Biogas logging identification method and device, medium and electronic equipment

Abstract

The invention discloses a biogas logging identification method and device, a medium and electronic equipment. The method comprises the steps that coring observation is conducted on the coal measure strata, seismic data and logging data are combined, geological layering is conducted on the coal measure strata, and the geological layering is used for eliminating the influence of the space structure of the coal measure strata on an acoustic logging curve; an acoustic logging curve of the coal measure stratum is obtained, and borehole environment correction is conducted on the interval transit time corresponding to the acoustic logging curve; establishing a cross plot according to the corrected acoustic logging curve and a neutron gamma curve obtained by analyzing measured data; based on the cross plot, a gas reservoir fitting curve is obtained, and the gas reservoir fitting curve is used for recognizing a gas reservoir in the coal measure strata. The accuracy of identifying the gas reservoir in the coal measure stratum can be improved.

Description

Background Art

[0002] Biogas is an unconventional natural gas resource. With the increasing demand for conventional oil and gas resources and their production, the development and utilization of unconventional oil and gas resources has attracted widespread attention from countries around the world, and biogas as a clean energy has therefore received much attention.

[0003] The coal-bearing biogas layer has logging response characteristics such as low volume density, high acoustic time difference, high compensated neutron value, low natural gamma value, and high resistivity value. Therefore, the logging curve in the coal-bearing strata is easily affected by many factors. Based on this, how to improve the accuracy of identifying gas layers in coal-bearing strata is a technical problem that needs to be solved urgently. Summary of the invention

[0004] The purpose of the present application is to provide a biogas logging identification method, device, medium and electronic equipment. The present application can improve the accuracy of identifying gas layers in coal-bearing strata.

[0005] Other features and advantages of the present application will become apparent from the following detailed description, or may be learned in part by the practice of the present application.

[0006] According to one aspect of an embodiment of the present application, a method for well logging identification of biogas is provided, characterized in that the method includes: conducting geological stratification of the coal-bearing strata by coring observations of the coal-bearing strata and combining seismic data and well logging data, the geological stratification being used to eliminate the influence of the spatial structure of the coal-bearing strata on the acoustic logging curve; obtaining the acoustic logging curve of the coal-bearing strata, and performing wellbore environment correction on the acoustic time difference corresponding to the acoustic logging curve; establishing an intersection diagram based on the corrected acoustic logging curve and the neutron gamma curve obtained by analyzing the measured data; and obtaining a gas layer fitting curve based on the intersection diagram, the gas layer fitting curve being used to identify the gas layer in the coal-bearing strata.

[0007] In one embodiment of the present application, based on the above solution, the acoustic time difference corresponding to the acoustic logging curve is corrected for the borehole environment by the following formula:

[0008] TA=Tma×(1―SH)+Tsh×SH

[0009] Among them, TA is the corrected acoustic time difference; Tma is the average acoustic time difference value of pure formation; Tsh is the acoustic time difference value of mudstone; SH is the mud content of coal-bearing formation.

[0010] In one embodiment of the present application, based on the aforementioned scheme, an intersection diagram is established according to the corrected sonic logging curve and the neutron gamma curve obtained by analyzing the measured data, including: obtaining a gas layer identification factor by analyzing the compensated neutron porosity curve, the gas layer identification factor being the ratio of the mudstone compensated neutron porosity in the compensated neutron porosity curve to the gas layer compensated neutron porosity value in the compensated neutron porosity curve; and establishing the intersection diagram according to the sonic logging curve, the neutron gamma curve and the gas layer identification factor.

[0011] In one embodiment of the present application, based on the aforementioned scheme, the acoustic time difference corresponding to the acoustic logging curve is corrected for the wellbore environment, including: obtaining the drill bit diameter and wellbore caliper logging curves, and based on the wellbore caliper logging curves, obtaining the wellbore caliper and expansion value of the wellbore; if the acoustic time difference is greater than the corrected acoustic time difference, and the difference between the wellbore caliper and the drill bit diameter is greater than the expansion value, then the corrected acoustic time difference is used as the new acoustic time difference.

[0012] In one embodiment of the present application, based on the above-mentioned scheme, the wellbore environment correction of the acoustic wave time difference corresponding to the acoustic logging curve includes: if the acoustic wave time difference is less than or equal to the corrected acoustic wave time difference, maintaining the current acoustic wave time difference.

