Method and device for evaluating gas-bearing property of dense clastic rock reservoir and storage medium

Abstract

The application discloses a method and device for evaluating gas content of a compact clastic rock reservoir and a storage medium. The method obtains a first neutron logging curve, a first acoustic logging curve and an open flow capacity of a test interval. The second neutron logging curve and the second acoustic logging curve of a standard mudstone section are determined based on the first neutron logging curve and the first acoustic logging curve of the test interval. The first scale value of the compensated neutron and the second scale value of the compensated acoustic wave are determined so that the first combined area obtained by combining the second neutron logging curve and the second acoustic logging curve is minimized. The first neutron logging curve and the first acoustic logging curve are combined based on the first scale value of the compensated neutron and the second scale value of the compensated acoustic wave, and the second combined area is obtained. The production prediction relationship is established based on the second combined area and the open flow capacity. The gas content of the reservoir is evaluated according to the production prediction relationship. The application can solve the problem of predicting the productivity of a fractured compact clastic rock gas reservoir.

Description

Technical Field

[0001] The embodiments of the present invention relate to the technical field of oil and gas exploration, and particularly to a method, apparatus, equipment, and storage medium for evaluating the gas content of tight clastic rock reservoirs. Background Technology

[0002] In recent years, as oil and gas exploration has progressed to deeper formations, accurately evaluating the gas-bearing capacity of unconventional gas reservoirs, such as deep tight sandstone, has become a critical issue that urgently needs to be addressed. Currently, although a relatively complete set of qualitative identification techniques for reservoir fluids has been developed, methods for quantitative analysis of reservoir gas-bearing capacity are still limited.

[0003] Conventional methods for quantitatively evaluating reservoir gas-bearing capacity have certain limitations. For example, while the method of overlaying neutron porosity and density porosity curves can qualitatively identify reservoirs, its quantitative evaluation effect is poor and it is easily affected by pore structure and wellbore conditions. The rock elastic parameter method requires additional logging data, which is labor-intensive and complex to operate. Although the comprehensive parameter method or index method considers multiple logging response factors, it lacks a theoretical basis and its quantitative evaluation effect is not ideal. Furthermore, methods such as reconstructing gas-bearing index curves by intersecting sonic and neutron logging curves, or using the difference spectrum method and shift spectrum method of nuclear magnetic resonance logging data to identify gas layers, either lack theoretical support or require special logging data, making them impractical. Therefore, there is an urgent need for a simple and accurate new method for quantitatively evaluating reservoir gas-bearing capacity. Summary of the Invention

[0004] The purpose of this invention is to provide at least one method, apparatus, equipment, and storage medium for evaluating the gas content of tight clastic rock reservoirs, which can at least solve the technical problem of the lack of a quantitative and accurate evaluation method for the gas content of deep tight sandstone reservoirs in the prior art.

[0005] To address the aforementioned technical problems, at least one embodiment of this application provides a method for evaluating the gas content of tight clastic rock reservoirs, comprising:

[0006] Acquire the first neutron logging curve, the first acoustic logging curve, and the unobstructed flow rate data for the test layer;

[0007] Based on the first neutron logging curve and the first acoustic logging curve of the test layer, determine the second neutron logging curve and the second acoustic logging curve of the standard mudstone section.

[0008] Determine the first scale value of the compensating neutron and the second scale value of the compensating acoustic wave to minimize the first superposition area obtained by superimposing the second neutron logging curve and the second acoustic logging curve;

[0009] The first neutron logging curve and the first acoustic logging curve are superimposed based on the first scale value of the compensated neutron and the second scale value of the compensated acoustic wave to obtain the second superimposed area;

[0010] A production prediction relationship is established based on the second overlapping area and the unobstructed flow data;

[0011] The gas content of the reservoir in the test section is evaluated based on the aforementioned production prediction relationship.

[0012] At least one embodiment of this application also provides a device for evaluating the gas content of tight clastic rock reservoirs, comprising:

[0013] The acquisition module is used to acquire the first neutron logging curve, the first acoustic logging curve, and the unobstructed flow rate data of the test layer.

[0014] The first determining module is used to determine the second neutron logging curve and the second acoustic logging curve of the standard mudstone section based on the first neutron logging curve and the first acoustic logging curve of the test layer.

[0015] The second determining module is used to determine the first scale value of the compensating neutron and the second scale value of the compensating acoustic wave when the first superposition area obtained by superimposing the second neutron logging curve and the second acoustic logging curve is minimized.

[0016] The overlay module is used to overlay the first neutron logging curve and the first acoustic logging curve based on the first scale value of the compensated neutron and the second scale value of the compensated acoustic wave to obtain a second overlay area.

[0017] The relationship establishment module is used to establish a production prediction relationship based on the second overlapping area and the unobstructed flow data;

[0018] The evaluation module is used to evaluate the gas content of the reservoir in the test section based on the production prediction relationship.

[0019] At least one embodiment of this application also provides an electronic device, including: at least one processor; and a memory communicatively connected to the at least one processor; wherein the memory stores instructions executable by the at least one processor, the instructions being executed by the at least one processor to enable the at least one processor to perform the steps of the following method:

[0020] Acquire the first neutron logging curve, the first acoustic logging curve, and the unobstructed flow rate data for the test layer;

[0021] Based on the first neutron logging curve and the first acoustic logging curve of the test layer, determine the second neutron logging curve and the second acoustic logging curve of the standard mudstone section.

[0022] Determine the first scale value of the compensating neutron and the second scale value of the compensating acoustic wave to minimize the first superposition area obtained by superimposing the second neutron logging curve and the second acoustic logging curve;

[0023] The first neutron logging curve and the first acoustic logging curve are superimposed based on the first scale value of the compensated neutron and the second scale value of the compensated acoustic wave to obtain the second superimposed area;

[0024] A production prediction relationship is established based on the second overlapping area and the unobstructed flow data;

[0025] The gas content of the reservoir in the test section is evaluated based on the aforementioned production prediction relationship.

[0026] At least one embodiment of this application also provides a computer-readable storage medium storing a computer program that, when executed by a processor, implements the steps of the following method:

[0027] Acquire the first neutron logging curve, the first acoustic logging curve, and the unobstructed flow rate data for the test layer;

[0028] Based on the first neutron logging curve and the first acoustic logging curve of the test layer, determine the second neutron logging curve and the second acoustic logging curve of the standard mudstone section.

[0029] Determine the first scale value of the compensating neutron and the second scale value of the compensating acoustic wave to minimize the first superposition area obtained by superimposing the second neutron logging curve and the second acoustic logging curve;

[0030] The first neutron logging curve and the first acoustic logging curve are superimposed based on the first scale value of the compensated neutron and the second scale value of the compensated acoustic wave to obtain the second superimposed area;

[0031] A production prediction relationship is established based on the second overlapping area and the unobstructed flow data;

[0032] The gas content of the reservoir in the test section is evaluated based on the aforementioned production prediction relationship.

