Fault sealing evaluation method, device and equipment

Abstract

The present disclosure provides a fault sealing evaluation method, device, and apparatus, relating to oil and gas exploration technology, comprising: obtaining basic data of a test well; obtaining pressure recovery data; determining a pressure derivative double logarithmic curve based on the basic data and the pressure recovery data; determining whether the shape of the pressure derivative double logarithmic curve presents a horizontal feature or a concave feature based on a preset template curve; if the pressure derivative double logarithmic curve presents a horizontal feature, the fault is determined to be sealed; if the pressure derivative double logarithmic curve presents a concave feature, the fault is determined to have flow conductivity. The pressure derivative double logarithmic curve can be constructed using the basic data and pressure recovery data obtained from the test well; then, by comparing the shape of the pressure derivative double logarithmic curve with the preset template curve, an evaluation of the fault sealing is obtained when the test well is located at a special position along the extension line of the fault.

Description

Technical Field

[0001] The present disclosure relates to oil and gas exploration technology, and in particular to a method, device, and equipment for evaluating the sealing performance of a fault. Background Art

[0002] Faults play a crucial role in oil and gas development, primarily in two ways: Fault openings serve as pathways for the migration of oil, gas, and water, improving reservoir properties but also creating the risk of communicating with marginal and bottom water. Fault sealing controls the extent of reserves, influences reserve utilization, and inhibits the advance of marginal and bottom water. Therefore, research on fault sealing is crucial for guiding oil and gas field development.

[0003] Currently, there are two main approaches to studying fault sealing, both domestically and internationally. Static methods include the mudstone smear coefficient method and cross-sectional stress analysis. Dynamic methods, based primarily on fluid seepage theory, are widely used in oil and gas reservoir engineering. Furthermore, since the development phase of an oil and gas reservoir provides more testing and production data than the exploration phase, using dynamic methods to determine the role of faults provides more direct verification.

[0004] Existing studies include a closed fault (such as Figure 1a However, the situation where the well and the fault are in the same straight line (i.e., the special position of the well on the extension line of the fault) has not been discussed, such as Figure 1b As shown in Figure 2, this situation has already been encountered during oilfield development in gas fields such as Yaha and Akmomu. This unique spatial relative position of faults and wells amplifies their impact on oil and gas field development. However, there is currently no dynamic method for evaluating fault sealing in this specific location. Summary of the Invention

[0005] The present disclosure provides a fault sealing evaluation method, device, and apparatus to solve the problem that there is no dynamic method for evaluating the fault sealing at such a special location in the prior art.

[0006] According to a first aspect of the present disclosure, a method for evaluating fault sealing is provided, wherein a test well is located on an extension line of the fault, and the method comprises:

[0007] Acquire basic data of the test well; wherein the basic data is used to represent status information of the test well;

[0008] Obtaining pressure recovery data, including the cumulative shut-in time and the temperature and pressure at each time point during the shut-in test;

[0009] determining a pressure derivative double logarithmic curve according to the basic data and the pressure recovery data;

[0010] Determining, based on a preset template curve, whether the shape of the pressure derivative double logarithmic curve presents a horizontal feature or a concave feature;

[0011] If the double logarithmic curve of the pressure derivative shows a horizontal feature, it is determined that the fault is closed;

[0012] If the double logarithmic curve of the pressure derivative shows a concave feature, it is determined that the fault has conductivity.

[0013] In one achievable manner, the basic data includes at least: wellbore diameter, oil and gas reservoir thickness, porosity, volume coefficient of reservoir oil and gas, oil and gas viscosity, and comprehensive compressibility coefficient of the reservoir.

[0014] In one achievable manner, before obtaining the basic data of the test well, the method further includes:

[0015] Obtaining the spatial positions of the test well and the fault;

[0016] Determining a numerical model based on the spatial position of the test well and the fault; the numerical model is used to simulate pressure changes after the well is shut in;

[0017] The preset template curve is determined according to the numerical model.