[0013] In one embodiment of the present application, based on the aforementioned scheme, the wellbore environment correction of the acoustic time difference corresponding to the acoustic logging curve includes: obtaining the natural gamma curve value and the wellbore diameter of the coal-bearing formation; if the starting point and the ending point corresponding to the natural gamma curve value, the wellbore diameter, and the acoustic time difference are different, then obtaining the target segment with the same starting point and the same ending point corresponding to the natural gamma curve value, the wellbore diameter, and the acoustic time difference, and correcting the acoustic time difference for the target segment.

[0014] According to one aspect of an embodiment of the present application, a biogas logging identification device is provided, characterized in that the device includes: an analysis unit, used to perform geological stratification on the coal-bearing strata by coring and observing the coal-bearing strata in combination with seismic data and logging data, the geological stratification being used to eliminate the influence of the spatial structure of the coal-bearing strata on the acoustic logging curve; a correction unit, used to obtain the acoustic logging curve of the coal-bearing strata, and perform borehole environment correction on the acoustic time difference corresponding to the acoustic logging curve; a construction unit, used to establish an intersection diagram based on the corrected acoustic logging curve and a neutron gamma curve obtained by analyzing measured data; an identification unit, used to obtain a gas layer fitting curve based on the intersection diagram, the gas layer fitting curve being used to identify the gas layer in the coal-bearing strata.

[0015] In one embodiment of the present application, based on the aforementioned scheme, the correction unit is also used to: obtain the drill bit diameter and wellbore diameter logging curves, and based on the wellbore diameter logging curves, obtain the wellbore diameter and expansion value of the wellbore; if the acoustic wave time difference is greater than the corrected acoustic wave time difference, and the difference between the wellbore diameter and the drill bit diameter is greater than the expansion value, then the corrected acoustic wave time difference is used as the new acoustic wave time difference.

[0016] According to one aspect of an embodiment of the present application, a computer-readable storage medium is provided, on which a computer program is stored. The computer program includes executable instructions. When the executable instructions are executed by a processor, the method described in the above embodiment is implemented.

[0017] According to one aspect of an embodiment of the present application, an electronic device is provided, comprising: one or more processors; and a memory for storing executable instructions of the processors, wherein when the executable instructions are executed by the one or more processors, the one or more processors implement the methods described in the above embodiments.

[0018] In the technical solution of the embodiment of the present application, the coal-bearing strata are geologically stratified by coring observations of known wells within or around the regional range of the coal-bearing strata and combining seismic data and logging data. This ensures that the logging identification of the gas layer is carried out under the same geological conditions, so as to eliminate the influence of structural conditions and sedimentary conditions brought about by different stratifications on the acoustic logging curve corresponding to the coal-bearing strata.

[0019] Then, the sonic logging curve of the coal-bearing stratum is obtained, and the sonic time difference corresponding to the sonic logging curve is corrected for the borehole environment. By correcting the sonic time difference, the accuracy of the sonic logging curve in detecting the coal-bearing stratum can be improved, thereby improving the accuracy of identifying the gas layer of biogas. In the process of correcting the sonic time difference, the change of the sonic time difference caused by the change of the well diameter can be analyzed by combining the well logging curve of the drill bit diameter and the well diameter, so as to further improve the accuracy of the sonic logging curve in detecting the coal-bearing stratum.

[0020] Based on the sonic logging curve, combined with the neutron gamma curve obtained by analyzing the measured data, a cross plot is established to obtain a gas layer fitting curve, so as to identify the gas layer in the coal-bearing stratum according to the gas layer fitting curve. Wherein, when the hydrogen content of the neutron gamma curve is small, the value corresponding to the neutron gamma curve increases, and when the hydrogen content of the stratum is large, the value corresponding to the neutron gamma curve decreases.

[0021] Therefore, the biogas logging identification method described in this application can improve the accuracy of identifying gas layers in coal-bearing strata, thereby providing guidance for subsequent well site deployment and development and exploitation work.

