0093] In one alternative implementation, the characteristic parameters include at least one of reservoir thickness, porosity, formation crude oil viscosity, and overall compressibility.

[0094] The fault angle determination device provided in this embodiment of the invention can execute the fault angle determination method provided in any embodiment of the invention, and has the corresponding functional modules and beneficial effects of the method.

[0095] Figure 7A schematic diagram of an electronic device 10, which can be used to implement embodiments 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 processors, cellular phones, smartphones, wearable devices (e.g., helmets, glasses, watches, etc.), and other similar computing devices. The components shown herein, their connections and relationships, and their functions are merely illustrative and are not intended to limit the implementation of the invention described and / or claimed herein.

[0096] like Figure 7 As shown, the electronic device 10 includes at least one processor 11 and a memory, such as a read-only memory (ROM) 12 or a random access memory (RAM) 13, communicatively connected to the at least one processor 11. The memory stores computer programs executable by the at least one processor. The processor 11 can perform various appropriate actions and processes based on the computer program stored in the ROM 12 or loaded from storage unit 18 into the RAM 13. The RAM 13 can also store various programs and data required for the operation of the electronic device 10. The processor 11, ROM 12, and RAM 13 are interconnected via a bus 14. An input / output (I / O) interface 15 is also connected to the bus 14.

[0097] Multiple components in electronic device 10 are connected to I / O interface 15, including: input unit 16, such as keyboard, mouse, etc.; output unit 17, such as various types of displays, speakers, etc.; storage unit 18, such as disk, optical disk, etc.; and communication unit 19, such as network card, modem, wireless transceiver, etc. Communication unit 19 allows electronic device 10 to exchange information / data with other devices through computer networks such as the Internet and / or various telecommunications networks.

[0098] Processor 11 can be a variety of general-purpose and / or special-purpose processing components with processing and computing capabilities. Some examples of processor 11 include, but are not limited to, a central processing unit (CPU), a graphics processing unit (GPU), various special-purpose artificial intelligence (AI) computing chips, various processors running machine learning model algorithms, a digital signal processor (DSP), and any suitable processor, controller, microcontroller, etc. Processor 11 performs the various methods and processes described above, such as the method for determining the fault angle value.

[0099] In some embodiments, the method for determining the fault angle value can be implemented as a computer program tangibly contained in a computer-readable storage medium, such as storage unit 18. In some embodiments, part or all of the computer program can be loaded and / or installed on electronic device 10 via ROM 12 and / or communication unit 19. When the computer program is loaded into RAM 13 and executed by processor 11, one or more steps of the method for determining the fault angle value described above can be performed. Alternatively, in other embodiments, processor 11 can be configured to perform the method for determining the fault angle value by any other suitable means (e.g., by means of firmware).

[0100] Various embodiments 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), system-on-a-chip (SoCs), complex programmable logic devices (CPLDs), computer hardware, firmware, software, and / or combinations thereof. These various embodiments may include implementations in one or more computer programs that can be executed and / or interpreted on a programmable system including at least one programmable processor, which may be a dedicated or general-purpose programmable processor, capable of receiving data and instructions from a storage system, at least one input device, and at least one output device, and transmitting data and instructions to the storage system, the at least one input device, and the at least one output device.

[0101] Computer programs used to implement 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, such that when executed by the processor, the computer programs cause the functions / operations specified in the flowcharts and / or block diagrams to be performed. The computer programs may be executed entirely on a machine, partially on a machine, or as a standalone software package, partially on a machine and partially on a remote machine, or entirely on a remote machine or server.

[0102] In the context of this invention, a computer-readable storage medium can be a tangible medium that may contain or store a computer program for use by or in conjunction with an instruction execution system, apparatus, or device. A computer-readable storage medium may include, but is not limited to, electronic, magnetic, optical, electromagnetic, infrared, or semiconductor systems, apparatus, or devices, or any suitable combination thereof. Alternatively, a computer-readable storage medium may be a machine-readable signal medium. More specific examples of machine-readable storage media include electrical connections based on one or more wires, portable computer disks, hard disks, random access memory (RAM), read-only memory (ROM), erasable programmable read-only memory (EPROM or flash memory), optical fibers, portable compact disk read-only memory (CD-ROM), optical storage devices, magnetic storage devices, or any suitable combination thereof.

