Risk assessment method and device for injection-production well

Abstract

The application discloses a kind of injection-production well risk assessment method and device, the method includes respectively determining the maximum allowable pressure of A annulus and the maximum allowable pressure of B annulus;According to the maximum allowable pressure of A annulus and the maximum allowable pressure of B annulus, establish pressure risk relationship;Collect the A annulus pressure and B annulus pressure in injection-production well evaluation period;According to the A annulus pressure and B annulus pressure in evaluation period, using the established pressure risk relationship, determine the risk level of injection-production well in evaluation period.The application is based on the maximum allowable pressure of A annulus and the maximum allowable pressure of B annulus to establish pressure risk relationship in advance, and then according to the A annulus pressure and B annulus pressure collected, using the established pressure risk relationship, determine the risk level of injection-production well in evaluation period, realize injection-production well risk real-time evaluation, and improve the accuracy of injection-production well risk assessment based on the established pressure risk relationship.

Description

Technical Field

[0001] This invention relates to the field of gas storage injection and production technology, and in particular to a method and apparatus for risk assessment of injection and production wells. Background Technology

[0002] This section is intended to provide background or context for the embodiments of the invention set forth in the claims. The description herein is not an admission that it is prior art simply because it is included in this section.

[0003] With the rapid development of natural gas, a large number of high-temperature, high-pressure, and high-acidity gas fields have been put into development, and gas storage facilities have also experienced significant growth. Gas storage facilities require periodic intensive injection and extraction to meet emergency peak-shaving needs, which poses higher safety risks compared to conventional gas wells. As gas fields develop and gas storage facilities operate, wellbore integrity issues have become increasingly prominent. Most notably, annular pressure has appeared to varying degrees in both gas wells and injection / production wells, threatening their safety. Therefore, it is essential to conduct risk assessments for wells with annular pressure, determine the risk level, and propose targeted measures.

[0004] Currently, both domestically and internationally, the maximum permissible annular pressure is determined by referring to the API (American Petroleum Institute) standard. The current annular pressure is compared to the maximum permissible pressure to simply assess the well's risk status. However, this method cannot comprehensively evaluate the risk of injection-production wells, and the evaluation results are biased. For wellbore integrity risk assessment, internationally, a professional technical team conducts an assessment based on detailed field test data. In my country, field tests for wellbore integrity risk assessment are relatively few, mainly due to testing risks and costs. Therefore, it is essential to establish a risk assessment method for injection-production wells based on annular pressure. Summary of the Invention

[0005] This invention provides a method for risk assessment of injection-production wells, enabling real-time risk assessment and improving the accuracy of such assessments. The method includes:

[0006] Determine the maximum permissible pressure of annulus A and annulus B respectively;

[0007] Establish a pressure-risk relationship based on the maximum permissible pressure of annulus A and the maximum permissible pressure of annulus B; the pressure-risk relationship reflects the relationship between annulus pressure and risk level.

[0008] Collect field data from injection and production wells; the field data should include at least the A annulus pressure and B annulus pressure during the evaluation period;

[0009] Based on the pressure of annulus A and annulus B during the evaluation period, the risk level of injection and production wells during the evaluation period is determined using the established pressure risk relationship.

[0010] This invention also provides a risk assessment device for injection-production wells, used to achieve real-time risk assessment of injection-production wells and improve the accuracy of risk assessment. The injection-production well risk assessment device includes:

[0011] The maximum permissible pressure determination module is used to determine the maximum permissible pressure of annulus A and the maximum permissible pressure of annulus B, respectively.

[0012] The pressure-risk relationship establishment module is used to establish a pressure-risk relationship based on the maximum permissible pressure of annulus A and the maximum permissible pressure of annulus B; the pressure-risk relationship reflects the relationship between annulus pressure and risk level.

[0013] The data acquisition module is used to collect field data from injection and production wells; the field data includes at least the A annulus pressure and B annulus pressure during the evaluation period.

[0014] The risk level determination module is used to determine the risk level of injection and production wells within the evaluation period based on the A annulus pressure and B annulus pressure within the evaluation period, using the established pressure risk relationship.