[0033] The embodiments of this application provide a method, apparatus, electronic equipment, and computer-readable storage medium for evaluating the gas content of tight clastic rock reservoirs. Based on conventional acoustic transit time and the changes in neutrons affected by natural gas, it utilizes the response characteristics of increased acoustic logging curves and decreased neutron logging curve excavation effect caused by the presence of gas in the reservoir. The gas content of the reservoir is quantitatively characterized by the area of ​​overlap between the two curves. The method is compared and analyzed with unobstructed flow rate data to establish the relationship between gas-bearing parameters and production. The method is simple to operate, has a high correlation coefficient, and provides a new approach for the quantitative evaluation of reservoir gas content. It solves the problem of predicting the production capacity of fractured tight clastic rock gas reservoirs, and addresses the issues of low calculation accuracy and production capacity prediction in previous methods. This has significant implications for the production capacity construction and economic development of gas reservoir reserves.

[0034] In some optional embodiments, the step of establishing a production forecast relationship based on the second overlapping area and the unobstructed flow data includes:

[0035] The acoustic and neutron-containing gas-bearing superposition area per unit thickness of the test layer is calculated based on the second superposition area.

[0036] The yield prediction relationship is obtained by fitting the acoustic wave and neutron-containing gas overlapping area per unit thickness with the unobstructed flow rate data.

[0037] In some alternative embodiments, the acoustic and neutron-containing gas overlap area per unit thickness is the ratio of the second overlap area to the energy contribution thickness.

[0038] In some optional embodiments, the second overlapping area is the sum of the increase in acoustic waves caused by gas inclusion and the decrease in neutron logging curves caused by gas extraction effects.

[0039] In some optional embodiments, the expression for the acoustic wave and neutron-containing gas overlap area per unit thickness of the test layer is:

[0040]

[0041] Where A is the superposition area of ​​sound waves and neutron-containing gas, AC i -AC1 represents the increase in sound waves caused by gas content; CNL1-CNL i H represents the reduction in neutron logging curves caused by gas extraction effects; H represents the thickness of the test section contributing to productivity.

[0042] In some optional embodiments, the step of determining the second neutron logging curve and the second sonic logging curve of the standard mudstone section based on the first neutron logging curve and the first sonic logging curve of the test layer includes:

[0043] Obtain the natural gamma curve of the test layer;

[0044] The mudstone section without coal was determined based on the first neutron logging curve, the first sonic logging curve, and the natural gamma curve.

[0045] The neutron logging curve of the coal-free mudstone section is determined to be the second neutron logging curve of the standard mudstone section, and the sonic logging curve of the coal-free mudstone section is determined to be the second sonic logging curve of the standard mudstone section.

[0046] In some optional embodiments, the step of determining a first scale value for the compensating neutron and a second scale value for the compensating acoustic wave to minimize the overlap area between the second neutron logging curve and the second acoustic logging curve includes:

[0047] The second neutron logging curve and the second acoustic logging curve are superimposed based on the calibration values ​​of the initial compensated neutron and the initial compensated acoustic wave.

[0048] Select the benchmark value of the superimposed overlap value of the second neutron logging curve and the second acoustic logging curve;

[0049] Based on the reference value of the overlap value of the compensated acoustic wave and the compensated neutron, the first scale value of the compensated neutron and the second scale value of the compensated acoustic wave are adjusted until the overlap area between the second neutron logging curve and the second acoustic wave logging curve is minimized. Attached Figure Description

[0050] One or more embodiments are illustrated by way of example with reference to the accompanying drawings, and these illustrative descriptions do not constitute a limitation on the embodiments.

[0051] Figure 1 This is a flowchart of a method for evaluating the gas content of tight clastic rock reservoirs provided in one embodiment of this application;

[0052] Figure 2 This is a flowchart of a method for evaluating the gas content of tight clastic rock reservoirs provided in another embodiment of this application;

[0053] Figure 3 A graph showing the relationship between unit thickness stacked area and unobstructed flow rate is provided for another embodiment of this application;

[0054] Figure 4 A well logging result diagram for well A provided in another embodiment of this application;

[0055] Figure 5 A comparison chart of the fitted production capacity and the measured production capacity of Well A provided for another embodiment of this application;

[0056] Figure 6 A logging result diagram of well B provided for another embodiment of this application;

[0057] Figure 7 A comparison chart of B-fit capacity and measured capacity provided for another embodiment of this application.

[0058] Figure 8 A schematic diagram of a gas-bearing evaluation device for tight clastic rock reservoirs provided in another embodiment of this application;

[0059] Figure 9 A schematic diagram of the structure of an electronic device provided for another embodiment of this application.

[0060] In the accompanying drawings, the same parts are referred to by the same reference numerals, and the drawings are not drawn to scale. Detailed Implementation

[0061] To make the objectives, technical solutions, and advantages of the embodiments of this application clearer, the various embodiments of this application will be described in detail below with reference to the accompanying drawings. However, those skilled in the art will understand that many technical details have been provided in the various embodiments of this application to help readers better understand this application. However, the technical solutions claimed in this application can be implemented even without these technical details and various changes and modifications based on the following embodiments. The division of the various embodiments below is for the convenience of description and should not constitute any limitation on the specific implementation of this application. The various embodiments can be combined with and referenced by each other without contradiction.

[0062] It should be noted that the terms "first," "second," etc., in the specification, claims, and accompanying drawings of this disclosure are used to distinguish similar objects and are not necessarily used to describe a specific order or sequence. It should be understood that such data can be interchanged where appropriate so that the embodiments of this disclosure described herein can be implemented in orders other than those illustrated or described herein. Furthermore, the terms "comprising" and "having," and any variations thereof, are intended to cover non-exclusive inclusion; for example, a process, method, system, product, or apparatus that comprises a series of steps or units is not necessarily limited to those steps or units explicitly listed, but may include other steps or units not explicitly listed or inherent to such processes, methods, products, or apparatus.

[0063] It should be noted that the steps shown in the flowchart in the accompanying drawings can be executed in a computer system such as a set of computer-executable instructions, and although a logical order is shown in the flowchart, in some cases the steps shown or described may be executed in a different order than that shown here.

[0064] This invention proposes a method for evaluating the gas content of tight clastic rock reservoirs. The implementation details of the method for evaluating the gas content of tight clastic rock reservoirs in this embodiment are described below. The following content is only for the convenience of understanding and is not necessary for implementing this solution.

[0065] Example 1:

[0066] The specific procedure for evaluating the gas content of tight clastic rock reservoirs in this embodiment can be as follows: Figure 1 As shown, it includes:

[0067] Step 110: Obtain the first neutron logging curve, the first acoustic logging curve, and the unobstructed flow rate data for the test layer.