[0022] It should be understood that the foregoing general description and the following detailed description are exemplary and explanatory only and are not restrictive of the present application. BRIEF DESCRIPTION OF THE DRAWINGS

[0023] The drawings herein are incorporated into the specification and constitute a part of the specification, showing embodiments consistent with the present application, and together with the specification, are used to explain the principles of the present application. Obviously, the drawings described below are only some embodiments of the present application, and for ordinary technicians in this field, other drawings can be obtained based on these drawings without creative work. In the drawings:

[0024] Figure 1 It is a flow chart of a method for well logging identification of biogas according to an embodiment of the present application;

[0025] Figure 2 A comparison diagram of natural gamma curve values, well diameters, and sonic logging curves according to an embodiment of the present application;

[0026] Figure 3 It is a cross-sectional diagram shown according to an embodiment of the present application;

[0027] Figure 4 It is a block diagram of a biogas logging identification device according to an embodiment of the present application;

[0028] Figure 5 It is a schematic diagram of the system structure of an electronic device according to an embodiment of the present application. DETAILED DESCRIPTION

[0029] Example embodiments will now be described more fully with reference to the accompanying drawings. However, example embodiments can be implemented in a variety of forms and should not be construed as limited to the examples set forth herein; rather, these embodiments are provided so that this application will be more comprehensive and complete and fully convey the concept of the example embodiments to those skilled in the art.

[0030] In addition, described feature, structure or characteristic can be combined in one or more embodiments in any suitable manner. In the following description, many specific details are provided to provide a full understanding of the embodiments of the present application. However, those skilled in the art will appreciate that the technical scheme of the present application can be put into practice without one or more of the specific details, or other methods, components, devices, steps, etc. can be adopted. In other cases, known methods, devices, realizations or operations are not shown or described in detail to avoid blurring the various aspects of the application.

[0031] The block diagrams shown in the accompanying drawings are merely functional entities and do not necessarily correspond to physically independent entities. That is, these functional entities may be implemented in software form, or in one or more hardware modules or integrated circuits, or in different networks and / or processor devices and / or microcontroller devices.

[0032] The flowcharts shown in the accompanying drawings are only exemplary and do not necessarily include all the contents and operations / steps, nor must they be executed in the order described. For example, some operations / steps can be decomposed, and some operations / steps can be combined or partially combined, so the actual execution order may change according to actual conditions.

[0033] It should be noted that the "multiple" mentioned in this article refers to two or more. "And / or" describes the association relationship of the associated objects, indicating that there can be three relationships. For example, A and / or B can mean: A exists alone, A and B exist at the same time, and B exists alone. The character " / " generally indicates that the associated objects before and after are in an "or" relationship.

[0034] The implementation details of the technical solution of the embodiment of the present application are described in detail below:

[0035] According to one aspect of the present application, a method for well logging identification of biogas is provided. Figure 1 The flowchart of the biogas logging identification method according to the embodiment of the present application is shown. The biogas logging identification method can be executed by a device with a computing and processing function. The biogas logging identification method includes at least steps 110 to 140, which are described in detail as follows:

[0036] In step 110, the coal-bearing strata are geologically stratified by coring and observing the coal-bearing strata and combining the seismic data and the logging data. The geological stratification is used to eliminate the influence of the spatial structure of the coal-bearing strata on the acoustic logging curve.

[0037] In the present application, the coal-bearing strata are geologically stratified by coring observations of known wells within or around the coal-bearing strata and combining seismic data and logging data, thereby ensuring logging identification of gas layers under the same geological conditions to eliminate the influence of structural conditions and sedimentary conditions on the acoustic logging curves due to different stratifications in the coal-bearing strata.

[0038] Specifically, when conducting geological stratification of the coal-bearing strata, the coal-bearing strata can be divided into three sub-segments based on seismic data and well logging data, combined with the occurrence and geological lithology combination of the coal-bearing strata, wherein, from bottom to top, they are respectively the lower sub-segment, the middle sub-segment and the upper sub-segment.

[0039] For example, in a specific embodiment, the lithology of the lower sub-section is mainly brown-red sandstone or intercalated with brown-red mudstone or thin-layer volcanic rock sediments, and the structural belt of the lower sub-section is mainly oil-bearing strata. The lithology of the middle sub-section is mainly pure and thick dark mudstone, among which the eastern slope belt and the western slope belt have marginal phase sandstone and sandstone conglomerate sediments. In addition, the dark mudstone in the middle sub-section has good hydrocarbon generation ability, and the dark mudstone is mainly oil-generating rock. The upper sub-section is mainly dark gray mudstone intercalated with light gray, black gray siltstone, sandstone, coal seam, and carbonaceous mudstone.