[0018] In one achievable manner, determining the numerical model according to the test well and the spatial position of the fault includes:

[0019] determining a gas reservoir physical model according to the test well and the spatial position of the fault;

[0020] The numerical model is determined according to the gas reservoir physical model and the dynamic and static parameters of the oil and gas reservoir.

[0021] According to a second aspect of the present disclosure, a fault sealing evaluation device is provided, wherein a test well is located on an extension line of the fault, and the device comprises:

[0022] An acquisition unit, configured to acquire basic data of a test well; wherein the basic data is used to represent status information of the test well;

[0023] The acquisition unit is further used to acquire pressure recovery data, wherein the pressure recovery data includes the cumulative shut-in time and the temperature and pressure at each time point during the shut-in test;

[0024] a processing unit, configured to determine a pressure derivative double logarithmic curve based on the basic data and the pressure recovery data;

[0025] a judgment unit, configured to determine, based on a preset template curve, whether the shape of the pressure derivative double logarithmic curve presents a horizontal feature or a concave feature;

[0026] a determining unit, configured to determine that the fault is closed if the double logarithmic curve of the pressure derivative presents a horizontal feature;

[0027] The determination unit is further configured to determine that the fault has conductivity if the double logarithmic curve of the pressure derivative presents a concave feature.

[0028] In one achievable manner, the basic data includes at least: wellbore diameter, oil and gas reservoir thickness, porosity, volume coefficient of reservoir oil and gas, oil and gas viscosity, and comprehensive compressibility coefficient of the reservoir.

[0029] In one possible implementation, before the acquiring unit, the method further includes:

[0030] a template determination unit, configured to obtain the spatial positions of the test well and the fault;

[0031] The template determination unit is further used to determine a numerical model based on the spatial position of the test well and the fault; the numerical model is used to simulate the pressure change after the well is shut in;

[0032] The template determination unit is further configured to determine the preset template curve according to the numerical model.

[0033] In one implementable manner, the template determining unit is further configured to:

[0034] determining a gas reservoir physical model according to the test well and the spatial position of the fault;

[0035] The numerical model is determined according to the gas reservoir physical model and the dynamic and static parameters of the oil and gas reservoir.

[0036] According to a third aspect of the present disclosure, an electronic device is provided, comprising a memory and a processor; wherein,

[0037] The memory is used to store computer programs;

[0038] The processor is configured to read the computer program stored in the memory and execute the fault sealing evaluation method as described in the first aspect according to the computer program in the memory.

[0039] According to a fourth aspect of the present disclosure, a computer-readable storage medium is provided, wherein the computer-readable storage medium stores computer-executable instructions. When a processor executes the computer-executable instructions, the fault sealing evaluation method as described in the first aspect is implemented.

[0040] According to a fifth aspect of the present disclosure, a computer program product is provided, comprising a computer program. When the computer program is executed by a processor, the fault sealing evaluation method as described in the first aspect is implemented.

[0041] The present disclosure provides a method, device, and apparatus for evaluating the sealing properties of a fault, including: obtaining basic data of a test well; wherein the basic data is used to characterize the state information of the test well; obtaining pressure recovery data, which includes the cumulative shut-in time and the temperature and pressure at each time point during the shut-in test; determining a pressure derivative double logarithmic curve based on the basic data and the pressure recovery data; and determining whether the shape of the pressure derivative double logarithmic curve presents a horizontal feature or a concave feature based on a preset template curve; if the pressure derivative double logarithmic curve presents a horizontal feature, the fault is determined to be sealed; if the pressure derivative double logarithmic curve presents a concave feature, the fault is determined to have conductivity. In this solution, a pressure derivative double logarithmic curve can be constructed using the basic data and pressure recovery data of the test well; and then, by comparing the shape of the pressure derivative double logarithmic curve with the preset template curve, an evaluation of the sealing properties of the fault can be obtained when the test well is located at a special position such as the extension line of the fault. BRIEF DESCRIPTION OF THE DRAWINGS