[0015] This invention also provides a computer device, including a memory, a processor, and a computer program stored in the memory and executable on the processor. When the processor executes the computer program, it implements the above-described injection-production well risk assessment method.

[0016] This invention also provides a computer-readable storage medium storing a computer program that performs the above-described injection-production well risk assessment method.

[0017] In this embodiment of the invention, the maximum permissible pressure of annulus A and annulus B are first determined; then, a pressure risk relationship is established based on the maximum permissible pressures of annulus A and annulus B; the pressures of annulus A and annulus B during the evaluation period of the injection-production well are collected; finally, based on the pressures of annulus A and annulus B during the evaluation period, the risk level of the injection-production well during the evaluation period is determined using the established pressure risk relationship. This embodiment of the invention pre-establishes a pressure risk relationship based on the maximum permissible pressures of annulus A and annulus B, and then determines the risk level of the injection-production well during the evaluation period based on the collected pressures of annulus A and annulus B using the established pressure risk relationship, achieving real-time risk assessment of injection-production wells and improving the accuracy of risk assessment based on the established pressure risk relationship. Attached Figure Description

[0018] To more clearly illustrate the technical solutions in the embodiments of the present invention or the prior art, the drawings used in the description of the embodiments or the prior art will be briefly introduced below. Obviously, the drawings described below are only some embodiments of the present invention. For those skilled in the art, other drawings can be obtained based on these drawings without creative effort. In the drawings:

[0019] Figure 1 The flowchart illustrates the implementation of the injection-production well risk assessment method provided in the first embodiment of the present invention.

[0020] Figure 2 This is a flowchart illustrating the implementation of step 102 in the injection-production well risk assessment method provided in the second embodiment of the present invention.

[0021] Figure 2-1 This is a schematic diagram of the annulus pressure diagram corresponding to the first low risk of annulus A when annulus A is pressurized, provided in an embodiment of the present invention;

[0022] Figure 2-2 This is a schematic diagram of the annulus pressure diagram corresponding to the second lowest risk of annulus A when annulus A is pressurized, provided in an embodiment of the present invention.

[0023] Figure 3 This is a flowchart illustrating the implementation of step 102 in the injection-production well risk assessment method provided in the third embodiment of the present invention.

[0024] Figure 3-1 This is a schematic diagram of the annular pressure diagram corresponding to the risk in the annular space when the annular space is pressurized, provided in an embodiment of the present invention.

[0025] Figure 3-2 This is a schematic diagram of the annular pressure diagram corresponding to the high risk in annular pressure zone A, provided in an embodiment of the present invention.

[0026] Figure 4 This is a flowchart illustrating the implementation of step 102 in the injection-production well risk assessment method provided in the fourth embodiment of the present invention.

[0027] Figure 4-1 This is a schematic diagram of the annulus pressure diagram corresponding to the first high risk in annulus A when annulus A is pressurized, provided in an embodiment of the present invention.

[0028] Figure 4-2 This is a schematic diagram of the annulus pressure diagram corresponding to the second highest risk in annulus A when annulus A is pressurized, provided in an embodiment of the present invention.

[0029] Figure 4-3 This is a schematic diagram of the annulus pressure diagram corresponding to the third highest risk in annulus A when annulus A is pressurized, provided in an embodiment of the present invention.

[0030] Figure 5This is a flowchart illustrating the implementation of step 102 in the injection-production well risk assessment method provided in the fifth embodiment of the present invention.

[0031] Figure 5-1 This is a schematic diagram of the annulus pressure diagram corresponding to low risk in the B annulus when the B annulus is pressurized, provided in an embodiment of the present invention.

[0032] Figure 5-2 This is a schematic diagram of the annular pressure diagram corresponding to the risk in the B annular space when the B annular space is pressurized, provided in an embodiment of the present invention.

[0033] Figure 5-3 This is a schematic diagram of the annulus pressure diagram corresponding to the high risk of annulus B under pressure, provided in an embodiment of the present invention.

[0034] Figure 6 This is a flowchart illustrating the implementation of step 102 in the injection-production well risk assessment method provided in the sixth embodiment of the present invention.