[0068] Specifically, neutron logging is a logging method that assesses formation characteristics by measuring the formation's ability to absorb neutrons. Neutron logging operations are performed using neutron logging instruments to obtain neutron logging data, which is then processed to obtain the first neutron logging curve for the test interval. Acoustic logging, on the other hand, assesses formation characteristics by measuring the propagation speed and time of sound waves in the formation. Acoustic logging operations are performed using acoustic logging instruments to obtain acoustic logging data, which is then processed to obtain the first acoustic logging curve for the test interval. Unobstructed flow rate refers to the maximum amount of gas a gas well can stably produce under certain conditions. In one example, unobstructed flow rate data is obtained through production capacity testing or production capacity simulation.

[0069] In some cases, production logging data and well logging data of the production well are obtained, test sections are determined based on the production logging data and well logging data, and the first neutron logging curve, the first sonic logging curve, and unobstructed flow data of the test section are obtained.

[0070] Furthermore, the natural gamma curve, caliper curve, and sonic curve are determined based on the production logging data and well logging data of the production well. The non-reservoir section is determined based on the natural gamma curve, caliper curve, and sonic curve. The test section is determined based on the non-reservoir section.

[0071] Step 120: Determine the second neutron logging curve and the second sonic logging curve of the standard mudstone section based on the first neutron logging curve and the first sonic logging curve of the test layer.

[0072] Specifically, by observing the first neutron logging curve, mudstone typically has a high hydrogen content, so the mudstone section is usually located in a low-value region in the neutron logging curve; and the sonic transit time of mudstone is usually small because mudstone has low porosity and high compaction. By observing the first sonic logging curve, mudstone sections can be identified, the corresponding sonic transit time values ​​can be extracted, and the second sonic logging curve of the standard mudstone section can be determined.

[0073] Step 130: Determine the first scale value of the compensating neutron and the second scale value of the compensating acoustic wave to minimize the first superposition area obtained by superimposing the second neutron logging curve and the second acoustic logging curve.

[0074] Specifically, the second neutron logging curve and the second acoustic logging curve are superimposed, and the scale values ​​of the second neutron logging curve and / or the second acoustic logging curve are adjusted to obtain the optimal combination that minimizes the first superposition area obtained by superimposing the second neutron logging curve and the second acoustic logging curve. That is, the first scale value of the compensating neutron and the second scale value of the compensating acoustic wave are determined to minimize the first superposition area obtained by superimposing the second neutron logging curve and the second acoustic logging curve.

[0075] Step 140: Based on the first scale value of the compensated neutron and the second scale value of the compensated acoustic wave, the first neutron logging curve and the first acoustic logging curve are superimposed to obtain the second superimposed area.

[0076] Specifically, the first neutron logging curve is calibrated based on the first scale value of the compensated neutron, and the first acoustic logging curve is corrected based on the second scale value of the compensated acoustic wave. The corrected first neutron logging curve and the first acoustic logging curve are then superimposed to obtain the second superimposed area.

[0077] In this embodiment, the first neutron logging curve and the first acoustic logging curve are superimposed based on the first scale value of the compensated neutron and the second scale value of the compensated acoustic wave to obtain the second superposition area. This avoids the problem of differences in the left and right scale values ​​of the neutron logging curve due to the inconsistency of lithology between the upper and lower surrounding rocks of the reservoir when directly superimposing the first neutron logging curve and the first acoustic logging curve.

[0078] Step 150: Establish a production prediction relationship based on the second overlapping area and the unobstructed flow data.

[0079] Specifically, statistical methods or machine learning algorithms are used to analyze the relationship between the second overlapping area and the unobstructed flow rate data. Based on the analysis results, a production prediction relationship is established based on the second overlapping area and the unobstructed flow rate data. The production prediction relationship can reflect the relationship between the second overlapping area and the unobstructed flow rate.

[0080] In some cases, the production forecast relationship is obtained by fitting the second overlapping area with the unobstructed flow rate data.

[0081] In some cases, yield prediction relationships are obtained by fitting the acoustic and neutron-bearing gas overlap area per unit thickness with unobstructed flow data.

[0082] Step 160: Evaluate the gas content of the reservoir in the test section based on the production prediction relationship.

[0083] Specifically, comprehensive logging data of the test section is obtained, and the superposition area value of acoustic and neutron gas-bearing is calculated based on the comprehensive logging data. The gas content of the reservoir in the test section is evaluated according to the production prediction relationship and in combination with the superposition area value of acoustic and neutron gas-bearing in the test section.

[0084] In this embodiment, conventional acoustic transit time and the influence of weather conditions on neutrons are utilized. Specifically, the response characteristics of increased acoustic logging curves and decreased neutron logging curve excavation effect caused by the presence of gas in the reservoir are used. The gas content of the reservoir is quantitatively characterized by the area of ​​overlap between the two curves. This is compared with unobstructed flow rate data to establish a fitting relationship between gas-bearing parameters and production. Based on this fitting relationship, the gas content of the reservoir is evaluated. The operation is simple, the fitting correlation coefficient is high, and the production capacity of fractured tight clastic gas reservoirs can be predicted. Compared with the existing method of overlapping neutron porosity and density porosity curves, this embodiment has better quantitative evaluation results and is less affected by pore structure and wellbore conditions.

[0085] Example 2:

[0086] Based on the above embodiments, the step of establishing a production prediction relationship based on the second overlapping area and the unobstructed flow data includes:

[0087] The acoustic and neutron-containing gas-bearing superposition area per unit thickness of the test layer is calculated based on the second superposition area.

[0088] The yield prediction relationship is obtained by fitting the acoustic wave and neutron-containing gas overlapping area per unit thickness with the unobstructed flow rate data.

[0089] In some embodiments, the acoustic and neutron-containing gas-bearing superposition area per unit thickness is the ratio of the second superposition area to the production capacity contribution thickness.

[0090] In some embodiments, the second overlapping area is the sum of the increase in acoustic waves caused by gas inclusion and the decrease in neutron logging curves caused by gas-bearing excavation effects.

[0091] In some embodiments, the expression for the acoustic wave and neutron-containing gas-bearing superposition area per unit thickness of the test layer is:

[0092]

[0093] Where A is the superposition area of ​​sound waves and neutron-containing gas, AC i -AC1 represents the increase in sound waves caused by gas content; CNL1-CNL iH represents the reduction in neutron logging curves caused by gas extraction effects; H represents the thickness of the test section contributing to productivity.

[0094] Specifically, ΔAC = AC - AC1 is the increase in acoustic waves caused by gas inclusion; ΔCNL = CNL - CNL1 is the decrease in neutron logging curve caused by gas inclusion exploitation effect.

[0095] The sum of the increase in acoustic wave intensity ΔAC and the decrease in the excavation effect ΔCNL is the overlapping area A of acoustic wave and neutron gas-bearing zone. The specific formula for this reservoir section, calculated using calculus, is as follows:

[0096]

[0097] The superposition area of ​​acoustic waves and neutron-containing gas per unit thickness is the ratio of the superposition area of ​​acoustic waves and neutron-containing gas to the thickness H contributing to the energy production of the test section.