[0042] Figure 1a A schematic diagram of a straight line fault is shown in an exemplary embodiment of the present disclosure;

[0043] Figure 1b A schematic diagram of a special position where a well and a fault are in a straight line is shown in an exemplary embodiment of the present disclosure;

[0044] Figure 2 This is a flow chart of a fault sealing evaluation method according to an exemplary embodiment of the present disclosure;

[0045] Figure 3 A schematic diagram of a double logarithmic curve of pressure recovery of the YH-X well is shown in an exemplary embodiment of the present disclosure;

[0046] Figure 4 A schematic diagram of a double logarithmic curve of pressure recovery of the YH-X well is shown as another exemplary embodiment of the present disclosure;

[0047] Figure 5 This is a flow chart of a fault sealing evaluation method according to another exemplary embodiment of the present disclosure;

[0048] Figure 6 A characteristic diagram of a double logarithmic curve of homogeneous reservoir pressure recovery is shown in an exemplary embodiment of the present disclosure;

[0049] Figure 7 This is a characteristic diagram of a double logarithmic curve of fracture reservoir pressure recovery according to an exemplary embodiment of the present disclosure;

[0050] Figure 8 This is a schematic diagram of the pressure field distribution after shutting in a closed fault according to an exemplary embodiment of the present disclosure;

[0051] Figure 9 This is a schematic diagram of the pressure field distribution after shutting in a leaking fault according to an exemplary embodiment of the present disclosure;

[0052] Figure 10 This is a characteristic diagram of a double logarithmic curve of closed fault pressure recovery according to an exemplary embodiment of the present disclosure;

[0053] Figure 11 This is a characteristic diagram of a double logarithmic curve of leakage fault pressure recovery according to an exemplary embodiment of the present disclosure;

[0054] Figure 12 This is a structural diagram of a fault sealing evaluation device according to an exemplary embodiment of the present disclosure;

[0055] Figure 13 This is a structural diagram of a fault sealing evaluation device according to another exemplary embodiment of the present disclosure;

[0056] Figure 14 This is a structural diagram of an electronic device according to an exemplary embodiment of the present disclosure. DETAILED DESCRIPTION

[0057] Faults play a crucial role in oil and gas development, primarily in two ways: Fault openings serve as pathways for the migration of oil, gas, and water, improving reservoir properties but also creating the risk of communicating with marginal and bottom water. Fault sealing controls the extent of reserves, influences reserve utilization, and inhibits the advance of marginal and bottom water. Therefore, research on fault sealing is crucial for guiding oil and gas field development.

[0058] Currently, there are two main approaches to studying fault sealing, both domestically and internationally. Static methods include the mudstone smear coefficient method and cross-sectional stress analysis. Dynamic methods, based primarily on fluid seepage theory, are widely used in oil and gas reservoir engineering. Furthermore, since the development phase of an oil and gas reservoir provides more testing and production data than the exploration phase, using dynamic methods to determine the role of faults provides more direct verification.

[0059] The unstable well test double logarithmic curve fault model that has been derived and solved includes a closed fault (such as Figure 1a However, the situation where the well and the fault are in the same straight line (i.e., the special position of the well on the extension line of the fault) has not been discussed, such as Figure 1b As shown in Figure 2, this situation has already been encountered during oilfield development in gas fields such as Yaha and Akmomu. This unique spatial relative position of faults and wells amplifies their impact on oil and gas field development. However, there is currently no dynamic method for evaluating fault sealing in this specific location.

[0060] In order to solve the above technical problems, the solution provided in the present disclosure can construct a pressure derivative double logarithmic curve by obtaining the basic data and pressure recovery data of the test well; then, by comparing the morphology of the pressure derivative double logarithmic curve with the preset template curve, an evaluation of the fault sealing performance when the test well is at a special position such as the extension line of the fault can be obtained.

