Acoustic Logging Calibration Method, Device, Equipment, Storage Medium and Program Product

Abstract

The present invention provides a method, device, equipment, storage medium and program product for sonic logging correction. The method includes: obtaining the vertical seismic profile logging velocity curve and the sonic velocity curve of multiple measured wells in a target area. For each measured well, performing a fitting operation according to the vertical seismic profile logging velocity curve and the sonic velocity curve of the measured well to obtain the fitting parameters corresponding to the measured well. According to the fitting parameters corresponding to multiple measured wells, obtain the fitting parameters of the vertical seismic profile logging velocity curve and the sonic velocity curve in the target area. According to the fitting parameters corresponding to the target area, correct the sonic velocity curves of other wells in the target area except for the multiple measured wells, realizing a quantitative description of sonic logging correction, making up for the limitations of existing correction technologies to a certain extent, greatly improving the calibration accuracy and reliability of sonic logging, improving the correction efficiency, and reducing the exploration cost.

Description

Technical Field

[0001] The present invention relates to the technical field of oil exploration, and in particular, to a method, device, equipment, storage medium and program product for acoustic logging correction. Background Art

[0002] Currently, in the field of oil and gas exploration, affected by both the instrument itself and the complex underground geological conditions, during the logging process of open-hole wells, there is often a certain error between the measured value and the true value of the acoustic travel time, which affects the synthetic seismogram based on acoustic logging and its subsequent well-seismic calibration work to varying degrees, and may lead to some incorrect conclusions.

[0003] The existing correction method is the borehole compensation method, which mainly corrects the measurement error caused by borehole collapse. This method has certain limitations, and the efficiency and accuracy of acoustic logging correction still need to be improved. Summary of the Invention

[0004] The present invention provides a method, device, equipment, storage medium and program product for acoustic logging correction to solve some limitations of the existing correction technology and improve the accuracy of acoustic logging correction.

[0005] In a first aspect, the present invention provides a method for acoustic logging correction, the method comprising:

[0006] Obtaining the vertical seismic profile logging velocity curve and the acoustic velocity curve of multiple measured wells in a target area;

[0007] For each measured well, performing a fitting operation according to the vertical seismic profile logging velocity curve and the acoustic velocity curve of the measured well to obtain the fitting parameters corresponding to the measured well;

[0008] According to the fitting parameters corresponding to multiple measured wells, obtaining the fitting parameters of the vertical seismic profile logging velocity curve and the acoustic velocity curve of the target area;

[0009] According to the fitting parameters corresponding to the target area, correcting the acoustic velocity curve of other wells in the target area except the multiple measured wells.

[0010] Optionally, performing a fitting operation according to the vertical seismic profile logging velocity curve and the acoustic velocity curve of the measured well to obtain the fitting parameters corresponding to the measured well, including:

[0011] Establishing a regression function between the vertical seismic profile logging velocity curve and the acoustic velocity curve, the regression function including fitting parameters;

[0012] Select a plurality of points on the vertical seismic profile logging velocity curve and the acoustic velocity curve of the well to be measured respectively, and perform a fitting operation according to the velocity values corresponding to the selected points, and assign fitting parameters corresponding to the well to be measured.

[0013] Optionally, the regression function is

[0014]

[0015] The convergence condition of the fitting operation is Take the minimum value;

[0016] Wherein, represents the regression function corresponding to the well to be measured, a0, a1, …, a n represents the fitting parameters of the well to be measured, x i represents the velocity value corresponding to the i-th point on the acoustic velocity curve, y i represents the velocity value corresponding to the i-th point on the measured vertical seismic profile logging velocity curve, represents the calculated value of the fitting formula, ξ represents the single-well error value, n represents a positive integer greater than or equal to 2, and p represents the number of selected points.

[0017] Optionally, according to the fitting parameters corresponding to multiple wells to be measured, obtain the fitting parameters of the vertical seismic profile logging velocity curve and the acoustic velocity curve of the target area, including:

[0018] Substitute the fitting parameters corresponding to the multiple wells to be measured into the following formula:

[0019]

[0020] Wherein, δ l represents the overall error of m wells to be measured under the l-th set of fitting parameters, represents the single-well error calculated for the j-th well to be measured under the l-th set of fitting parameters, ξ j represents the minimum single-well error of the j-th well to be measured to obtain the best fitting parameters, and m represents the number of wells to be measured;

[0021] According to the convergence condition, select the fitting parameters corresponding to the target area from the fitting parameters corresponding to the multiple wells to be measured;

[0022] Wherein, the convergence condition is that δ l takes the minimum value.

[0023] Optionally, for each well to be measured, perform a fitting operation according to the vertical seismic profile logging velocity curve and the acoustic velocity curve of the well to be measured to obtain the fitting parameters corresponding to the well to be measured, including:

[0024] Establish an interactive graph of the vertical seismic profile logging velocity curve and the acoustic velocity curve of the target area. The horizontal axis of the interactive graph is the acoustic logging velocity, and the vertical axis is the vertical seismic profile logging velocity. The position of the interactive points in the interactive graph is determined by the vertical seismic profile logging velocity curves and the acoustic velocity curves of multiple wells to be measured;

[0025] According to the positions of the respective interactive points in the interactive graph, determine whether the concentration degree of the respective interactive points meets a preset condition;

[0026] If it is satisfied, for each well to be measured, perform a fitting operation according to the vertical seismic profile logging velocity curve and the acoustic velocity curve of the well to be measured, and obtain the fitting parameters corresponding to the well to be measured.

[0027] Optionally, correcting the acoustic velocity curves of other wells in the target area except the multiple wells to be measured includes:

[0028] Obtain the acoustic velocity curve of the well to be analyzed in the target area;

[0029] According to the acoustic velocity curve of the well to be analyzed and the fitting parameters corresponding to the target area, determine the quasi-vertical seismic profile logging velocity curve corresponding to the well to be analyzed;

[0030] Perform well-seismic calibration on the well to be analyzed according to the determined quasi-vertical seismic profile logging velocity curve.