[0098] Example 3:

[0099] Based on the above embodiments, the step of determining the second neutron logging curve and the second sonic logging curve of the standard mudstone section based on the first neutron logging curve and the first sonic logging curve of the test layer includes:

[0100] Obtain the natural gamma curve of the test layer;

[0101] The mudstone section without coal was determined based on the first neutron logging curve, the first sonic logging curve, and the natural gamma curve.

[0102] The neutron logging curve of the coal-free mudstone section is determined to be the second neutron logging curve of the standard mudstone section, and the sonic logging curve of the coal-free mudstone section is determined to be the second sonic logging curve of the standard mudstone section.

[0103] In some embodiments, the step of acquiring the first neutron logging curve, the first acoustic logging curve, and the unobstructed flow rate data of the test layer further includes:

[0104] Obtain the natural gamma curve, caliper curve, and sonic curve of the well to be logged;

[0105] The non-reservoir section is determined based on the natural gamma curve, caliper curve, and sonic curve of the well to be logged.

[0106] The test section is determined based on the non-reservoir layer, and the first neutron logging curve, the first sonic logging curve, and the unobstructed flow rate data of the test section are obtained.

[0107] Specifically, production logging data and well logging data from production wells are acquired, and mudstone formations near the test interval are selected based on the logging data. Further, natural gamma ray curves, caliper curves, and sonic logging curves are determined based on the logging data, and non-reservoir intervals are identified based on these curves. Standard mudstone intervals without coal are delineated by combining the characteristics of natural gamma ray curves, neutron logging curves, and sonic transit time curves. These standard mudstone intervals are then designated as mudstone formations near the test interval.

[0108] Example 4:

[0109] Based on the above embodiments, the step of determining the first scale value of the compensating neutron and the second scale value of the compensating acoustic wave to minimize the overlap area between the second neutron logging curve and the second acoustic logging curve includes:

[0110] The second neutron logging curve and the second acoustic logging curve are superimposed based on the calibration values ​​of the initial compensated neutron and the initial compensated acoustic wave.

[0111] Select the benchmark value of the superimposed overlap value of the second neutron logging curve and the second acoustic logging curve;

[0112] Based on the reference value of the overlap value of the compensated acoustic wave and the compensated neutron, the first scale value of the compensated neutron and the second scale value of the compensated acoustic wave are adjusted until the overlap area between the second neutron logging curve and the second acoustic wave logging curve is minimized.

[0113] Specifically, the calibration value of the compensating neutron and the reference value of the compensating neutron superposition overlap are determined based on the second neutron logging curve; the calibration value of the compensating acoustic wave and the reference value of the compensating acoustic wave superposition overlap are determined based on the second acoustic logging curve; wherein, the calibration value of the compensating acoustic wave is 120-20 μS / ft, and the calibration value of the compensating neutron is 60-0%; the reference values ​​of the compensating acoustic wave and the compensating neutron superposition overlap are selected, AC1 and CNL1, and the calibration values ​​of the compensating acoustic wave and the compensating neutron are adjusted to minimize or eliminate the acoustic-neutron superposition area in the mudstone formation section, thereby obtaining the first calibration value of the second neutron logging curve and the second calibration value of the second acoustic logging curve.

[0114] Example 5:

[0115] Another embodiment of this application relates to a method for quantitatively evaluating the gas content of tight sandstone reservoirs based on the acoustic-neutron superposition area, the specific process of which can be as follows: Figure 2 As shown, it includes the following steps:

[0116] Step S1: Obtain production logging data and well logging data from the production well, and select mudstone formations near the test section.

[0117] Step S2: Ensure that the acoustic-neutron overlap area is minimal or almost non-existent in the mudstone strata.

[0118] Step S3: Determine the superimposed area per unit thickness of the reservoir: Superimpose the acoustic-neutron curves of the reservoir section and calculate the superimposed area per unit thickness of the reservoir using calculus.

[0119] Step S4: Establish a regional reservoir productivity prediction model: Fit the relationship between the superimposed area per unit thickness of the reservoir and the unobstructed flow rate. Establish the relationship using the superimposed area per unit thickness of the reservoir and the unobstructed flow rate of the test section, and quantitatively evaluate the gas content of the reservoir based on the superimposed area per unit thickness.

[0120] Step S5: Verification of the effectiveness of the logging production capacity prediction method for tight clastic gas reservoirs.

[0121] In one example, step S1 includes:

[0122] Step S101: Determine the non-reservoir section based on the natural gamma curve, caliper curve, sonic curve, etc.

[0123] Step S102: Combine the characteristics of natural gamma curve, neutron logging curve, and sonic transit time curve to delineate standard mudstone sections that do not contain coal;

[0124] Step S103: Set the standard mudstone section as the mudstone stratum section near the test section.

[0125] In one example, step S2 includes:

[0126] Step S201: Compensate for acoustic wave scale value of 120-20 μs / ft, and compensate for neutron scale value of 60-0%.

[0127] Step S202: Select the reference values ​​AC1 and CNL1 for the superposition and overlap of the compensated acoustic wave and the compensated neutron;

[0128] Step S203: Adjust the calibration values ​​of the compensated acoustic wave and compensated neutron to minimize or eliminate the acoustic-neutron overlap area in the mudstone strata.

[0129] In an optional embodiment, the baseline values ​​for the superposition of compensated acoustic waves and compensated neutrons are selected as AC1 as 60 μS / ft and CNL1 as 8%. The scale values ​​of compensated acoustic waves and compensated neutrons are adjusted to minimize or eliminate the acoustic-neutron superposition area in the mudstone strata, such as adjusting the scale value of compensated acoustic waves to 90-25 μS / ft and the scale value of compensated neutrons to 50-0%.

[0130] In one example, step S3 includes:

[0131] Step S301: Calculate ΔAC = AC - AC1, which is the increase in sound waves caused by the presence of gas;

[0132] Step S302: Calculate ΔCNL = CNL - CNL1, which is the reduction in the neutron logging curve caused by the gas-bearing exploitation effect;

[0133] Step S303: The sum of the increase in acoustic wave ΔAC and the decrease in the mining effect ΔCNL is the overlapping area A of acoustic wave and neutron gas-bearing zone. The specific expression formula for the reservoir section is calculated using calculus:

[0134]

[0135] Where A is the superposition area of ​​sound waves and neutron-containing gas, AC i -AC1 represents the increase in acoustic wave amplitude caused by gas content; CNL1-CNL i H represents the reduction in neutron logging curves caused by gas extraction effects; H represents the thickness of the test section contributing to productivity.

[0136] Step S304: Calculate the superposition area of ​​acoustic waves and neutron-containing gas per unit thickness, that is, divide the value calculated in step 303 by the thickness H of the test section's energy contribution.