[0040] Continue to refer to Figure 1 In step 120, the sonic logging curve of the coal-bearing stratum is obtained, and the sonic time difference corresponding to the sonic logging curve is corrected for the wellbore environment.

[0041] In the present application, after the geological stratification of the coal-bearing strata is completed, the sonic logging curve of the coal-bearing strata is obtained, wherein the sonic logging curve can be used to identify gas layers and oil layers in the strata. Before identifying the gas layer based on the sonic logging curve, the sonic logging curve can be corrected to improve the accuracy of identifying the gas layer by the sonic logging curve.

[0042] Furthermore, in one embodiment of the present application, the acoustic time difference corresponding to the acoustic logging curve is corrected for the borehole environment by the following formula:

[0043] TA=Tma×(1―SH)+Tsh×SH

[0044] Among them, TA is the corrected acoustic time difference; Tma is the average acoustic time difference value of pure formation; Tsh is the acoustic time difference value of mudstone; SH is the mud content of coal-bearing formation.

[0045] Specifically, during the drilling process, the collapse of the wellbore will cause the wellbore diameter to increase, and at the same time, the wellbore wall will be uneven, thereby affecting the accuracy of the acoustic logging curve in identifying the gas layer. In addition, the impact of the above-mentioned recognition accuracy caused by the wellbore collapse is a random impact. Therefore, the acoustic time difference corresponding to the acoustic logging curve can be corrected by using an approximate value or an estimated method.

[0046] Furthermore, in one embodiment of the present application, the shale content of the coal-bearing stratum is calculated by the following formula:

[0047]

[0048]

[0049] Among them, SH is the mud content of coal-bearing strata; GR is the natural gamma curve value; GRmin is the minimum value within the correction depth range; GRmax is the maximum value within the correction depth range.

[0050] In one embodiment of the present application, the performing of borehole environment correction on the acoustic time difference corresponding to the acoustic logging curve specifically includes steps 121 to 122:

[0051] Step 121, obtaining the drill bit diameter and the wellbore caliper logging curve, and based on the wellbore caliper logging curve, obtaining the wellbore caliper and the expansion value of the wellbore.

[0052] Step 122: If the acoustic wave time difference is greater than the corrected acoustic wave time difference, and the difference between the well diameter and the drill bit diameter is greater than the diameter expansion value, the corrected acoustic wave time difference is used as a new acoustic wave time difference.

[0053] In this embodiment, in order to improve the correction accuracy of the acoustic logging curve during the correction process of the acoustic logging curve, first, the drill bit diameter and the wellbore caliper logging curve can be obtained, and the wellbore caliper and the diameter expansion value can be obtained based on the wellbore caliper logging curve. Then, according to the obtained drill bit diameter, the wellbore caliper and the diameter expansion value, the acoustic time difference corresponding to the acoustic logging curve is corrected and analyzed.

[0054] If the acoustic time difference corresponding to the acoustic logging curve is greater than the corrected acoustic time difference, and the difference between the well diameter and the drill bit diameter is greater than the diameter expansion value, it means that the increase in the acoustic time difference corresponding to the acoustic logging curve is caused by the expansion of the well diameter due to the collapse of the wellbore during the drilling process. Therefore, the correction of the acoustic logging curve can be achieved by using the corrected acoustic time difference obtained by using an approximate value or an estimated method as the acoustic time difference corresponding to the acoustic logging curve.

[0055] Furthermore, the performing borehole environment correction on the acoustic time difference corresponding to the acoustic logging curve includes: if the acoustic time difference is less than or equal to the corrected acoustic time difference, maintaining the current acoustic time difference.

[0056] Specifically, if the acoustic time difference is less than or equal to the corrected acoustic time difference, it means that the acoustic time difference corresponding to the acoustic logging curve is not affected by the diameter expansion value of the wellbore. Therefore, the current acoustic time difference can be maintained without correcting the acoustic time difference corresponding to the acoustic logging curve.