[0031] In a second aspect, the present invention provides an acoustic logging correction device, including:

[0032] An acquisition module, configured to acquire the vertical seismic profile logging velocity curves and the acoustic velocity curves of multiple wells to be measured in a target area;

[0033] A first obtaining module, configured to perform a fitting operation on each well to be measured according to the vertical seismic profile logging velocity curve and the acoustic velocity curve of the well to be measured, and obtain the fitting parameters corresponding to the well to be measured;

[0034] A second obtaining module, configured to obtain the fitting parameters of the vertical seismic profile logging velocity curve and the acoustic velocity curve of the target area according to the fitting parameters corresponding to multiple wells to be measured;

[0035] A correction module, configured to correct the acoustic velocity curves of other wells in the target area except the multiple wells to be measured according to the fitting parameters corresponding to the target area.

[0036] In a third aspect, the present invention provides an acoustic logging correction device, including:

[0037] At least one processor and a memory;

[0038] The memory stores computer-executable instructions;

[0039] The at least one processor executes the computer-executable instructions stored in the memory, such that the at least one processor executes the acoustic logging correction method according to any one of the first aspect.

[0040] In a fourth aspect, the present invention provides a computer-readable storage medium, in which computer-executable instructions are stored, and when the computer-executable instructions are executed by a processor, they are used to implement the acoustic logging correction method according to any one of the first aspect.

[0041] In a fifth aspect, the present invention provides a computer program product, including a computer program, and when the computer program is executed by a processor, it implements the acoustic logging correction method according to any one of the first aspect.

[0042] The present invention provides an acoustic logging correction method, device, equipment, storage medium and program product. The method includes: by obtaining the vertical seismic profile logging velocity curve and the acoustic velocity curve of multiple measured wells in a target area, for each measured well, performing a fitting operation according to the vertical seismic profile logging velocity curve and the acoustic velocity curve of the measured well to obtain the fitting parameters corresponding to the measured well, obtaining the fitting parameters of the vertical seismic profile logging velocity curve and the acoustic velocity curve of the target area according to the fitting parameters corresponding to multiple measured wells, and correcting the acoustic velocity curves of other wells in the target area except the multiple measured wells according to the fitting parameters corresponding to the target area, so that the inherent law hidden in the target block can be analyzed by statistical means, a correction scheme for the target area can be established according to multiple measured wells, quantitative description of acoustic logging correction can be realized, the limitations of the existing correction technology can be made up to a certain extent, the calibration accuracy and reliability of acoustic logging can be greatly improved, the correction efficiency can be improved, and the exploration cost can be reduced. Description of the Drawings

[0043] In order to more clearly illustrate the technical solutions in the present invention or the prior art, the following will briefly introduce the drawings required for use in the description of the embodiments or the prior art. Obviously, the drawings in the following description are some embodiments of the present invention. For those of ordinary skill in the art, other drawings can be obtained according to these drawings without creative efforts.

[0044] Figure 1 It is a schematic diagram of an application scenario provided by an embodiment of the present invention;

[0045] Figure 2 It is a schematic flow chart of an acoustic logging correction method provided by an embodiment of the present invention;

[0046] Figure 3 An interactive graph of multi-well acoustic logging velocity and vertical seismic profile logging velocity before correction provided by an embodiment of the present invention;

[0047] Figure 4 An interactive graph of multi-well acoustic logging velocity and vertical seismic profile logging velocity after correction provided by an embodiment of the present invention;

[0048] Figure 5A A probability distribution graph of multi-well acoustic logging velocity and vertical seismic profile logging velocity before correction provided by an embodiment of the present invention;

[0049] Figure 5B A probability distribution graph of multi-well acoustic logging velocity and vertical seismic profile logging velocity after correction provided by an embodiment of the present invention;

[0050] Figure 6A An overlay graph of acoustic velocity curve and vertical seismic profile velocity curve before correction provided by an embodiment of the present invention;

[0051] Figure 6B An overlay graph of acoustic velocity curve and vertical seismic profile velocity curve after correction provided by an embodiment of the present invention;

[0052] Figure 7A A time-depth relationship graph of acoustic logging and vertical seismic profile logging before correction provided by an embodiment of the present invention;

[0053] Figure 7B A time-depth relationship graph of acoustic logging and vertical seismic profile logging after correction provided by an embodiment of the present invention;

[0054] Figure 8 A comparison graph of the comprehensive calibration profiles of Well 2 in a certain area before and after correction provided by an embodiment of the present invention;

[0055] Figure 9 A comparison graph of the comprehensive calibration profiles of Well 1 in a certain area before and after correction provided by an embodiment of the present invention;

[0056] Figure 10 An acoustic velocity correction chart provided by an embodiment of the present invention;

[0057] Figure 11 A structural schematic diagram of an acoustic logging correction device provided by an embodiment of the present invention;

[0058] Figure 12 A hardware structural schematic diagram of an acoustic logging correction device provided by an embodiment of the present invention. Detailed implementation manners

[0059] Next, the technical solutions in the embodiments of the present invention will be clearly and completely described in conjunction with the accompanying drawings in the embodiments of the present invention. Obviously, the described embodiments are only a part of the embodiments of the present invention, rather than all the embodiments. All other embodiments obtained by those of ordinary skill in the art based on the embodiments of the present invention without creative efforts shall fall within the protection scope of the present invention.

[0060] The terms "first", "second", "third", "fourth", etc. (if any) in the specification and claims of the present invention and the above-mentioned drawings are used to distinguish similar objects, and do not necessarily need to be used to describe a specific order or sequence. It should be understood that such data can be interchanged under appropriate circumstances, 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 inclusion. For example, a process, method, system, product or device including a series of steps or units does not necessarily have to be limited to those steps or units clearly listed, but may include other steps or units not clearly listed or inherent to these processes, methods, products or devices.

[0061] Figure 1 FIG. is a schematic diagram of an application scenario provided for an embodiment of the present invention. When conducting oil and gas exploration in some complex blocks of an oilfield, after the seismic exploration determines the geological structure of the area, it is necessary to have a certain understanding of the possible oil-bearing conditions of the formation to be logged. Usually, sonic logging technology is used for logging operations, and the directly logged data has certain errors, so it is necessary to correct the logging results.

[0062] Among them, in some technologies, borehole compensation can be used to correct the sonic velocity measurement. This correction method usually corrects the measurement error caused by borehole collapse. Specifically, first obtain a collapse index to describe the degree of borehole collapse, and then compensate the sonic logging to a certain extent according to the size of the collapse index. However, when the collapse is severe, this method is not applicable.