[0137] In one example, step S4 includes:

[0138] Step S401: Compare and analyze the test yield data to establish a fitting relationship curve between the unit thickness acoustic wave and neutron gas-bearing superposition area and the yield;

[0139] Step S402: The fitting curve of the superimposed area of ​​acoustic waves and neutron-bearing gas per unit thickness with production shows that the superimposed area of ​​acoustic waves and neutron-bearing gas per unit thickness in the reservoir section is positively correlated with production capacity. Based on the established fitting curve, the gas-bearing capacity of the reservoir is quantitatively evaluated using the calculated superimposed area of ​​acoustic waves and neutron-bearing gas per unit thickness.

[0140] In one example, the establishment of a regional reservoir productivity prediction model involves fitting the relationship between the superimposed area of ​​acoustic waves and neutron-bearing gas per unit thickness and the unobstructed flow rate as follows:

[0141] Q AOF = 0.6707 × exp(0.4094 × A)

[0142] Among them, Q AOF denoted as the superposition area of ​​acoustic waves and neutron-containing gas per unit thickness; A is the unobstructed flow rate.

[0143] In one example, step S5: Verification of the effectiveness of the logging production capacity prediction method for tight clastic gas reservoirs. Specifically, the acoustic and neutron-bearing overlapping area per unit thickness of the new well is extracted to predict the unobstructed flow rate of a single well. The single-well logging project includes comprehensive logging data. The acoustic and neutron-bearing overlapping area per unit thickness of the reservoir is calculated and statistically obtained. Based on the production prediction relationship, the unobstructed flow rate of a single well is predicted. The predicted results are compared and analyzed with the actual tested unobstructed flow rate to verify the accuracy of the logging production capacity prediction method for fractured tight clastic gas reservoirs in predicting unobstructed flow rate.

[0144] In this embodiment, based on the changes in conventional acoustic transit time and the influence of natural gas on compensated neutrons, the gas-bearing capacity of the reservoir is quantitatively characterized by the increase in acoustic logging curves and the decrease in the excavation effect of neutron logging curves caused by the presence of gas in the reservoir, using the size of the overlapping area of ​​the two curves. The relationship between gas-bearing parameters and production is established by comparing and analyzing the results with unobstructed flow rate data. This method is simple to operate, has a high correlation coefficient, and provides a new approach for the quantitative evaluation of reservoir gas-bearing capacity. It solves the problem of production capacity prediction for fractured tight clastic rock gas reservoirs, addressing the issues of low calculation accuracy and production capacity prediction in previous methods. This is of great significance for the production capacity construction and economic development of gas reservoir reserves.

[0145] Example 6:

[0146] Another embodiment of this application relates to a well logging production prediction method for fractured tight clastic gas reservoirs, applied to the CX work area of ​​the Sichuan Basin, which includes:

[0147] In the CX work area, production logging data and test data from production wells were acquired. Based on the production logging data, mudstone formations near the test sections were selected. The acoustic-neutron curves of the reservoir sections were superimposed to ensure that the acoustic-neutron superposition area of ​​the mudstone formation sections was minimized or almost non-existent. The relationship between the superposition area per unit thickness of the reservoir and the unobstructed flow rate of the test sections was fitted, and the gas content of the reservoir was quantitatively evaluated based on the superposition area per unit thickness of the reservoir.

[0148] The following two well examples will be used to verify this. Figures 3 to 7 As shown, the overlapping area per unit thickness of the reservoir in both wells was calculated. Using the relationship between the overlapping area per unit thickness and the unobstructed flow rate, the unobstructed flow rate of this well was predicted. The predicted value was then compared with the measured value (e.g., ...). Figure 5 and Figure 7 As shown in the figure, the effectiveness of the well logging production prediction method for tight clastic gas reservoirs is verified.

[0149] Furthermore, the superposition area of ​​acoustic waves and neutrons in the reservoir was calculated using calculus, thus determining the superposition area per unit thickness of the reservoir (see Formula 1 below); secondly, a graph showing the relationship between the superposition area per unit thickness of the reservoir and the reservoir's unobstructed flow rate was plotted (see Formula 1 below). Figure 3Based on the relationship between the superimposed area per unit thickness of the reservoir and the unobstructed flow rate, a formula for the relationship between the superimposed area per unit thickness of the reservoir and the unobstructed flow rate is fitted (see Formula 2 below).

[0150]

[0151] The diagram showing the relationship between the superimposed area per unit thickness of the reservoir and the unobstructed flow rate is presented. The unobstructed flow rate relationship is also shown.

[0152] Q AOF =0.6707×exp (0.4094×A) (2)

[0153] Furthermore, a reservoir productivity prediction model for the CX region was established.

[0154] In well A, 4900.0-4914.0m (see...) Figure 4 Based on the sonic-neutron log curve, the superimposed area per unit thickness was calculated to be 7.37. According to the relationship between reservoir comprehensive productivity index and unobstructed flow rate, the predicted unobstructed flow rate of well A was 137,119 m³ / day. The actual unobstructed flow rate measured during perforation testing at depths of 4900.0-4914.0 m was 142,830 m³ / day. A comparative analysis of the predicted and actual measured unobstructed flow rates confirmed the accuracy of the unobstructed flow rate prediction method for tight clastic gas reservoirs. The predicted unobstructed flow rate of well A was 137,119 m³ / day, and the actual measured unobstructed flow rate was 142,830 m³ / day; the predicted results are consistent with the actual results (see...). Figure 5 ).

[0155] In well B, at depths of 3229.0-3246.0m (see...) Figure 6 The calculated unit thickness overlap area is 8.19. Based on the relationship between reservoir comprehensive production capacity index and unobstructed flow rate, the predicted unobstructed flow rate of well B is 192,227 m³ / day. The actual measured unobstructed flow rate at depths of 3229.0-3246.0 m is 185,946 m³ / day. A comparative analysis of the predicted and actual measured unobstructed flow rates verifies the accuracy of the unobstructed flow rate prediction method for tight clastic gas reservoirs. The predicted unobstructed flow rate of well B is 192,227 m³ / day, and the actual measured unobstructed flow rate is 185,946 m³ / day; the predicted results are consistent with the actual results (see...). Figure 7 The correlation coefficient between the gas production (unhindered flow rate) of the Xujiahe Formation in the study area and the superimposed area per unit thickness of AC-CNL was found to be high, indicating that the reservoir fluid discrimination technology is feasible.

[0156] In this embodiment, based on the changes in conventional acoustic transit time and the influence of natural gas on compensated neutrons, the gas-bearing capacity of the reservoir is quantitatively characterized by the increase in acoustic logging curves and the decrease in the excavation effect of neutron logging curves caused by the presence of gas in the reservoir, using the size of the overlapping area of ​​the two curves. The relationship between gas-bearing parameters and production is established by comparing and analyzing the results with unobstructed flow rate data. This method is simple to operate, has a high correlation coefficient, and provides a new approach for the quantitative evaluation of reservoir gas-bearing capacity. It solves the problem of production capacity prediction for fractured tight clastic rock gas reservoirs, addressing the issues of low calculation accuracy and production capacity prediction in previous methods. This is of great significance for the production capacity construction and economic development of gas reservoir reserves.