[0057] Furthermore, the wellbore environment correction of the sonic time difference corresponding to the sonic logging curve includes: obtaining the natural gamma curve value and the wellbore diameter of the coal-bearing stratum; if the starting point and the ending point corresponding to the natural gamma curve value, the wellbore diameter, and the sonic time difference are different, obtaining a target segment having the same starting point and the same ending point corresponding to the natural gamma curve value, the wellbore diameter, and the sonic time difference, and correcting the sonic time difference for the target segment.

[0058] Specifically, refer to Figure 2 , is a comparison diagram of the natural gamma curve value, well diameter, and sonic logging curve according to an embodiment of the present application. In the process of correcting the sonic time difference corresponding to the sonic logging curve, if the natural gamma curve value, well diameter, and the starting point and the ending point of the sonic time difference corresponding to the sonic logging curve are different, it is necessary to obtain a target segment with the same starting point and the ending point according to the natural gamma curve value, well diameter, and the sonic time difference corresponding to the sonic logging curve, so as to correct the sonic time difference for the target segment, wherein curve AC is the sonic logging curve, curve GR is the natural gamma curve, and curve CAL is the well diameter logging curve.

[0059] Continue to refer to Figure 1 In step 130, a cross plot is established based on the corrected acoustic logging curve and the neutron gamma curve obtained by analyzing the measured data.

[0060] In the present application, the neutron gamma curve has the following characteristics: when the hydrogen content of the formation is small, the value corresponding to the neutron gamma curve increases, and when the hydrogen content of the formation is large, the value corresponding to the neutron gamma curve decreases. At the same time, compared with the oil and water in the formation, the density of hydrogen in the gas layer in the formation is very small. At the same porosity, the hydrogen content in the gas layer is much smaller than that in the oil layer and the water layer. Therefore, in the gas layer, the neutron gamma curve has a higher value, which can be used to identify and divide the gas layer and water layer in the coal-bearing formation. In addition, the identification and division of the gas layer and the water layer in the coal-bearing formation by the neutron gamma curve can reduce the influence of the identification accuracy caused by the mineral composition of the reservoir and the spatial structure of the reservoir.

[0061] In one embodiment of the present application, the cross-plot is established based on the corrected acoustic logging curve and the neutron gamma curve obtained by analyzing the measured data, specifically including steps 131 to 132:

[0062] Step 131, by analyzing the compensated neutron porosity curve, a gas layer identification factor is obtained, wherein the gas layer identification factor is the ratio of the mudstone compensated neutron porosity in the compensated neutron porosity curve to the gas layer compensated neutron porosity value in the compensated neutron porosity curve.

[0063] Step 132: establishing the cross-plot according to the sonic logging curve, the neutron gamma curve and the gas layer identification factor.

[0064] In this embodiment, in order to further improve the fit of the cross-plot and improve the accuracy of the present application in identifying the gas layer in the coal-bearing stratum, a compensated neutron porosity curve is obtained in the process of establishing the cross-plot. Since the compensated neutron porosity curve has the characteristic of significantly reducing the value at the gas layer, in order to further enhance the identifiability of the gas layer, the compensated neutron porosity curve at the mudstone is selected as the base value, and the ratio of the mudstone base value to the compensated neutron porosity corresponding to the gas layer is obtained, thereby obtaining the gas layer identification factor.

[0065] In addition, since the value range of the neutron gamma curve in practical applications is generally 0-2, and the amplitude of the curve value is small. It is difficult to highlight the difference between gas layers and non-gas layers during the intersection identification process. The compensated neutron curve has a better distinguishing effect on gas layers, so the gain neutron gamma value can be obtained according to the gas layer identification factor and the neutron gamma curve. Among them, the gain neutron gamma value is the product of the gas layer identification factor and the value corresponding to the neutron gamma curve. Based on the gain neutron gamma value, the deficiency of the small amplitude of the neutron gamma curve can be compensated. Therefore, after establishing an intersection diagram according to the sonic logging curve and the gain neutron gamma value, the amplitude of the sonic logging curve at the gas layer can be highlighted, thereby improving the accuracy of the intersection diagram for gas layer identification.

[0066] Continue to refer to Figure 1 In step 140, a gas layer fitting curve is obtained based on the intersection diagram, and the gas layer fitting curve is used to identify the gas layer in the coal-bearing stratum.