[0103] To provide interaction with a user, the systems and techniques described herein can 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 pointing device (e.g., a mouse or trackball) through which the user provides input to the electronic device. Other types of devices can also be used to provide interaction with the user; for example, feedback provided to the user can be any form of sensory feedback (e.g., visual feedback, auditory feedback, or tactile feedback); and input from the user can be received in any form (including sound input, voice input, or tactile input).

[0104] The systems and technologies described herein can be implemented in computing systems that include backend components (e.g., as data servers), or computing systems that include middleware components (e.g., application servers), or computing systems that include frontend components (e.g., user computers with graphical user interfaces or web browsers through which users can interact with implementations of the systems and technologies described herein), or any combination of such backend, middleware, or frontend components. The components of the system can be interconnected via digital data communication of any form or medium (e.g., communication networks). Examples of communication networks include local area networks (LANs), wide area networks (WANs), blockchain networks, and the Internet.

[0105] A computing system can include clients and servers. Clients and servers are generally located far apart and typically interact through communication networks. The client-server relationship is created by computer programs running on the respective computers and having a client-server relationship with each other. The server can be a cloud server, also known as a cloud computing server or cloud host, which is a hosting product within the cloud computing service system to address the shortcomings of traditional physical hosts and VPS services, such as high management difficulty and weak business scalability.

[0106] It should be understood that the various forms of processes shown above can be used, with steps reordered, added, or deleted. For example, the steps described in this invention can be executed in parallel, sequentially, or in different orders, as long as the desired result of the technical solution of this invention can be achieved, and this is not limited herein.

[0107] This invention also provides a computer program product, including a computer program that, when executed by a processor, implements the method for determining the fault angle value as provided in any embodiment of this application.

[0108] In implementing the computer program product, computer program code for performing the operations of this invention can be written in one or more programming languages ​​or a combination thereof. Programming languages ​​include object-oriented programming languages ​​such as Java, Smalltalk, and C++, as well as conventional procedural programming languages ​​such as C or similar languages. The program code can be executed entirely on the user's computer, partially on the user's computer, as a standalone software package, partially on the user's computer and partially on a remote computer, or entirely on a remote computer or server. In cases involving remote computers, the remote computer can be connected to the user's computer via any type of network—including a local area network (LAN) or a wide area network (WAN)—or can be connected to an external computer (e.g., via the Internet using an Internet service provider).

[0109] It should be understood that the various forms of processes shown above can be used, with steps reordered, added, or deleted. For example, the steps described in this invention can be executed in parallel, sequentially, or in different orders, as long as the desired result of the technical solution of this invention can be achieved, and this is not limited herein.

[0110] The specific embodiments described above do not constitute a limitation on the scope of protection of this invention. Those skilled in the art should understand that various modifications, combinations, sub-combinations, and substitutions can be made according to design requirements and other factors. Any modifications, equivalent substitutions, and improvements made within the spirit and principles of this invention should be included within the scope of protection of this invention.

Claims

1. A method for determining the angle value of a fault, characterized in that, include: Obtain wellhead production data and bottomhole flow pressure data of the first oil well in the first time period; The first oil well is an oil well associated with a fault zone in the reservoir; The wellbore flow pressure data is normalized based on the wellhead production data to obtain normalized pressure data. Calculate the pressure derivative curve corresponding to the pressure curve of the normalized pressure data; Based on the characteristic parameters of the reservoir, the pressure derivative curve is dimensionless to obtain a dimensionless pressure derivative curve. Based on the unsteady flow theory, the first fault angle value of the fault region is calculated according to the dimensionless pressure derivative curve.