[0157] Example 7:

[0158] Another embodiment of this application relates to a device for evaluating the gas-bearing capacity of tight clastic rock reservoirs. The implementation details of this device are described below. The following details are for ease of understanding and are not essential for implementing this solution. A schematic diagram of the device for evaluating the gas-bearing capacity of tight clastic rock reservoirs in this embodiment can be seen as follows: Figure 8 As shown, it includes an acquisition module 801, a first determination module 802, a second determination module 803, an overlay module 804, a relationship establishment module 805, and an evaluation module 806.

[0159] The acquisition module 801 is used to acquire the first neutron logging curve, the first acoustic logging curve, and the unobstructed flow rate data of the test layer.

[0160] The first determining module 802 is used to determine the second neutron logging curve and the second acoustic logging curve of the standard mudstone section based on the first neutron logging curve and the first acoustic logging curve of the test layer.

[0161] The second determining module 803 is used to determine the first scale value of the compensating neutron and the second scale value of the compensating acoustic wave so that the first superposition area obtained by superimposing the second neutron logging curve and the second acoustic logging curve is minimized.

[0162] The overlay module 804 is used to overlay the first neutron logging curve and the first acoustic logging curve based on the first scale value of the compensated neutron and the second scale value of the compensated acoustic wave to obtain a second overlay area.

[0163] Relationship establishment 805 is used to establish a production prediction relationship based on the second overlapping area and the unobstructed flow data.

[0164] Evaluation module 806 is used to evaluate the gas content of the reservoir in the test section based on the production prediction relationship.

[0165] In some optional embodiments, the relationship establishment 805 is also used to calculate the acoustic and neutron-containing gas-bearing superposition area per unit thickness of the test segment based on the second superposition area;

[0166] The yield prediction relationship is obtained by fitting the acoustic wave and neutron-containing gas overlapping area per unit thickness with the unobstructed flow rate data.

[0167] In some alternative embodiments, the acoustic and neutron-containing gas overlap area per unit thickness is the ratio of the second overlap area to the energy contribution thickness.

[0168] In some optional embodiments, the second overlapping area is the sum of the increase in acoustic waves caused by gas inclusion and the decrease in neutron logging curves caused by gas extraction effects.

[0169] In some optional embodiments, the expression for the acoustic wave and neutron-containing gas overlap area per unit thickness of the test layer is:

[0170]

[0171] Where A is the superposition area of ​​sound waves and neutron-containing gas, AC i -AC1 represents the increase in acoustic wave amplitude caused by gas content; CNL1-CNL i H represents the reduction in neutron logging curves caused by gas extraction effects; H represents the thickness of the test section contributing to productivity.

[0172] In some optional embodiments, the first determining module 802 is further configured to obtain the natural gamma curve of the test layer segment;

[0173] The mudstone section without coal was determined based on the first neutron logging curve, the first sonic logging curve, and the natural gamma curve.

[0174] The neutron logging curve of the coal-free mudstone section is determined to be the second neutron logging curve of the standard mudstone section, and the sonic logging curve of the coal-free mudstone section is determined to be the second sonic logging curve of the standard mudstone section.

[0175] In some optional embodiments, the second determining module 803 is further configured to superimpose the second neutron logging curve and the second acoustic logging curve based on the initial compensation neutron scale value and the initial compensation acoustic scale value;

[0176] Select the benchmark value of the superimposed overlap value of the second neutron logging curve and the second acoustic logging curve;

[0177] Based on the reference value of the overlap value of the compensated acoustic wave and the compensated neutron, the first scale value of the compensated neutron and the second scale value of the compensated acoustic wave are adjusted until the overlap area between the second neutron logging curve and the second acoustic wave logging curve is minimized.

[0178] In this embodiment, based on the changes in conventional acoustic transit time and the influence of natural gas on compensated neutrons, the gas-bearing capacity of the reservoir is quantitatively characterized by the increase in acoustic logging curves and the decrease in the excavation effect of neutron logging curves caused by the presence of gas in the reservoir, using the size of the overlapping area of ​​the two curves. The relationship between gas-bearing parameters and production is established by comparing and analyzing the results with unobstructed flow rate data. This method is simple to operate, has a high correlation coefficient, and provides a new approach for the quantitative evaluation of reservoir gas-bearing capacity. It solves the problem of production capacity prediction for fractured tight clastic rock gas reservoirs, addressing the issues of low calculation accuracy and production capacity prediction in previous methods. This is of great significance for the production capacity construction and economic development of gas reservoir reserves.

[0179] It is worth mentioning that all modules involved in this embodiment are logical modules. In practical applications, a logical unit can be a physical unit, a part of a physical unit, or a combination of multiple physical units. Furthermore, to highlight the innovative aspects of this application, this embodiment does not introduce units that are not closely related to solving the technical problems proposed in this application; however, this does not mean that other units are absent in this embodiment.

[0180] In the embodiments provided in this application, it should be understood that the disclosed apparatus and methods can also be implemented in other ways. The apparatus embodiments described above are merely illustrative. For example, the flowcharts and block diagrams in the accompanying drawings illustrate the architecture, functionality, and operation of possible implementations of apparatus, methods, and computer program products according to various embodiments of this disclosure. In this regard, each block in a flowchart or block diagram may represent a module, segment, or portion of code containing one or more executable instructions for implementing a specified logical function. It should also be noted that in some alternative implementations, the functions marked in the blocks may occur in a different order than those marked in the drawings. For example, two consecutive blocks may actually be executed substantially in parallel, and they may sometimes be executed in reverse order, depending on the functions involved. It should also be noted that each block in a block diagram and / or flowchart, and combinations of blocks in block diagrams and / or flowcharts, can be implemented using a dedicated hardware-based system that performs the specified function or action, or using a combination of dedicated hardware and computer instructions.

[0181] It should be noted that, in this disclosure, the terms "comprising," "including," or any other variations thereof are intended to cover non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements includes not only those elements but also other elements not expressly listed, or elements inherent to such a process, method, article, or apparatus. Without further limitation, an element limited by the phrase "comprising one..." does not exclude the presence of other identical elements in the process, method, article, or apparatus that includes that element.

[0182] Example 8:

[0183] Another embodiment of this application relates to an electronic device, such as... Figure 9 As shown, it includes: at least one processor; and a memory communicatively connected to the at least one processor; wherein the memory stores instructions executable by the at least one processor, the instructions being executed by the at least one processor to enable the at least one processor to perform the following steps:

[0184] Acquire the first neutron logging curve, the first acoustic logging curve, and the unobstructed flow rate data for the test layer;

[0185] Based on the first neutron logging curve and the first acoustic logging curve of the test layer, determine the second neutron logging curve and the second acoustic logging curve of the standard mudstone section.