[0067] In the present application, after establishing the intersection diagram, a gas layer fitting curve can be obtained according to the intersection diagram and the regression curve fitting method, so that the gas layer of the coal-bearing stratum can be identified according to the gas layer fitting curve.

[0068] Reference Figure 3 , is a cross-sectional diagram according to an embodiment of the present application. Figure 3 It can be known that B is the gain neutron gamma value. According to the characteristics that the value of the neutron gamma curve increases with the decrease of the hydrogen content of the formation, and the value of the neutron gamma curve decreases with the increase of the hydrogen content of the formation, and combined with the acoustic logging curve that is sensitive to the gas layer and the gain neutron gamma value, a cross-plot for identifying the gas layer in the coal-bearing formation is established. Then, by constructing the gas layer fitting curve based on the measured data on the cross-plot, the gas-bearing area and the water-bearing area of ​​the coal-bearing formation can be intuitively divided in the plane. At the same time, based on this, a judgment basis for the gas-bearing and water-bearing properties of the coal-bearing formation that has not been actually detected can be provided to achieve the identification of the gas layer.

[0069] The following describes an apparatus embodiment of the present application, which can be used to perform the biogas logging identification method in the above-mentioned embodiment of the present application. For details not disclosed in the apparatus embodiment of the present application, please refer to the above-mentioned embodiment of the biogas logging identification method in the present application.

[0070] Figure 4 It is a block diagram of a biogas logging identification device according to an embodiment of the present application.

[0071] Reference Figure 4 As shown, according to an embodiment of the present application, a biogas logging identification device 400, the device 400 includes: an analysis unit 401, which is used to perform geological stratification on the coal-bearing strata by coring and observing the coal-bearing strata and combining seismic data and logging data, and the geological stratification is used to eliminate the influence of the spatial structure of the coal-bearing strata on the acoustic logging curve; a correction unit 402, which is used to obtain the acoustic logging curve of the coal-bearing strata and perform borehole environment correction on the acoustic time difference corresponding to the acoustic logging curve; a construction unit 403, which is used to establish an intersection diagram based on the corrected acoustic logging curve and the neutron gamma curve obtained by analyzing the measured data; an identification unit 404, which is used to obtain a gas layer fitting curve based on the intersection diagram, and the gas layer fitting curve is used to identify the gas layer in the coal-bearing strata.

[0072] Among them, the correction unit 402 is also used to: obtain the drill bit diameter and well diameter logging curves, and based on the well diameter logging curves, obtain the wellbore diameter and expansion value of the wellbore; if the acoustic wave time difference is greater than the corrected acoustic wave time difference, and the difference between the well diameter and the drill bit diameter is greater than the expansion value, then the corrected acoustic wave time difference is used as the new acoustic wave time difference.

[0073] As another aspect, the present application further provides a computer-readable storage medium on which a program product capable of implementing the above method of the present specification is stored. In some possible implementations, various aspects of the present application may also be implemented in the form of a program product, which includes a program code, and when the program product is run on a terminal device, the program code is used to enable the terminal device to execute the steps according to various exemplary implementations of the present application described in the above "Exemplary Method" section of the present specification.

[0074] Computer readable signal media may include data signals propagated in baseband or as part of a carrier wave, in which readable program code is carried. Such propagated data signals may take a variety of forms, including but not limited to electromagnetic signals, optical signals, or any suitable combination of the above. Readable signal media may also be any readable medium other than a readable storage medium, which may send, propagate, or transmit a program for use by or in conjunction with an instruction execution system, apparatus, or device.

[0075] The program code embodied on the readable medium may be transmitted using any appropriate medium, including but not limited to wireless, wired, optical cable, RF, etc., or any suitable combination of the foregoing.

[0076] Program code for performing the operations of the present application may be written in any combination of one or more programming languages, including object-oriented programming languages ​​such as Java, C++, etc., and conventional procedural programming languages ​​such as "C" or similar programming languages. The program code may be executed entirely on the user computing device, partially on the user device, as a separate software package, partially on the user computing device and partially on a remote computing device, or entirely on a remote computing device or server. In the case of a remote computing device, the remote computing device may be connected to the user computing device through any type of network, including a local area network (LAN) or a wide area network (WAN), or may be connected to an external computing device (e.g., using an Internet service provider to connect through the Internet).