[0061] Figure 2 This is a flow chart of a fault sealing evaluation method according to an exemplary embodiment of the present disclosure, wherein the test well is located on the extension line of the fault.

[0062] like Figure 2 As shown, the fault sealing evaluation method provided in this embodiment includes:

[0063] Step 201 : obtaining basic data of the test well; wherein the basic data is used to represent status information of the test well.

[0064] The method provided in the present disclosure may be executed by an electronic device with computing capabilities, such as a computer, etc. The electronic device may be capable of acquiring basic data of the test well.

[0065] Among them, the basic data of the test well represents the status information of the test well, such as the wellbore diameter, oil and gas reservoir thickness, porosity, volume coefficient of reservoir oil and gas, oil and gas viscosity, comprehensive compression coefficient of the reservoir and other information.

[0066] Specifically, the basic data of the test well can be obtained from the test well completion geological summary report, oil test summary report, and block development plan.

[0067] Step 202: Obtain pressure recovery data, which includes the cumulative shut-in time and the temperature and pressure at each time point during the shut-in test.

[0068] Specifically, during the shut-in test of the test well, the pressure gauge can be used to obtain temperature and pressure data at various time points at the mid-depth position of the reservoir.

[0069] Step 203: Determine a pressure derivative double logarithmic curve based on the basic data and the pressure recovery data.

[0070] Specifically, in this embodiment, the shut-in test of the test well measures the pressure change at a mid-depth position in the reservoir after the well is shut in, and a pressure derivative curve, i.e., a double logarithmic pressure derivative curve, is obtained based on the pressure change. Specifically, the pressure change can be processed using third-party software to obtain the double logarithmic pressure derivative curve, such as the reservoir flow dynamics analysis software platform (Ecrin), the well testing software PanSystem, or the office software Excel.

[0071] Step 204 : Determine, based on a preset template curve, whether the shape of the pressure derivative double logarithmic curve presents a horizontal feature or a concave feature.

[0072] Specifically, step 205a or step 205b may be executed after step 204.

[0073] The preset template curve is a pre-derived double-logarithmic curve suitable for specific locations where the well and fault are aligned (i.e., the well is located on an extension of the fault). This preset template curve displays the curve characteristics of both fault closure and fault conductivity. Using this preset template curve as a reference, the double-logarithmic pressure derivative curve of the test well can be compared with the preset template curve to determine if there are similarities in morphological characteristics. This can then be used to further determine whether the fault is closed or conductive based on the curve characteristics of the double-logarithmic pressure derivative curve of the test well.

[0074] Step 205a: If the double logarithmic curve of the pressure derivative shows a horizontal feature, it is determined that the fault is closed.

[0075] Step 205b: If the double logarithmic curve of the pressure derivative shows a concave feature, it is determined that the fault has conductivity.

[0076] Specifically, taking the YH-X well in the Yaha condensate gas field as an example, the edge water breakthrough time of the YH-X well is significantly earlier than that of other edge production wells, proving that the fault has the ability to conduct flow, allowing the edge water to break through. Its sealing performance is poor, and it is a leaking fault. The double logarithmic curve of its pressure derivative shows a certain degree of concavity, as shown in Figure 2. Figure 3 The double logarithmic curve of YH-X well and Figure 4 The double logarithmic curve of well YH-X is shown as an example.

[0077] The present disclosure provides a method for evaluating the sealing properties of a fault, including: obtaining basic data of a test well; wherein the basic data is used to characterize the state information of the test well; obtaining pressure recovery data, which includes the cumulative shut-in time and the temperature and pressure at each time point during the shut-in test; determining a pressure derivative double logarithmic curve based on the basic data and the pressure recovery data; and determining whether the shape of the pressure derivative double logarithmic curve exhibits a horizontal or concave characteristic based on a preset template curve; if the pressure derivative double logarithmic curve exhibits a horizontal characteristic, the fault is determined to be sealed; if the pressure derivative double logarithmic curve exhibits a concave characteristic, the fault is determined to have flow conductivity. In this solution, a pressure derivative double logarithmic curve can be constructed using the basic data and pressure recovery data of the test well; and then, by comparing the shape of the pressure derivative double logarithmic curve with the preset template curve, an evaluation of the sealing properties of the fault can be obtained when the test well is located at a special position along the extension line of the fault.