[0186] Determine the first scale value of the compensating neutron and the second scale value of the compensating acoustic wave to minimize the first superposition area obtained by superimposing the second neutron logging curve and the second acoustic logging curve;

[0187] The first neutron logging curve and the first acoustic logging curve are superimposed based on the first scale value of the compensated neutron and the second scale value of the compensated acoustic wave to obtain the second superimposed area;

[0188] A production prediction relationship is established based on the second overlapping area and the unobstructed flow data;

[0189] The gas content of the reservoir in the test section is evaluated based on the aforementioned production prediction relationship.

[0190] In one embodiment, the processor, when executing a computer program, also performs the following steps:

[0191] The acoustic and neutron-containing gas-bearing superposition area per unit thickness of the test layer is calculated based on the second superposition area.

[0192] The yield prediction relationship is obtained by fitting the acoustic wave and neutron-containing gas overlapping area per unit thickness with the unobstructed flow rate data.

[0193] In one embodiment, the acoustic and neutron-containing gas-bearing superposition area per unit thickness is the ratio of the second superposition area to the production capacity contribution thickness.

[0194] In one embodiment, the second overlapping area is the sum of the increase in acoustic waves caused by gas inclusion and the decrease in neutron logging curves caused by gas extraction effects.

[0195] In one embodiment, the expression for the acoustic wave and neutron-containing gas-bearing superposition area per unit thickness of the test layer is:

[0196]

[0197] Where A is the superposition area of ​​sound waves and neutron-containing gas, AC i -AC1 represents the increase in acoustic wave amplitude caused by gas content; CNL1-CNL i H represents the reduction in neutron logging curves caused by gas extraction effects; H represents the thickness of the test section contributing to productivity.

[0198] In one embodiment, the processor, when executing a computer program, also performs the following steps:

[0199] Obtain the natural gamma curve of the test layer;

[0200] The mudstone section without coal was determined based on the first neutron logging curve, the first sonic logging curve, and the natural gamma curve.

[0201] The neutron logging curve of the coal-free mudstone section is determined to be the second neutron logging curve of the standard mudstone section, and the sonic logging curve of the coal-free mudstone section is determined to be the second sonic logging curve of the standard mudstone section.

[0202] In one embodiment, the processor, when executing a computer program, also performs the following steps:

[0203] The second neutron logging curve and the second acoustic logging curve are superimposed based on the calibration values ​​of the initial compensated neutron and the initial compensated acoustic wave.

[0204] Select the benchmark value of the superimposed overlap value of the second neutron logging curve and the second acoustic logging curve;

[0205] Based on the reference value of the overlap value of the compensated acoustic wave and the compensated neutron, the first scale value of the compensated neutron and the second scale value of the compensated acoustic wave are adjusted until the overlap area between the second neutron logging curve and the second acoustic wave logging curve is minimized.

[0206] The memory and processor are connected via a bus, which can include any number of interconnecting buses and bridges, connecting various circuits of one or more processors and memories. The bus can also connect various other circuits, such as peripheral devices, voltage regulators, and power management circuits, which are well known in the art and will not be described further herein. The bus interface provides an interface between the bus and the transceiver. The transceiver can be a single element or multiple elements, such as multiple receivers and transmitters, providing a unit for communicating with various other devices over a transmission medium. Data processed by the processor is transmitted over the wireless medium via an antenna, which further receives data and transmits it to the processor.

[0207] The processor manages the bus and general processing, and also provides various functions, including timing, peripheral interfaces, voltage regulation, power management, and other control functions. Memory is used to store data used by the processor during operation.

[0208] The processor may include, but is not limited to, one or more processors or microprocessors. Each processor may be implemented as an Application Specific Integrated Circuit (ASIC), Digital Signal Processor (DSP), Digital Signal Processing Device (DSPD), Programmable Logic Device (PLD), Field Programmable Gate Array (FPGA), controller, microcontroller, microprocessor, or other electronic component, for executing the methods in the above embodiments.

[0209] Example 9:

[0210] Another embodiment of this application relates to a computer-readable storage medium storing a computer program. When executed by a processor, the computer program performs the following steps:

[0211] Acquire the first neutron logging curve, the first acoustic logging curve, and the unobstructed flow rate data for the test layer;

[0212] Based on the first neutron logging curve and the first acoustic logging curve of the test layer, determine the second neutron logging curve and the second acoustic logging curve of the standard mudstone section.

[0213] Determine the first scale value of the compensating neutron and the second scale value of the compensating acoustic wave to minimize the first superposition area obtained by superimposing the second neutron logging curve and the second acoustic logging curve;

[0214] The first neutron logging curve and the first acoustic logging curve are superimposed based on the first scale value of the compensated neutron and the second scale value of the compensated acoustic wave to obtain the second superimposed area;

[0215] A production prediction relationship is established based on the second overlapping area and the unobstructed flow data;

[0216] The gas content of the reservoir in the test section is evaluated based on the aforementioned production prediction relationship.

[0217] In one embodiment, when the computer program is executed by a processor, it also performs the following steps:

[0218] The acoustic and neutron-containing gas-bearing superposition area per unit thickness of the test layer is calculated based on the second superposition area.

[0219] The yield prediction relationship is obtained by fitting the acoustic wave and neutron-containing gas overlapping area per unit thickness with the unobstructed flow rate data.

[0220] In one embodiment, the acoustic and neutron-containing gas-bearing superposition area per unit thickness is the ratio of the second superposition area to the production capacity contribution thickness.

[0221] In one embodiment, the second overlapping area is the sum of the increase in acoustic waves caused by gas inclusion and the decrease in neutron logging curves caused by gas extraction effects.

[0222] In one embodiment, the expression for the acoustic wave and neutron-containing gas-bearing superposition area per unit thickness of the test layer is:

[0223]

[0224] Where A is the superposition area of ​​sound waves and neutron-containing gas, AC i -AC1 represents the increase in acoustic wave amplitude caused by gas content; CNL1-CNL i H represents the reduction in neutron logging curves caused by gas extraction effects; H represents the thickness of the test section contributing to productivity.

[0225] In one embodiment, when the computer program is executed by a processor, it also performs the following steps:

[0226] Obtain the natural gamma curve of the test layer;

[0227] The mudstone section without coal was determined based on the first neutron logging curve, the first sonic logging curve, and the natural gamma curve.

[0228] The neutron logging curve of the coal-free mudstone section is determined to be the second neutron logging curve of the standard mudstone section, and the sonic logging curve of the coal-free mudstone section is determined to be the second sonic logging curve of the standard mudstone section.

[0229] In one embodiment, when the computer program is executed by a processor, it also performs the following steps:

[0230] The second neutron logging curve and the second acoustic logging curve are superimposed based on the calibration values ​​of the initial compensated neutron and the initial compensated acoustic wave.