2. The method according to claim 1, characterized in that, The step of normalizing the bottom hole flow pressure data based on the wellhead production data to obtain normalized pressure data includes: Calculate the pressure difference between the first bottom-hole flowing pressure and the second bottom-hole flowing pressure at the first time point in the first time period. The first time point is any time point in the first time period, and the second bottom-hole flowing pressure is the bottom-hole flowing pressure of the first oil well when the oil reservoir is in an unexploited state. The ratio of the pressure difference to the first wellhead production at the first time point is calculated to obtain the first normalized pressure data at the first time point.

3. The method according to claim 1, characterized in that, The calculation of the first fault angle value of the fault region based on the dimensionless pressure derivative curve according to the unsteady flow theory includes: The candidate fault angle values ​​are determined according to the preset fault angle range and the preset step size. Substituting the angle value of the candidate fault into the seepage equation constructed based on the theory of unsteady seepage, the theoretical pressure derivative curve corresponding to the angle value of the candidate fault is obtained. The dimensionless pressure derivative curve and the theoretical pressure derivative curve are fitted and compared to obtain the first fault angle value. The first fault angle value is the candidate fault angle value that makes the dimensionless pressure derivative curve and the theoretical pressure derivative curve have the highest matching degree.

4. The method according to claim 3, characterized in that, The step of substituting the angle value of the candidate fault into the seepage equation constructed based on the unsteady seepage theory to obtain the theoretical pressure derivative curve corresponding to the angle value of the candidate fault includes: Determine the outer boundary constraint conditions corresponding to the included angle values ​​of the candidate faults; Substituting the aforementioned outer boundary constraints into the seepage equation constructed based on the unsteady seepage theory, the formation pressure distribution is obtained; The theoretical bottom hole pressure curve is determined based on the formation pressure distribution, and the theoretical bottom hole pressure derivative curve is solved. The theoretical bottom hole pressure derivative curve is then dimensionless to obtain the theoretical pressure derivative curve.

5. The method according to claim 1, characterized in that, The step of dimensionlessly transforming the pressure derivative curve based on the reservoir's characteristic parameters to obtain a dimensionless pressure derivative curve includes: Based on the characteristic parameters of the reservoir, the pressure and time of the pressure derivative curves are dimensionless to obtain dimensionless pressure and dimensionless time. Calculate the logarithm of the dimensionless time and use the numerical difference method to calculate the logarithmic derivative of the dimensionless pressure to obtain the dimensionless pressure derivative curve. Wherein, the vertical axis of the dimensionless pressure derivative curve is the logarithmic derivative of the dimensionless pressure, and the horizontal axis of the dimensionless pressure derivative curve is the logarithm of the dimensionless time.

6. The method according to claim 1, characterized in that, The characteristic parameters include at least one of the following: oil layer thickness, porosity, formation crude oil viscosity, and overall compressibility.

7. A device for determining the angle value of a fault, characterized in that, include: The data acquisition module is used to acquire the wellhead production data and bottom hole flow pressure data of the first oil well in the first time period; The first oil well is an oil well associated with a fault zone in the reservoir; The pressure normalization module is used to normalize the bottom hole flow pressure data based on the wellhead production data to obtain normalized pressure data. The pressure derivative module is used to calculate the pressure derivative curve corresponding to the pressure curve of normalized pressure data. The pressure derivative dimensionless transformation module is used to dimensionless the pressure derivative curve based on the characteristic parameters of the reservoir, so as to obtain a dimensionless pressure derivative curve. The angle calculation module is used to calculate the first fault angle of the fault region based on the dimensionless pressure derivative curve according to the unsteady flow theory.

8. An electronic device, characterized in that, The method includes 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, the computer program being executed by the at least one processor to enable the at least one processor to perform the method for determining the fault angle value according to any one of claims 1-6.

9. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores computer instructions that cause a processor to execute the method for determining the fault angle value as described in any one of claims 1-6.

10. A computer program product, comprising a computer program, characterized in that, When the computer program is executed by the processor, it implements the method for determining the fault angle value as described in any one of claims 1-6.

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