[0078] Figure 5This is a flow chart of a fault sealing evaluation method according to another exemplary embodiment of the present disclosure, wherein the test well is located on the extension line of the fault.

[0079] like Figure 5 As shown, the fault sealing evaluation method provided in this embodiment includes:

[0080] Step 501: Acquire the spatial positions of the test well and the fault.

[0081] The spatial location of the test well and the fault may include the following information: the length of the fault, the shortest distance between the fault and the test well, the wellbore diameter of the test well, the thickness of the oil and gas reservoir, the formation dip, etc.

[0082] Specifically, the information on the spatial location of the test well and the fault can be obtained from the structural well location map of the test well and the block development plan.

[0083] Step 502: Determine a numerical model based on the spatial location of the test well and the fault; the numerical model is used to simulate pressure changes after the well is shut in.

[0084] Specifically, a numerical model is determined based on the special situation where the test well and the fault are in a straight line (i.e., the well is on the extension line of the fault). The numerical model is used to simulate the pressure changes after the well is shut in.

[0085] Optionally, determining a physical model of the gas reservoir based on the spatial location of the test wells and faults;

[0086] Specifically, according to the special position of the test well and the fault in a straight line (that is, the well is on the extension line of the fault), the physical model of the gas reservoir can be determined according to the spatial position of the test well and the fault, and then qualitative prediction can be made using existing mature theories.

[0087] Specifically, the existing mature theory mainly includes the following information: For example, taking the YH-X well in the Yaha condensate gas field as an example, when the fault has conductivity, the seepage field can be simplified into two parts: the first part is the homogeneous oil and gas reservoir, which accounts for α / 2π of the energy supply. The double logarithmic curve in the radial flow stage shows a horizontal feature, such as Figure 6 As shown (i.e., the double logarithmic curve characteristics of the homogeneous reservoir); in the second part, the fluid flows to the fault and then flows within the fault. The fault is equivalent to a large crack. This flow form is similar to the flow of a double-porosity and double-permeability oil and gas reservoir, accounting for (2π-α) / 2π of the energy supply. In the radial flow stage, the pressure derivative curve decreases in the early stage and rises again in the later stage, forming a "concave", as shown in Figure 7 As shown (i.e., double logarithmic curve characteristics of fracture reservoir).

[0088] Furthermore, according to the principle of potential superposition, when the well and the conductive fault are in the same straight line (i.e., the well is on the extension line of the fault), the composite characteristics of the above two should appear, that is, the curve will appear slightly concave.

[0089] If the special position where the well and the fault are in a straight line (i.e. the well is on the extension line of the fault) is a closed fault, there will be no fluid flowing in the fault. Compared with the entire reservoir, the fault volume is small, and the interference with the radial flow seepage field can be basically ignored. Its double logarithmic curve should be consistent with the homogeneous curve, such as Figure 6 shown.

[0090] The numerical model is determined based on the physical model of the gas reservoir and the dynamic and static parameters of the oil and gas reservoir.

[0091] Specifically, the numerical model is used to simulate the pressure changes after well shut-in.

[0092] The physical model of the gas reservoir may include at least the following information: fault length, the shortest distance between the fault and the test well, the wellbore diameter of the test well, the thickness of the oil and gas reservoir, the formation dip, etc.

[0093] Among them, the static parameters in the dynamic and static parameters of the oil and gas reservoir can at least include the wellbore diameter, oil and gas reservoir thickness, porosity, and comprehensive compression coefficient of the reservoir; the dynamic parameters in the dynamic and static parameters of the oil and gas reservoir can at least include the volume coefficient and oil and gas viscosity of the reservoir oil and gas.