[0231] Select the benchmark value of the superimposed overlap value of the second neutron logging curve and the second acoustic logging curve;

[0232] Based on the reference value of the overlap value of the compensated acoustic wave and the compensated neutron, the first scale value of the compensated neutron and the second scale value of the compensated acoustic wave are adjusted until the overlap area between the second neutron logging curve and the second acoustic wave logging curve is minimized.

[0233] That is, those skilled in the art will understand that all or part of the steps in the methods of the above embodiments can be implemented by a program instructing related hardware. This program is stored in a storage medium and includes several instructions to cause a device (which may be a microcontroller, chip, etc.) or processor to execute all or part of the steps of the methods described in the various embodiments of this application. The aforementioned storage medium includes various media capable of storing program code, such as USB flash drives, portable hard drives, read-only memory (ROM), random access memory (RAM), magnetic disks, or optical disks.

[0234] Computer-readable storage media may also store at least one computer-executable program / instruction, such as computer-readable instructions. Computer-readable storage media include, but are not limited to, volatile memory and / or non-volatile memory. Volatile memory may include, for example, random access memory (RAM) and / or cache memory. Computer-readable storage media may include, for example, read-only memory (ROM), hard disk, flash memory, etc. For example, a non-transitory computer-readable storage medium may be connected to a computing device such as a computer, and then, when the computing device executes the computer-readable instructions stored on the computer-readable storage medium, the various methods described above can be performed.

[0235] In addition, the computer device may include (but is not limited to) a data bus, an input / output (I / O) bus, a display, and input / output devices (e.g., keyboard, mouse, speakers, etc.).

[0236] The processor can communicate with external devices via the I / O bus through wired or wireless networks.

[0237] Those skilled in the art will understand that the above embodiments are specific embodiments for implementing this application, and in practical applications, various changes can be made to them in form and detail without departing from the spirit and scope of this application.

Claims

1. A method for evaluating the gas content of tight clastic rock reservoirs, characterized in that, include: Acquire the first neutron logging curve, the first acoustic logging curve, and the unobstructed flow rate data for the test layer; Based on the first neutron logging curve and the first acoustic logging curve of the test layer, determine the second neutron logging curve and the second acoustic logging curve of the standard mudstone section. Determine the first scale value of the compensating neutron and the second scale value of the compensating acoustic wave to minimize the first superposition area obtained by superimposing the second neutron logging curve and the second acoustic logging curve; The first neutron logging curve and the first acoustic logging curve are superimposed based on the first scale value of the compensated neutron and the second scale value of the compensated acoustic wave to obtain the second superimposed area; A production prediction relationship is established based on the second overlapping area and the unobstructed flow data; The gas content of the reservoir in the test section is evaluated based on the aforementioned production prediction relationship.

2. The method for evaluating the gas content of tight clastic rock reservoirs according to claim 1, characterized in that, The step of establishing a production forecast relationship based on the second overlapping area and the unobstructed flow data includes: The acoustic and neutron-containing gas-bearing superposition area per unit thickness of the test layer is calculated based on the second superposition area. The yield prediction relationship is obtained by fitting the acoustic wave and neutron-containing gas overlapping area per unit thickness with the unobstructed flow rate data.

3. The method for evaluating the gas content of tight clastic rock reservoirs according to claim 2, characterized in that, The superposition area of ​​acoustic waves and neutron-containing gas per unit thickness is the ratio of the second superposition area to the thickness contributing to energy production.

4. The method for evaluating the gas content of tight clastic rock reservoirs according to claim 1, characterized in that, The second overlapping area is the sum of the increase in acoustic waves caused by gas inclusion and the decrease in neutron logging curves caused by gas inclusion excavation effect.

5. The method for evaluating the gas content of tight clastic rock reservoirs according to claim 3, characterized in that, The expression for the acoustic wave and neutron-containing gas-bearing superposition area per unit thickness of the test layer is as follows: Where A is the superposition area of ​​sound waves and neutron-containing gas, AC i -AC1 represents the increase in sound waves caused by gas content; CNL1-CNL i H represents the reduction in neutron logging curves caused by gas extraction effects; H represents the thickness of the test section contributing to productivity.

6. The method for evaluating the gas content of tight clastic rock reservoirs according to any one of claims 1-5, characterized in that, The steps for determining the second neutron logging curve and the second sonic logging curve of the standard mudstone section based on the first neutron logging curve and the first sonic logging curve of the test layer include: Obtain the natural gamma curve of the test layer; The mudstone section without coal was determined based on the first neutron logging curve, the first sonic logging curve, and the natural gamma curve. The neutron logging curve of the coal-free mudstone section is determined to be the second neutron logging curve of the standard mudstone section, and the sonic logging curve of the coal-free mudstone section is determined to be the second sonic logging curve of the standard mudstone section.

7. The method for evaluating the gas content of tight clastic rock reservoirs according to any one of claims 1-5, characterized in that, The step of determining the first scale value of the compensated neutron and the second scale value of the compensated acoustic wave to minimize the first superposition area obtained by superimposing the second neutron logging curve and the second acoustic logging curve includes: The second neutron logging curve and the second acoustic logging curve are superimposed based on the calibration values ​​of the initial compensated neutron and the initial compensated acoustic wave. Select the benchmark value of the superimposed overlap value of the second neutron logging curve and the second acoustic logging curve; Based on the reference value of the overlap value of the compensated acoustic wave and the compensated neutron, the first scale value of the compensated neutron and the second scale value of the compensated acoustic wave are adjusted until the overlap area between the second neutron logging curve and the second acoustic wave logging curve is minimized.

8. A device for evaluating the gas content of tight clastic rock reservoirs, characterized in that, include: The acquisition module is used to acquire the first neutron logging curve, the first acoustic logging curve, and the unobstructed flow rate data of the test layer. The first determining module is used to determine the second neutron logging curve and the second acoustic logging curve of the standard mudstone section based on the first neutron logging curve and the first acoustic logging curve of the test layer. The second determining module is used to determine the first scale value of the compensating neutron and the second scale value of the compensating acoustic wave when the first superposition area obtained by superimposing the second neutron logging curve and the second acoustic logging curve is minimized. The overlay module is used to overlay the first neutron logging curve and the first acoustic logging curve based on the first scale value of the compensated neutron and the second scale value of the compensated acoustic wave to obtain a second overlay area. The relationship establishment module is used to establish a production prediction relationship based on the second overlapping area and the unobstructed flow data; The evaluation module is used to evaluate the gas content of the reservoir in the test section based on the production prediction relationship.

9. An electronic device, characterized in that, include: At least one processor; as well as, A memory communicatively connected to the at least one processor; wherein, The memory stores instructions that can be executed by the at least one processor to enable the at least one processor to perform the gas-bearing evaluation method for tight clastic reservoirs as described in any one of claims 1 to 7.

10. A computer-readable storage medium storing a computer program, characterized in that, When the computer program is executed by the processor, it implements the gas-bearing evaluation method for tight clastic rock reservoirs as described in any one of claims 1 to 7.

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