[0077] As another aspect, the present application also provides an electronic device capable of implementing the above method.

[0078] Those skilled in the art will appreciate that various aspects of the present application may be implemented as a system, method or program product. Therefore, various aspects of the present application may be specifically implemented in the following forms, namely: a complete hardware implementation, a complete software implementation (including firmware, microcode, etc.), or a combination of hardware and software, which may be collectively referred to as "circuit", "module" or "system" herein.

[0079] Figure 5 The schematic diagram of the system structure of the electronic device according to the embodiment of the present application is shown below. Figure 5 The electronic device 500 according to this embodiment of the present application is described. Figure 5 The electronic device 500 shown is merely an example and should not bring any limitation to the functions and scope of use of the embodiments of the present application.

[0080] like Figure 5As shown, the electronic device 500 is in the form of a general computing device. The components of the electronic device 500 may include but are not limited to: at least one processing unit 510, at least one storage unit 520, and a bus 530 connecting different system components (including the storage unit 520 and the processing unit 510).

[0081] The storage unit stores program codes, which can be executed by the processing unit 510, so that the processing unit 510 executes the steps described in the above “Example Method” section of this specification according to various exemplary implementations of the present application.

[0082] The storage unit 520 may include a readable medium in the form of a volatile storage unit, such as a random access memory unit (RAM) 521 and / or a cache memory unit 522 , and may further include a read-only memory unit (ROM) 523 .

[0083] The storage unit 520 may also include a program / utility 524 having a set (at least one) of program modules 525, such program modules 525 including but not limited to: an operating system, one or more application programs, other program modules, and program data, each of which or some combination may include an implementation of a network environment.

[0084] Bus 530 may represent one or more of several types of bus structures, including a memory unit bus or memory unit controller, a peripheral bus, an accelerated graphics port, a processing unit, or a local bus using any of a variety of bus architectures.

[0085] The electronic device 500 may also communicate with one or more external devices 1200 (e.g., keyboards, pointing devices, Bluetooth devices, etc.), may also communicate with one or more devices that enable a user to interact with the electronic device 500, and / or communicate with any device that enables the electronic device 500 to communicate with one or more other computing devices (e.g., routers, modems, etc.). Such communication may be performed via an input / output (I / O) interface 550. In addition, the electronic device 500 may also communicate with one or more networks (e.g., local area networks (LANs), wide area networks (WANs), and / or public networks, such as the Internet) via a network adapter 560. As shown, the network adapter 560 communicates with other modules of the electronic device 500 via a bus 530. It should be understood that, although not shown in the figure, other hardware and / or software modules may be used in conjunction with the electronic device 500, including but not limited to: microcode, device drivers, redundant processing units, external disk drive arrays, RAID systems, tape drives, and data backup storage systems.

[0086] Through the description of the above implementation methods, it is easy for those skilled in the art to understand that the example implementation methods described here can be implemented by software or by combining software with necessary hardware. Therefore, the technical solution according to the implementation methods of the present application can be embodied in the form of a software product, which can be stored in a non-volatile storage medium (which can be a CD-ROM, a USB flash drive, a mobile hard disk, etc.) or on a network, and includes several instructions to enable a computing device (which can be a personal computer, a server, a terminal device, or a network device, etc.) to execute the method according to the implementation methods of the present application.

[0087] In addition, the above-mentioned figures are only schematic illustrations of the processes included in the method according to the exemplary embodiments of the present application, and are not intended to be limiting. It is easy to understand that the processes shown in the above-mentioned figures do not indicate or limit the time sequence of these processes. In addition, it is also easy to understand that these processes can be performed synchronously or asynchronously, for example, in multiple modules.

[0088] It should be understood that the present application is not limited to the precise structures that have been described above and shown in the drawings, and that various modifications and changes may be performed without departing from the scope thereof. The scope of the present application is limited only by the appended claims.