[0063] In other technologies, mud invasion is used to correct the acoustic travel time, correcting the formation where the invasion of the drilling fluid is relatively serious. Specifically, an alteration index can be obtained by using resistivity or other logging curves to describe the depth and influence degree of the drilling fluid invading the virgin formation, and then the acoustic travel time is corrected according to the alteration index. However, this method is relatively limited and only considers one influencing factor, namely mud invasion.

[0064] In some comprehensive technologies, two calibration methods can be combined to calibrate the acoustic travel time by using both the collapse index and the alteration index. However, these methods only consider the impacts of borehole collapse and mud invasion on acoustic logging and quantify them. Therefore, these methods are not suitable for some composite basins.

[0065] In certain complex blocks, due to the large errors in acoustic logging and the inability of conventional calibration methods to meet the requirements, the vertical seismic profile logging with higher reliability is often used to complete the well-seismic calibration work. As a result, the exploration cost is increased to a great extent. To solve the problem of calibrating the acoustic travel time under extremely complex geological conditions and eliminate the comprehensive impacts of various influencing factors on acoustic logging as much as possible, the embodiments of the present invention provide an acoustic logging calibration method. By statistically analyzing a region where the vertical seismic profile logging data of several wells have been measured, starting from the velocity, the acoustic velocity calibration formula is obtained by fitting the vertical seismic profile logging velocity curve and the acoustic logging velocity curve, so as to calibrate the acoustic logging of other wells in this region, and to a certain extent, make up for the limitations and deficiencies of the existing calibration technologies.

[0066] The technical solutions of the present invention will be described in detail below with specific embodiments. These specific embodiments can be combined with each other, and the same or similar concepts or processes may not be repeated in some embodiments.

[0067] Figure 2 The flow chart of an acoustic logging calibration method provided by the embodiments of the present invention is as Figure 2 shown. The method provided in this embodiment may include:

[0068] Step 201: Obtain the vertical seismic profile logging velocity curves and the acoustic velocity curves of multiple measured wells in the target area.

[0069] Optionally, the target area may be the area where multiple measured wells to be processed are located. The positions of the multiple measured wells may have the same or similar geological conditions and not have too large a lateral span. Specifically, the target area may include an area within the same secondary tectonic unit. Here, the secondary tectonic unit is a tectonic zone composed of a series of similar single structures in the basin.

[0070] In this embodiment, multiple wells in the target area are selected as the measured wells. According to the vertical seismic profile (VSP) logging and acoustic logging technologies, two velocity curves corresponding to the multiple wells are obtained. One is the velocity curve based on the vertical seismic profile logging, and the other is the acoustic velocity curve calculated based on the acoustic logging.

[0071] Among them, the horizontal axes of the velocity curve based on vertical seismic profile logging and the acoustic velocity curve are both well depth, and the vertical axes are velocity.

[0072] Optionally, the acoustic velocity curve is calculated based on the acoustic travel time curve. The acoustic travel time velocity and the acoustic logging velocity are reciprocals of each other.

[0073] Among them, the acoustic travel time curve, also known as the acoustic curve and the acoustic logging curve, is a curve obtained from the measured acoustic travel time velocity during acoustic logging.

[0074] Step 202: For each well to be measured, perform a fitting operation according to the vertical seismic profile logging velocity curve and the acoustic velocity curve of the well to be measured to obtain the fitting parameters corresponding to the well to be measured.

[0075] Optionally, for each well, the vertical seismic profile logging velocity curve and the acoustic velocity curve can be fitted based on the least squares method to obtain the fitting parameters of each well, so as to obtain the regression function of each well.

[0076] Step 203: According to the fitting parameters corresponding to multiple wells to be measured, obtain the fitting parameters of the vertical seismic profile logging velocity curve and the acoustic velocity curve of the target area.

[0077] Optionally, according to the obtained fitting parameters of multiple wells to be measured, a suitable fitting parameter can be selected from them as the fitting parameter of the target area.

[0078] Step 204: According to the fitting parameters corresponding to the target area, correct the acoustic velocity curves of other wells in the target area except the multiple wells to be measured.

[0079] Optionally, after obtaining the fitting parameters corresponding to the target area, the correction formula corresponding to the target area can be obtained. According to the obtained correction formula, acoustic logging correction can be performed on other wells in the target area. By using acoustic logging to obtain the acoustic velocity curves of other wells and substituting the acoustic velocity into the correction formula, the acoustic velocity curves of other wells can be corrected.

[0080] Specifically, when the fitting parameters of a certain target area are calculated, the correction function of the area can be obtained. Select other wells outside the multiple wells to be measured in the target area, perform acoustic logging on other wells to obtain the acoustic velocity curves of other wells, and correct the acoustic velocity curves with the correction function to obtain the corrected acoustic velocity curves.

[0081] In the embodiments of the present invention, by obtaining the vertical seismic profile logging velocity curves and acoustic velocity curves of multiple wells to be measured in a target area, for each well to be measured, fitting operations are performed according to the vertical seismic profile logging velocity curve and the acoustic velocity curve of the well to be measured to obtain the fitting parameters corresponding to the well to be measured. According to the fitting parameters corresponding to multiple wells to be measured, the fitting parameters of the vertical seismic profile logging velocity curve and the acoustic velocity curve of the target area are obtained. According to the fitting parameters corresponding to the target area, the acoustic velocity curves of other wells in the target area except the multiple wells to be measured are corrected. Thus, the internal laws hidden in the target block can be analyzed by statistical means, a correction scheme for the target area can be established based on multiple wells to be measured, quantitative description of acoustic logging correction can be realized, the limitations of existing correction technologies can be made up to a certain extent, the calibration accuracy and reliability of acoustic logging can be greatly improved, the correction efficiency can be increased, and the exploration cost can be reduced.

[0082] Based on the above embodiments, optionally, performing fitting operations according to the vertical seismic profile logging velocity curve and the acoustic velocity curve of the well to be measured to obtain the fitting parameters corresponding to the well to be measured includes:

[0083] Establish a regression function for the vertical seismic profile logging velocity curve and the acoustic velocity curve, where the regression function includes fitting parameters; select multiple points on the vertical seismic profile logging velocity curve and the acoustic velocity curve of the well to be measured, and perform fitting operations according to the velocity values corresponding to the selected points to assign values to the fitting parameters corresponding to the well to be measured.