[0094] As for the judgment of no conductivity, it can be seen from the pressure field distribution that the fault at this special position has almost no effect on the pressure field distribution, such as Figure 8 As shown (i.e. pressure field distribution after closing the well and sealing the fault).

[0095] In the case of faults with conductivity, it is first necessary to complete the modeling of the faults with conductivity. Currently, there are only three states for describing faults in numerical well testing modeling software: semi-closed, unclosed, and fully closed. There is no modeling function for faults with conductivity. Because faults have similar effects to fractures when they have conductivity, this numerical model establishment is the first attempt to use fracturing wells instead of faults to characterize their conductivity. The specific operation is: the half-length of the fracture in the double-wing fracture fracturing well (modeling tools are already available in the Ecrin software) is half the length of the fault, that is, the double-wing fracture is consistent with the full length of the fault; the fracturing well is set to the shut-in state; the fracture is set to infinite conductivity or the fracture is set to finite conductivity based on other existing test data. In this case, only the fracture in the pressure well tool is effective and plays a role in affecting the fluid distribution in the actual model. The above steps complete the description of the fracture for the fault with conductivity. In numerical simulation operations, the fault exhibits a strong flow capacity. The fluid first flows into the fault, flows along the fault direction, and then flows into the bottom of the well. Figure 9As shown in Figure 2, it is consistent with the actual expected results (i.e., the pressure field distribution after the leakage fault is shut in). The double logarithmic curves of the pressure derivative obtained from the two tests also show different characteristics. The double logarithmic curve of the pressure derivative of the closed fault shows a horizontal feature, as shown in Figure 2. Figure 10 (i.e., double logarithmic curve characteristics of the pressure derivative of the closed fault). The leakage fault shows a concave feature, and the closer the fault is to the well and the longer the fault is, the earlier the concave feature appears and the more obvious it is; the farther the fault is from the well and the shorter the fault is, the later the concave feature appears and the smaller the concave amplitude is. Figure 11 As shown (i.e., double logarithmic curve characteristics of leakage fault pressure derivative).

[0096] Step 503: Determine a preset template curve according to the numerical model.

[0097] Specifically, the numerical model is used to simulate the pressure change after the well is shut in, and the data model can output a double logarithmic curve (such as Figure 11 The double logarithmic curve is the preset template curve.

[0098] Step 504: Acquire basic data of the test well; wherein the basic data is used to represent status information of the test well.

[0099] Optionally, the basic data includes at least: wellbore diameter, oil and gas reservoir thickness, porosity, volume coefficient of reservoir oil and gas, oil and gas viscosity, and comprehensive compressibility coefficient of the reservoir.

[0100] Step 505: Obtain pressure recovery data, which includes the cumulative shut-in time and the temperature and pressure at each time point during the shut-in test.

[0101] Specifically, the principle and implementation of step 505 are similar to those of step 202 and will not be described in detail.

[0102] Step 506: Determine a pressure derivative double logarithmic curve based on the basic data and the pressure recovery data.

[0103] Specifically, the principle and implementation of step 506 are similar to those of step 203 and will not be described in detail.

[0104] Step 507 : Determine, based on a preset template curve, whether the shape of the pressure derivative double logarithmic curve presents a horizontal feature or a concave feature.

[0105] Specifically, the principle and implementation of step 507 are similar to those of step 204 and will not be described in detail.

[0106] Step 508a: If the double logarithmic curve of the pressure derivative shows a horizontal feature, it is determined that the fault is closed.

[0107] Specifically, the principle and implementation of step 508a are similar to those of step 205a and will not be repeated here.

[0108] Step 508b: If the double logarithmic curve of the pressure derivative shows a concave feature, it is determined that the fault has conductivity.

[0109] Specifically, the principle and implementation of step 508b are similar to those of step 205b and will not be described in detail.