Claims

1. A biogas logging identification method, characterized in that: The method comprises: By coring and observing the coal-bearing strata, and combining seismic data and logging data, the coal-bearing strata are geologically layered, and the geological layering is used to eliminate the influence of the spatial structure of the coal-bearing strata on the acoustic logging curve; Acquiring the sonic logging curve of the coal-bearing stratum, and performing wellbore environment correction on the sonic time difference corresponding to the sonic logging curve; Establishing a crossplot based on the corrected sonic logging curve and the neutron gamma curve obtained by analyzing the measured data; Based on the intersection diagram, a gas layer fitting curve is obtained, and the gas layer fitting curve is used to identify the gas layer in the coal-bearing stratum.

2. The method according to claim 1, characterized in that The acoustic time difference corresponding to the acoustic logging curve is corrected for the borehole environment by the following formula: TA=Tma×(1―SH)+Tsh×SH Among them, TA is the corrected acoustic time difference; Tma is the average acoustic time difference value of pure formation; Tsh is the acoustic time difference value of mudstone; SH is the mud content of coal-bearing formation.

3. The method according to claim 1, characterized in that The method of establishing a cross-plot based on the corrected acoustic logging curve and the neutron gamma curve obtained by analyzing the measured data includes: By analyzing the compensated neutron porosity curve, a gas layer identification factor is obtained, wherein the gas layer identification factor is the ratio of the mudstone compensated neutron porosity in the compensated neutron porosity curve to the gas layer compensated neutron porosity value in the compensated neutron porosity curve; The cross-plot is established according to the sonic logging curve, the neutron gamma curve and the gas layer identification factor.

4. The method according to claim 1, characterized in that: The performing borehole environment correction on the acoustic time difference corresponding to the acoustic logging curve comprises: Obtaining a drill bit diameter and a wellbore caliper logging curve, and obtaining a wellbore caliper and a diameter expansion value based on the wellbore caliper logging curve; If the acoustic wave time difference is greater than the corrected acoustic wave time difference, and the difference between the well diameter and the drill bit diameter is greater than the diameter expansion value, the corrected acoustic wave time difference is used as a new acoustic wave time difference.

5. The method according to claim 1, characterized in that The performing borehole environment correction on the acoustic time difference corresponding to the acoustic logging curve comprises: If the acoustic wave time difference is less than or equal to the corrected acoustic wave time difference, the current acoustic wave time difference is maintained.

6. The method according to claim 1, characterized in that The performing borehole environment correction on the acoustic time difference corresponding to the acoustic logging curve comprises: Obtaining the natural gamma curve value and well diameter of the coal-bearing stratum; If the starting point and the ending point corresponding to the natural gamma curve value, the well diameter, and the acoustic wave time difference are different, obtain a target segment having the same starting point and the same ending point corresponding to the natural gamma curve value, the well diameter, and the acoustic wave time difference, and perform acoustic wave time difference correction on the target segment.

7. A biogas logging identification device, characterized in that: The device comprises: An analysis unit is used to perform geological stratification of the coal-bearing strata by coring and observing the coal-bearing strata and combining seismic data and logging data, wherein the geological stratification is used to eliminate the influence of the spatial structure of the coal-bearing strata on the acoustic logging curve; A correction unit, used for obtaining the sonic logging curve of the coal-bearing stratum and performing wellbore environment correction on the sonic time difference corresponding to the sonic logging curve; A construction unit, used to establish a cross-plot based on the corrected acoustic logging curve and the neutron gamma curve obtained by analyzing the measured data; An identification unit is used to obtain a gas layer fitting curve based on the intersection diagram, and the gas layer fitting curve is used to identify the gas layer in the coal-bearing stratum.

8. The device according to claim 7, characterized in that The correction unit is also used to: obtain the drill bit diameter and well diameter logging curves, and based on the well diameter logging curves, obtain the wellbore diameter and diameter expansion value of the wellbore; if the acoustic wave time difference is greater than the corrected acoustic wave time difference, and the difference between the well diameter and the drill bit diameter is greater than the diameter expansion value, then the corrected acoustic wave time difference is used as the new acoustic wave time difference.

9. A computer-readable storage medium, characterized in that: The computer-readable storage medium stores at least one program code, and the at least one program code is loaded and executed by a processor to implement the operations performed by the method according to any one of claims 1 to 6.

10. An electronic device, characterized in that: The electronic device includes one or more processors and one or more memories, wherein the one or more memories store at least one program code, and the at least one program code is loaded and executed by the one or more processors to implement the operations performed by the method according to any one of claims 1 to 6.

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