[0084] For the vertical seismic profile logging velocity curve and the acoustic velocity curve corresponding to the well to be measured, establish a regression function for the two curves corresponding to the well to be measured, and the regression function contains fitting parameters.

[0085] Specifically, for a certain well to be measured, the velocity values corresponding to the two curves of the well to be measured can be selected according to different depths, and the velocity values at different depths are selected and fitted to obtain the fitting parameters of the well to be measured.

[0086] Optionally, the velocity values on the two velocity curves of each well to be measured can be traversed for fitting to obtain the fitting parameters corresponding to each well to be measured, so as to obtain multiple fitting parameters.

[0087] In this embodiment, by fitting the velocities on the two curves of each well to be measured, the fitting parameters of each well to be measured are obtained, quantifying the error of acoustic logging in the target area, and providing a new idea for the correction method of acoustic logging.

[0088] Optionally, the regression function is

[0089]

[0090] The convergence condition for the fitting operation is to take the minimum value; where represents the regression function corresponding to the well under test, a0, a1, …, a n represents the fitting parameters of the well under test, x i is the velocity value corresponding to the i-th point on the acoustic velocity curve, y i represents the velocity value corresponding to the i-th point on the vertical seismic profile logging velocity curve, is the calculated value of the fitting formula, ξ represents the single-well error value, n represents a positive integer greater than or equal to 2, and p represents the number of selected points.

[0091] Among them, the depths corresponding to the points with the same serial number on the two curves are the same. For example, when selecting the velocity values on the two velocity curves of a certain well under test, the velocity values corresponding to the depth when i = 3 can be selected on the two velocity curves. For example, when i = 3, the selected depth is 200m, and the velocity values corresponding to the same depth on the two velocity curves are respectively selected as 3400m / s and 4500m / s. When 50 depth-corresponding velocity values are selected, the two velocity curves of the well under test can be fitted.

[0092] According to the regression functions of the two curves corresponding to each well established, the fitting parameters corresponding to each well are obtained. Among them, can be obtained according to the following expression:

[0093]

[0094] where m represents the number of wells under test, and n represents a positive integer greater than or equal to 2.

[0095] Optionally, when n = 2, the regression function can be obtained as The relationship between the acoustic velocity curves and the vertical seismic profile logging velocity curves of most wells can be clearly outlined by the quadratic regression function.

[0096] When the convergence condition takes the minimum value, j groups of fitting parameters that can minimize the fitting error of each well under test can be obtained. Among them, the number of wells under test and the number of fitting parameters can be the same.

[0097] In this embodiment, geological factors such as formation fluid properties, wellbore temperature and pressure conditions, and pore fractures, which have obvious effects on acoustic time difference measurement but are difficult to quantify, are effectively comprehensively considered to obtain the fitting parameters of each well, so as to retain the single-well characteristics of each well.

[0098] Optionally, according to the fitting parameters corresponding to multiple wells under test, the fitting parameters of the vertical seismic profile logging velocity curve and the acoustic velocity curve in the target area are obtained, including:

[0099] Substitute the fitting parameters corresponding to the multiple wells to be measured into the following formula:

[0100]

[0101] where, δ l represents the overall error of m wells to be measured under the l-th set of fitting parameters, represents the single-well error obtained by calculating the j-th well to be measured with the l-th set of fitting parameters, ξ j represents the minimum single-well error of the j-th well to be measured to obtain the optimal fitting parameters, and m represents the number of wells to be measured; according to the convergence condition, select the fitting parameters corresponding to the target area from the fitting parameters corresponding to the multiple wells to be measured; where, the convergence condition is that δ l takes the minimum value.

[0102] The fitting parameters corresponding to each well can be successively substituted into formula (3) to obtain the error δ l of each well under this formula. By obtaining the minimum error δ l , the fitting parameters corresponding to the target area are obtained.

[0103] In this embodiment, the fitting parameters of the target area are found by the substitution method, so that the found fitting parameters are more in line with the geological characteristics of the target area, calibrate the acoustic logging, and obtain an acoustic logging curve consistent with the vertical seismic profile logging velocity, greatly improving the calibration accuracy and reliability of the acoustic logging. On this basis, a calibration formula for multiple target areas can be established to minimize the number of vertical seismic profile logging and reduce the exploration cost.

[0104] Optionally, for each well to be measured, perform a fitting operation according to the vertical seismic profile logging velocity curve and the acoustic velocity curve of the well to be measured to obtain the fitting parameters corresponding to the well to be measured, including:

[0105] Establish an interaction diagram of the vertical seismic profile logging velocity curve and the acoustic velocity curve of the target area. The horizontal axis of the interaction diagram is the acoustic logging velocity, and the vertical axis is the vertical seismic profile logging velocity. The positions of the interaction points in the interaction diagram are determined by the vertical seismic profile logging velocity curves and the acoustic velocity curves of multiple wells to be measured; according to the positions of the respective interaction points in the interaction diagram, determine whether the concentration degree of the respective interaction points meets a preset condition; if so, for each well to be measured, perform a fitting operation according to the vertical seismic profile logging velocity curve and the acoustic velocity curve of the well to be measured to obtain the fitting parameters corresponding to the well to be measured.

[0106] According to the logging velocity curve and acoustic velocity curve of the vertical seismic profile corresponding to the well in the target area, use Jason software to make an interactive plot of the two curves, and determine whether the position of the intersection point on the interactive plot meets the preset conditions, where the preset conditions can be set according to the actual situation. Specifically, on an interactive plot with the acoustic logging velocity on the horizontal axis and the vertical seismic profile logging velocity on the vertical axis, draw a straight line of y = x, dividing the plane into upper and lower parts. Set the upper part as the first region and the lower part as the second region. Determine that when the percentage of the intersection points of the target area in the first region on the interactive plot exceeds the preset threshold, the value by which the acoustic velocity is greater than the vertical seismic profile logging velocity in this area is related in a certain way. It is obtained that the well under test in the target area meets the conditions, and a correction function for the target area can be constructed to fit the two curves to obtain the corresponding fitting parameters.