[0110] Figure 12 This is a structural diagram of a fault sealing evaluation device according to an exemplary embodiment of the present disclosure.

[0111] Among them, the test well is on the extension line of the fault.

[0112] like Figure 12 As shown, the fault sealing evaluation device 1200 provided in this embodiment includes:

[0113] The acquisition unit 1210 is used to acquire basic data of the test well, wherein the basic data is used to represent the status information of the test well;

[0114] The acquisition unit 1210 is further configured to acquire pressure recovery data, including the cumulative shut-in time and the temperature and pressure at each time point during the shut-in test;

[0115] The processing unit 1220 is configured to determine a pressure derivative double logarithmic curve based on the basic data and the pressure recovery data;

[0116] The judgment unit 1230 is used to determine whether the shape of the pressure derivative double logarithmic curve presents a horizontal feature or a concave feature according to a preset template curve;

[0117] a determination unit 1240 for determining that the fault is closed if the double logarithmic curve of the pressure derivative exhibits a horizontal feature;

[0118] The determination unit 1240 is further configured to determine that the fault has conductivity if the double logarithmic curve of the pressure derivative presents a concave feature.

[0119] Figure 13 This is a structural diagram of a fault sealing evaluation device according to another exemplary embodiment of the present disclosure, wherein the test well is located on the extension line of the fault.

[0120] like Figure 13 As shown, based on the above embodiment, the fault sealing evaluation device 1300 provided in this embodiment includes:

[0121] The basic data in the acquisition unit 1210 at least include: wellbore diameter, oil and gas reservoir thickness, porosity, volume coefficient of reservoir oil and gas, oil and gas viscosity, and comprehensive compressibility coefficient of the reservoir.

[0122] Before acquiring unit 1210, apparatus 1300 further includes:

[0123] The template determination unit 1250 is used to obtain the spatial position of the test well and the fault;

[0124] The template determination unit 1250 is further used to determine a numerical model based on the spatial location of the test well and the fault; the numerical model is used to simulate the pressure change after the well is shut in;

[0125] The template determining unit 1250 is further configured to determine a preset template curve according to the numerical model.

[0126] The template determining unit 1250 is further configured to:

[0127] Determine the physical model of the gas reservoir based on the spatial location of the test wells and faults;

[0128] The numerical model is determined based on the physical model of the gas reservoir and the dynamic and static parameters of the oil and gas reservoir.

[0129] Figure 14 This is a structural diagram of an electronic device according to an exemplary embodiment of the present disclosure.

[0130] like Figure 14 As shown, the electronic device provided in this embodiment includes:

[0131] Memory 1401;

[0132] Processor 1402; and

[0133] computer programs;

[0134] The computer program is stored in the memory 1401 and configured to be executed by the processor 1402 to implement any of the above fault sealing evaluation methods.

[0135] This embodiment further provides a computer-readable storage medium having a computer program stored thereon. The computer program is executed by a processor to implement any of the above-mentioned fault sealing evaluation methods.

[0136] This embodiment further provides a computer program product, including a computer program. When the computer program is executed by a processor, it implements any of the above-mentioned fault sealing evaluation methods.

[0137] Those skilled in the art will appreciate that all or part of the steps in the above-described method embodiments can be implemented using hardware associated with program instructions. The aforementioned program can be stored in a computer-readable storage medium. When executed, the program performs the steps of the above-described method embodiments. The aforementioned storage medium includes various media capable of storing program code, such as ROM, RAM, magnetic disks, or optical disks.

[0138] Finally, it should be noted that the above embodiments are only used to illustrate the technical solutions of the present invention, rather than to limit it. Although the present invention has been described in detail with reference to the above embodiments, those skilled in the art should understand that they can still modify the technical solutions described in the above embodiments, or replace some or all of the technical features therein with equivalents. However, these modifications or replacements do not cause the essence of the corresponding technical solutions to deviate from the scope of the technical solutions of the embodiments of the present invention.