[0107] Figure 3 This is an interactive plot of the acoustic logging velocity and vertical seismic profile logging velocity of multiple wells before correction provided by an embodiment of the present invention. As Figure 3 shown, the horizontal axis of this interactive plot represents the acoustic velocity, with the unit of m / s, and the vertical axis represents the vertical seismic profile logging velocity, with the unit of m / s. There is a straight line of y = x that divides the interactive plot into two parts, which are respectively represented as the first region and the second region. Among them, the first region is represented as VSP velocity > acoustic velocity, meaning that the vertical seismic profile logging velocity of the intersection points in this region is greater than the acoustic logging velocity. The second region is represented as VSP velocity < acoustic velocity, meaning that the vertical seismic profile logging velocity of the intersection points in this quadrant is less than the acoustic logging velocity. When a certain percentage of the intersection points in the first region of the interactive plot account for the total intersection points, they are relatively concentrated on the upper side of the y = x curve. It can be obtained that the intersection points of the well under test in the target area with a vertical seismic profile logging velocity greater than the acoustic logging velocity account for a relatively large proportion, and there is a correlation between the two. Curve fitting can be performed on each well in the target area to obtain the fitting parameters.

[0108] Specifically, the percentage can be set to 80%. When the intersection points in the first region account for 80% of the total intersection points, further curve fitting can be carried out.

[0109] Since there are many influencing factors during acoustic logging, the usually obtained acoustic velocity is relatively small compared to the vertical seismic profile logging velocity with fewer influencing factors. Therefore, when the intersection points where the acoustic logging velocity is smaller than the vertical seismic profile logging velocity account for a certain percentage, it can be known that the velocity curves of the two satisfy a certain relationship, and further correction can be carried out.

[0110] In this embodiment, an interactive analysis is performed on the acoustic logging velocity and the vertical seismic profile logging velocity of the well to be measured, the positional relationship of the interactive points on the interactive graph is judged, it is obtained that the well to be measured in the target area meets the statistical basis, and it is obtained that the subsequent calibration work is feasible.

[0111] Optionally, calibrating the acoustic velocity curves of other wells in the target area except the multiple wells to be measured includes:

[0112] Obtain the acoustic velocity curve of the well to be analyzed in the target area; determine the vertical seismic profile logging velocity curve corresponding to the well to be analyzed according to the acoustic velocity curve of the well to be analyzed and the fitting parameters corresponding to the target area; perform well-seismic calibration on the well to be analyzed according to the determined vertical seismic profile logging velocity curve.

[0113] According to the obtained fitting parameters corresponding to the target area, a calibration function for the target area is obtained. Other wells in the target area that need to be analyzed can be calibrated through the calibration function. First, use acoustic logging to obtain the acoustic travel time velocity of the well to be analyzed, then obtain the acoustic velocity according to the acoustic travel time velocity, substitute the acoustic velocity into the calibration function to obtain the calibrated acoustic velocity curve, that is, the pseudo-vertical seismic profile logging velocity curve of the well to be analyzed after fitting. The calibrated pseudo-vertical seismic profile logging velocity curve can be applied to the well-seismic calibration work.

[0114] In this embodiment, by calculating the fitting parameters of the target area, the acoustic logging data is calibrated and compensated, which saves the logging cost of the vertical seismic profile logging velocity curve in complex blocks and makes up for the limitations and deficiencies of the existing calibration methods to a certain extent.

[0115] Figure 4 This is an interactive graph of the calibrated multi-well acoustic logging velocity and vertical seismic profile logging velocity provided by the embodiment of the present invention. As Figure 4 shown, according to Figure 3 the interactive graph analysis, the interactive points on the interactive graph of the target area meet the preset conditions, the wells to be measured in the target area can be fitted to obtain the fitting parameters of the target area, and thus the calibration formula is obtained as f(x) = 6.16×10 -5 x 2 + 0.38x + 1548. After calibrating the acoustic velocity in Figure 3 , it can be obtained that the interactive points are evenly distributed on both sides of the y = x curve. When the interactive points are evenly distributed on both sides of the y = x curve, it indicates that the calibrated acoustic velocity is relatively close to the vertical seismic profile logging velocity, and the calibrated acoustic velocity can be equivalent to the vertical seismic profile logging velocity, which shows that the calibration formula has a certain feasibility.

[0116] Figure 5AThis is the probability distribution diagram of the multi-well acoustic logging velocity and vertical seismic profile logging velocity before calibration provided by the embodiments of the present invention. As Figure 5A shown, the relationship between the acoustic velocity and the vertical seismic profile logging velocity is displayed in a three-dimensional manner. Before calibration, the data points in the figure are more concentrated in the right half of the figure. In the second area on the right side of the figure, it can be obtained that the VSP velocity > acoustic velocity, and in the first area on the left side, the VSP velocity < acoustic velocity. Obviously, the data points of the measured wells in the target area are relatively concentrated and not scattered in the right half of the three-dimensional figure. Therefore, the preset conditions are met, and curve fitting can be performed to obtain the fitting parameters corresponding to the target area.

[0117] Figure 5B This is the probability distribution diagram of the multi-well acoustic logging velocity and vertical seismic profile logging velocity after calibration provided by the embodiments of the present invention. As Figure 5B shown, by calibrating the target area, the data points in the figure after calibration are distributed to the middle part, which is equivalent to the two velocities being basically equal. Compared with Figure 5A it can be known that the number of sample points in the probability distribution diagram after calibration has obvious changes, and the position is relatively concentrated between the first area and the second area.

[0118] In an achievable embodiment, when calibrating and correlating the strata of a certain formation in the west, it is found that the synthetic seismogram made using acoustic logging does not match the seismic data, with a large error and unable to meet the calibration work. When comparing the acoustic logging data with the vertical seismic profile logging data, it is found that there is an obvious separation phenomenon in the velocity baselines of the two. Comparing from the time-depth relationship, it is found that the slope of the time-depth relationship of the vertical seismic profile is larger, and the two show an obvious separation at the bottom, and the calibration results are quite different. Therefore, there will be relatively large problems when simply using acoustic logging data for calibration.

[0119] When comprehensively analyzing the calibration error, it is found that complex geological conditions and formations are important factors leading to errors in acoustic measurement. Such influencing factors are comprehensive, and common calibration methods usually correct for a single influencing factor. Therefore, it cannot meet the requirements in terms of calibration principle, and a new calibration method needs to be constructed. In the case of the embodiments of the present invention, first, statistical analysis is performed on the vertical seismic profiles and acoustic logging of all wells in structural unit A. Under the statistics of big data and multiple samples, it is found that the acoustic logging velocities of all wells are less than the vertical seismic profile logging velocities, and the sample points are concentrated, meeting the basic conditions of the present invention and passing the feasibility verification. Then, fitting calculations are performed on all wells in the area of structural unit A to obtain the calibration formula for this area. Next, acoustic logging calibration is performed on all wells in this area. It is verified that the calibrated logging velocity curve coincides with the baseline of the vertical seismic profile velocity curve, and the sample points after calibration are significantly transferred to between the first area and the second area, and the distribution density is relatively uniform.

[0120] Figure 6A This is the overlay diagram of the acoustic wave velocity curve before correction and the vertical seismic profile velocity curve provided by the embodiment of the present invention. As Figure 6A shown, before correction, from the time-depth curve, the seismic profile velocities of the three measured wells are to the right compared to the acoustic wave velocity, indicating that the seismic profile velocity is larger and the acoustic wave velocity is smaller.

[0121] Figure 6B This is the overlay diagram of the acoustic wave velocity curve after correction and the vertical seismic profile velocity curve provided by the embodiment of the present invention. As Figure 6B shown, after correction, from the time-depth curve, the seismic profile velocities of the three measured wells and the acoustic wave velocities are basically coincident. It shows that the acoustic wave velocity curve obtained according to the correction formula can well fit the vertical seismic profile curve.

[0122] Figure 7A This is the relationship diagram of the acoustic wave logging and the vertical seismic profile logging time-depth curves provided by the embodiment of the present invention. As Figure 7A shown, for Well 2 in a certain area, Well 101 in a certain area, and Well 3 in a certain area among the three measured wells, the gap of the time-depth curves from the top to the bottom becomes significantly larger. Since when passing through the rock layers of the same depth, the logging velocity of the vertical seismic profile is faster and the time is shorter than that of the acoustic wave velocity, with the accumulation of depth, the gap at the bottom becomes larger and larger. Among them, the time-depth relationship curve represents converting the velocity curve into the relationship between time and depth.

[0123] Figure 7B This is the relationship diagram of the acoustic wave logging and the vertical seismic profile logging time-depth curves after correction provided by the embodiment of the present invention. As Figure 7B shown, for Well 2 in a certain area, Well 101 in a certain area, and Well 3 in a certain area after correction, the acoustic wave velocity and the vertical seismic profile logging velocity are approximately equal, so the comparison of the two in terms of time and depth is also the same. Therefore, the acoustic wave time-depth curve and the vertical seismic profile logging time-depth curve have a high degree of coincidence.

[0124] Figure 8 This is the comparison diagram of the comprehensive calibration profiles of Well 2 in a certain area before and after correction provided by the embodiment of the present invention. As Figure 8 shown, the synthetic seismogram after correction is shorter than that before correction. The wave group characteristics of the synthetic seismogram made after correction and the wave group relationship of the entire well section match well with the seismic profile. When the velocity curve after correction is used for calibration, the calibration effect is better, and the calibration accuracy and reliability are greatly improved.

[0125] Figure 9 This is the comparison diagram of the comprehensive calibration profiles of Well 1 in a certain area before and after correction provided by the embodiment of the present invention. As Figure 9As shown, the corrected synthetic record is shorter than the uncorrected one. After correction, the wave group characteristics of the synthetic record and the wave group relationship in the entire well section match well with the seismic profile. When the velocity curve after correction is used for calibration, the calibration effect is better, and the calibration accuracy and credibility are greatly improved.

[0126] Figure 10 This is the acoustic velocity correction chart provided by the embodiment of the present invention. As Figure 10 shown, according to the correction method provided by the present invention, correction charts can be established for structural unit A, structural unit B, and structural unit C to obtain the correction function for each area. This correction function can be used to correct the acoustic velocity curves of relevant areas.

[0127] Figure 11 This is the structural schematic diagram of the acoustic logging correction device provided by the embodiment of the present invention. As Figure 11 shown, in this embodiment Figure 11 This is the structural schematic diagram of the acoustic logging correction device provided by the embodiment of the present invention. The device may include: an acquisition module 1101, a first obtaining module 1102, a second obtaining module 1103, and a correction module 1104.

[0128] The acquisition module 1101 is used to acquire the vertical seismic profile logging velocity curves and acoustic velocity curves of multiple wells to be measured in the target area;

[0129] The first obtaining module 1102 is used to perform a fitting operation on each well to be measured according to the vertical seismic profile logging velocity curve and acoustic velocity curve of the well to be measured, and obtain the fitting parameters corresponding to the well to be measured;

[0130] The second obtaining module 1103 is used to obtain the fitting parameters of the vertical seismic profile logging velocity curve and acoustic velocity curve in the target area according to the fitting parameters corresponding to multiple wells to be measured;

[0131] The correction module 1104 is used to correct the acoustic velocity curves of other wells in the target area except the multiple wells to be measured according to the fitting parameters corresponding to the target area.

[0132] Optionally, when the first obtaining module 1102 performs a fitting operation on the vertical seismic profile logging velocity curve and acoustic velocity curve of the well to be measured to obtain the fitting parameters corresponding to the well to be measured, it specifically is used for:

[0133] Establish a regression function between the vertical seismic profile logging velocity curve and the acoustic velocity curve, and the regression function includes fitting parameters;

[0134] Select a plurality of points on the vertical seismic profile logging velocity curve and the acoustic velocity curve of the well to be measured respectively, and perform a fitting operation according to the velocity values corresponding to the selected points, and assign fitting parameters corresponding to the well to be measured.

[0135] Optionally, the regression function is

[0136]

[0137] The convergence condition of the fitting operation is Take the minimum value;

[0138] Among them, represents the regression function corresponding to the well to be measured, a0, a1,..., a n represents the fitting parameter of the well to be measured, x i represents the velocity value corresponding to the i-th point on the acoustic velocity curve, y i represents the velocity value corresponding to the i-th point on the vertical seismic profile logging velocity curve, represents the calculated value of the fitting formula, ξ represents the single-well error value, n represents a positive integer greater than or equal to 2, and p represents the number of selected points.