Claims

1. A fault sealing evaluation method, characterized in that: The test well is located on an extension line of the fault, and the method includes: Acquire basic data of the test well; wherein the basic data is used to represent status information of the test well; Obtaining pressure recovery data, including the cumulative shut-in time and the temperature and pressure at each time point during the shut-in test; determining a pressure derivative double logarithmic curve according to the basic data and the pressure recovery data; Determining, based on a preset template curve, whether the shape of the pressure derivative double logarithmic curve presents a horizontal feature or a concave feature; If the double logarithmic curve of the pressure derivative shows a horizontal feature, it is determined that the fault is closed; If the double logarithmic curve of the pressure derivative shows a concave feature, it is determined that the fault has conductivity.

2. The method according to claim 1, characterized in that The basic data include at least: wellbore diameter, oil and gas reservoir thickness, porosity, volume coefficient of reservoir oil and gas, oil and gas viscosity, and comprehensive compressibility coefficient of the reservoir.

3. The method according to claim 1, characterized in that Before obtaining the basic data of the test well, the method further includes: Obtaining the spatial positions of the test well and the fault; Determining a numerical model based on the spatial position of the test well and the fault; the numerical model is used to simulate pressure changes after the well is shut in; The preset template curve is determined according to the numerical model.

4. The method according to claim 3, characterized in that Determining a numerical model according to the test well and the spatial position of the fault includes: determining a gas reservoir physical model according to the test well and the spatial position of the fault; The numerical model is determined according to the gas reservoir physical model and the dynamic and static parameters of the oil and gas reservoir.

5. A fault sealing evaluation device, characterized in that: The test well is located on the extension line of the fault, and the device comprises: An acquisition unit, configured to acquire basic data of a test well; wherein the basic data is used to represent status information of the test well; The acquisition unit is further used to acquire pressure recovery data, wherein the pressure recovery data includes the cumulative shut-in time and the temperature and pressure at each time point during the shut-in test; a processing unit, configured to determine a pressure derivative double logarithmic curve based on the basic data and the pressure recovery data; a judgment unit, configured to determine, based on a preset template curve, whether the shape of the pressure derivative double logarithmic curve presents a horizontal feature or a concave feature; a determining unit, configured to determine that the fault is closed if the double logarithmic curve of the pressure derivative presents a horizontal feature; The determination unit is further configured to determine that the fault has conductivity if the double logarithmic curve of the pressure derivative presents a concave feature.

6. The device according to claim 5, characterized in that The basic data include at least: wellbore diameter, oil and gas reservoir thickness, porosity, volume coefficient of reservoir oil and gas, oil and gas viscosity, and comprehensive compressibility coefficient of the reservoir.

7. The device according to claim 5, characterized in that Before the acquisition unit, it also includes: a template determination unit, configured to obtain the spatial positions of the test well and the fault; The template determination unit is further used to determine a numerical model based on the spatial position of the test well and the fault; the numerical model is used to simulate the pressure change after the well is shut in; The template determination unit is further configured to determine the preset template curve according to the numerical model.

8. The device according to claim 7, characterized in that The template determination unit is further configured to: determining a gas reservoir physical model according to the test well and the spatial position of the fault; The numerical model is determined according to the gas reservoir physical model and the dynamic and static parameters of the oil and gas reservoir.

9. An electronic device, characterized in that: comprising a memory and a processor; wherein, The memory is used to store computer programs; The processor is configured to read the computer program stored in the memory and execute the method according to any one of claims 1 to 4 above according to the computer program in the memory.

10. A computer-readable storage medium, characterized in that The computer-readable storage medium stores computer-executable instructions, and when the processor executes the computer-executable instructions, the method according to any one of claims 1 to 4 is implemented.

11. A computer program product comprising a computer program, characterized in that When the computer program is executed by a processor, the method according to any one of claims 1 to 4 is implemented.

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