[0139] Optionally, the second obtaining module 1103 is specifically configured to:

[0140] Substitute the fitting parameters corresponding to the multiple wells to be measured into the following formula:

[0141]

[0142] Among them, δ l represents the overall error of m wells to be measured under the l-th set of fitting parameters, represents the single-well error obtained by calculating the j-th well to be measured with the l-th set of fitting parameters, ξ j represents the minimum single-well error of the j-th well to be measured to obtain the best fitting parameter, and m represents the number of wells to be measured;

[0143] According to the convergence condition, select the fitting parameters corresponding to the target area from the fitting parameters corresponding to the multiple wells to be measured;

[0144] Among them, the convergence condition is δ l Take the minimum value.

[0145] Optionally, the first obtaining module 1102 is specifically configured to:

[0146] Establish an interactive graph of the vertical seismic profile logging velocity curve and the acoustic velocity curve of the target area. The horizontal axis of the interactive graph is the acoustic logging velocity, and the vertical axis is the vertical seismic profile logging velocity. The position of the interactive points in the interactive graph is determined by the vertical seismic profile logging velocity curves and the acoustic velocity curves of multiple wells to be measured;

[0147] Determine whether the concentration degree of each interactive point in the interactive graph meets a preset condition according to the positions of the interactive points in the interactive graph;

[0148] If it is satisfied, for each well to be measured, perform a fitting operation according to the vertical seismic profile logging velocity curve and the acoustic velocity curve of the well to be measured to obtain the fitting parameters corresponding to the well to be measured.

[0149] Optionally, when the correction module 1104 corrects the acoustic velocity curves of other wells in the target area except the multiple wells to be measured, it is specifically used for:

[0150] Obtain the acoustic velocity curve of the well to be analyzed in the target area;

[0151] Determine the vertical seismic profile logging velocity curve corresponding to the well to be analyzed according to the acoustic velocity curve of the well to be analyzed and the fitting parameters corresponding to the target area;

[0152] Perform well-seismic calibration on the well to be analyzed according to the determined vertical seismic profile logging velocity curve.

[0153] The acoustic logging correction device provided by the embodiments of the present invention can implement the acoustic logging correction method of the above embodiments as Figures 1 - 10 shown. The implementation principle and technical effects are similar, and will not be elaborated here.

[0154] Figure 12 This is a schematic structural diagram of an acoustic logging correction device provided by an embodiment of the present invention. As Figure 12 shown, the device provided in this embodiment may include: at least one processor 121 and a memory 122;

[0155] The memory 122 stores computer execution instructions;

[0156] The at least one processor 121 executes the computer execution instructions stored in the memory 122, so that the at least one processor 121 executes the method described in any of the above embodiments.

[0157] Among them, the memory 122 and the processor 121 may be connected through a bus 123.

[0158] The specific implementation principle and effect of the device provided in this embodiment can be referred to Figures 1 - 10For the relevant descriptions and effects corresponding to the illustrated embodiments, no further elaboration will be provided here.

[0159] An embodiment of the present invention further provides a computer-readable storage medium, in which computer-executable instructions are stored, and when the computer-executable instructions are executed by a processor, they are used to implement the acoustic logging correction method described in any embodiment of the present invention.

[0160] An embodiment of the present invention further provides a computer program product, including a computer program, and when the computer program is executed by a processor, it implements the acoustic logging correction method described in any embodiment of the present invention.

[0161] In the several embodiments provided by the present invention, it should be understood that the disclosed devices and methods can be implemented in other ways. For example, the device embodiments described above are merely illustrative. For example, the division of modules is only a logical function division. In actual implementation, there may be other division methods. For example, multiple modules or components can be combined or integrated into another system, or some features can be ignored or not executed. Another point is that the displayed or discussed couplings or direct couplings or communication connections to each other can be through some interfaces. The indirect couplings or communication connections of devices or modules can be in electrical, mechanical or other forms.

[0162] The modules described as separate components may or may not be physically separated. The components displayed as modules may or may not be physical units, that is, they can be located in one place or distributed to multiple network units. Some or all of the modules can be selected according to actual needs to implement the solution of this embodiment.

[0163] In addition, in each embodiment of the present invention, the functional modules can be integrated in a processing unit, or each module can exist physically alone, or two or more modules can be integrated in one unit. The units formed by the above modules can be implemented in the form of hardware or in the form of a hardware plus software functional unit.

[0164] The integrated modules implemented in the form of software functional modules can be stored in a computer-readable storage medium. The above software functional modules are stored in a storage medium, including several instructions for causing a computer device (which can be a personal computer, a server, or a network device, etc.) or a processor to execute some steps of the methods described in each embodiment of the present invention.

[0165] It should be understood that the above-mentioned processor may be a Central Processing Unit (CPU), or other general-purpose processors, Digital Signal Processors (DSPs), Application Specific Integrated Circuits (ASICs), etc. The general-purpose processor may be a microprocessor or any conventional processor, etc. The steps of the method disclosed in combination with the invention can be directly embodied as being executed and completed by a hardware processor, or by a combination of hardware and software modules in the processor.

[0166] The memory may include high-speed RAM memory, and may also include non-volatile storage NVM, such as at least one disk memory, and may also be a USB flash drive, a mobile hard disk, a read-only memory, a magnetic disk, or an optical disc, etc.

[0167] The bus may be an Industry Standard Architecture (ISA) bus, a Peripheral Component Interconnect (PCI) bus, an Extended Industry Standard Architecture (EISA) bus, etc. The bus can be divided into an address bus, a data bus, a control bus, etc. For the sake of convenience in representation, the buses in the drawings of the present invention are not limited to only one bus or one type of bus.

[0168] The above-mentioned storage medium can be implemented by any type of volatile or non-volatile storage device or a combination thereof, such as Static Random Access Memory (SRAM), Electrically Erasable Programmable Read-Only Memory (EEPROM), Erasable Programmable Read-Only Memory (EPROM), Programmable Read-Only Memory (PROM), Read-Only Memory (ROM), magnetic memory, flash memory, a magnetic disk, or an optical disc. The storage medium can be any available medium that can be accessed by a general-purpose or special-purpose computer.

[0169] An exemplary storage medium is coupled to the processor, enabling the processor to read information from the storage medium and write information to the storage medium. Of course, the storage medium can also be a component of the processor. The processor and the storage medium can be located in an Application Specific Integrated Circuit (ASIC). Of course, the processor and the storage medium can also exist as discrete components in an electronic device or a master control device.

[0170] Those of ordinary skill in the art can understand that all or part of the steps of implementing the above method embodiments can be completed by hardware related to program instructions. The foregoing program can be stored in a computer-readable storage medium. When the program is executed, it performs the steps of the above method embodiments; and the foregoing storage medium includes: various media such as ROM, RAM, magnetic disk, or optical disc that can store program codes.

[0171] After considering the specification and practicing the invention disclosed herein, those skilled in the art will readily conceive of other embodiments of the invention. The present invention is intended to cover any variations, uses, or adaptations of the invention, which follow the general principles of the invention and include common general knowledge or conventional technical means in the technical field not disclosed by the present invention. The specification and examples are only regarded as exemplary, and the true scope and spirit of the present invention are pointed out by the following claims.

[0172] It should be understood that the present invention is not limited to the exact structures described above and shown in the drawings, and various modifications and changes can be made without departing from its scope. The scope of the present invention is only limited by the appended claims.

Claims

1. An acoustic logging correction method, characterized in that Including: Obtaining the vertical seismic profile logging velocity curves and acoustic velocity curves of multiple measured wells in the target area, and obtaining the acoustic velocity curve of the well to be analyzed in the target area; the well to be analyzed in the target area is other wells in the target area except the multiple measured wells; For each measured well, performing a fitting operation according to the vertical seismic profile logging velocity curve and acoustic velocity curve of the measured well to obtain the fitting parameters corresponding to the measured well; According to the fitting parameters corresponding to multiple measured wells, obtaining the fitting parameters of the vertical seismic profile logging velocity curve and acoustic velocity curve of the target area; According to the acoustic velocity curve of the well to be analyzed and the fitting parameters corresponding to the target area, determining the pseudo-vertical seismic profile logging velocity curve corresponding to the well to be analyzed; Performing well-seismic calibration on the well to be analyzed according to the determined pseudo-vertical seismic profile logging velocity curve.

2. The method according to claim 1, wherein Performing a fitting operation according to the vertical seismic profile logging velocity curve and acoustic velocity curve of the measured well to obtain the fitting parameters corresponding to the measured well, including: Establishing a regression function between the vertical seismic profile logging velocity curve and the acoustic velocity curve, and the regression function includes fitting parameters; Selecting multiple points on the vertical seismic profile logging velocity curve and acoustic velocity curve of the measured well respectively, and performing a fitting operation according to the velocity values corresponding to the selected points to assign values to the fitting parameters corresponding to the measured well.

3. The method according to claim 2, characterized in that The regression function is: The convergence condition for the fitting operation is to take the minimum value; Among them, represents the regression function of the well to be measured, a0, a1, …, a n represents the fitting parameters of the well to be measured, x i represents the velocity value corresponding to the i-th point on the acoustic velocity curve, y i represents the velocity value corresponding to the i-th point on the vertical seismic profile logging velocity curve, represents the calculated value of the fitting formula, ξ represents the single-well error value, n is a positive integer greater than or equal to 2, and p represents the number of points selected.

4. The method according to claim 1, characterized in that According to the fitting parameters corresponding to multiple measured wells, obtaining the fitting parameters of the vertical seismic profile logging velocity curve and acoustic velocity curve of the target area, including: Substituting the fitting parameters corresponding to the multiple measured wells into the following formula: Among them, δ l represents the overall error of m measured wells under the l-th set of fitting parameters, and ξ lj represents the single-well error calculated for the j-th measured well according to the l-th set of fitting parameters, and ξ j represents the minimum single-well error of the j-th measured well with the best fitting parameters, and m is the number of measured wells; According to the convergence condition, selecting the fitting parameters corresponding to the target area from the fitting parameters corresponding to the multiple measured wells; Among them, the convergence condition is δ l takes the minimum value.

5. The method according to claim 1, wherein For each measured well, performing a fitting operation according to the vertical seismic profile logging velocity curve and acoustic velocity curve of the measured well to obtain the fitting parameters corresponding to the measured well, including: Establishing an interaction diagram of the vertical seismic profile logging velocity curve and acoustic velocity curve of the target area, the horizontal axis of the interaction diagram is the acoustic logging velocity, the vertical axis is the vertical seismic profile logging velocity, and the positions of the interaction points in the interaction diagram are determined by the vertical seismic profile logging velocity curves and acoustic velocity curves of multiple measured wells; According to the positions of the respective interaction points in the interaction diagram, determining whether the concentration degree of the respective interaction points meets a preset condition; If it is satisfied, for each measured well, performing a fitting operation according to the vertical seismic profile logging velocity curve and acoustic velocity curve of the measured well to obtain the fitting parameters corresponding to the measured well.

6. An acoustic logging correction device, characterized in that, Including: An acquisition module, configured to acquire the vertical seismic profile logging velocity curves and acoustic velocity curves of multiple measured wells in the target area, and acquire the acoustic velocity curve of the well to be analyzed in the target area; the well to be analyzed in the target area is other wells in the target area except the multiple measured wells; A first obtaining module, configured to perform a fitting operation on the vertical seismic profile logging velocity curve and the acoustic velocity curve of each well to be measured, so as to obtain the fitting parameters corresponding to the well to be measured; A second obtaining module, configured to obtain the fitting parameters of the vertical seismic profile logging velocity curve and the acoustic velocity curve of the target area according to the fitting parameters corresponding to multiple wells to be measured; A determining module, configured to determine the pseudo vertical seismic profile logging velocity curve corresponding to the well to be analyzed according to the acoustic velocity curve of the well to be analyzed and the fitting parameters corresponding to the target area; A calibration module, configured to perform well-seismic calibration on the well to be analyzed according to the determined pseudo vertical seismic profile logging velocity curve; 7. An acoustic logging calibration device, characterized in that, including: at least one processor and a memory; the memory stores computer-executable instructions; the at least one processor executes the computer-executable instructions stored in the memory, so that the at least one processor executes the acoustic logging correction method according to any one of claims 1-5; 8. A computer-readable storage medium, characterized in that, computer-executable instructions are stored in the computer-readable storage medium, and when the computer-executable instructions are executed by a processor, they are used to implement the acoustic logging correction method according to any one of claims 1-5; 9. A computer program product, comprising a computer program, characterized in that, the computer program, when executed by a processor, implements the acoustic logging correction method according to any one of claims 1-5.

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