[0035] Figure 7 The flowchart illustrates the implementation of the injection-production well risk assessment method provided in the seventh embodiment of the present invention.

[0036] Figure 7-1 This is a schematic diagram of the annular pressure zone of a gas storage injection-production well provided in an embodiment of the present invention;

[0037] Figure 8 This is a functional block diagram of the injection-production well risk assessment device provided in the eighth embodiment of the present invention;

[0038] Figure 9 This is a structural block diagram of the pressure risk relationship establishment module 802 in the injection-production well risk assessment device provided in the ninth embodiment of the present invention;

[0039] Figure 10 This is a structural block diagram of the pressure risk relationship establishment module 802 in the injection-production well risk assessment device provided in the tenth embodiment of the present invention;

[0040] Figure 11 This is a structural block diagram of the pressure risk relationship establishment module 802 in the injection-production well risk assessment device provided in the eleventh embodiment of the present invention;

[0041] Figure 12 This is a structural block diagram of the pressure risk relationship establishment module 802 in the injection-production well risk assessment device provided in the twelfth embodiment of the present invention;

[0042] Figure 13 This is a structural block diagram of the pressure risk relationship establishment module 802 in the injection-production well risk assessment device provided in the thirteenth embodiment of the present invention;

[0043] Figure 14 This is a functional block diagram of the injection-production well risk assessment device provided in the fourteenth embodiment of the present invention. Detailed Implementation

[0044] To make the objectives, technical solutions, and advantages of the embodiments of the present invention clearer, the embodiments of the present invention will be further described in detail below with reference to the accompanying drawings. Here, the illustrative embodiments of the present invention and their descriptions are used to explain the present invention, but are not intended to limit the present invention.

[0045] Figure 1 The implementation flow of the injection-production well risk assessment method provided in the first embodiment of the present invention is shown. For ease of description, only the parts related to the embodiment of the present invention are shown, and are detailed below:

[0046] like Figure 1 As shown, the risk assessment method for injection-production wells includes:

[0047] Step 101: Determine the maximum permissible pressure of annulus A and annulus B respectively;

[0048] Step 102: Establish a pressure risk relationship based on the maximum permissible pressure of annulus A and the maximum permissible pressure of annulus B; the pressure risk relationship reflects the relationship between annulus pressure and risk level.

[0049] Step 103: Collect field data from injection and production wells; the field data shall include at least the A annulus pressure and B annulus pressure during the evaluation period;

[0050] Step 104: Based on the A-annular pressure and B-annular pressure within the evaluation period, determine the risk level of the injection-production well within the evaluation period using the established pressure risk relationship.

[0051] When determining the risk level of injection and production wells within the evaluation period, the standards of the American Petroleum Institute (API) and field experience can be referenced to determine the maximum allowable pressure (MAP) of annulus A and annulus B, respectively. Then, a pressure-risk relationship can be established based on the MAPs of annulus A and annulus B. This pressure-risk relationship reflects the relationship between annulus pressure and risk level. For example, the pressure-risk relationship can be described using an annulus pressure chart.

[0052] The pressure conditions in annular pressure wells vary widely and can be classified to create typical annular pressure maps. Different annular pressure maps correspond to different risk levels. Annular pressure wells can be divided into two main categories: annulus A and annulus B, where only one annulus is pressured (i.e., either annulus A or annulus B is pressured), and both annulus A and annulus B are pressured.

[0053] The severity of failure consequences varies among wells with annular pressure, and the corresponding treatment measures also differ. Therefore, the risk level of wells with annular pressure is determined based on the failure consequences and treatment measures. Wells with annular pressure can be classified into four categories: low risk, medium risk, medium-high risk, and high risk. Low-risk wells with annular pressure can continue normal production without additional countermeasures; medium-risk wells with annular pressure only require enhanced annular pressure monitoring; medium-high risk wells with annular pressure require close monitoring of the annular pressure status, risk assessment, and risk reduction measures; high-risk wells with annular pressure require immediate detailed risk assessment and immediate risk elimination measures or well workover operations.

[0054] After establishing the pressure-risk relationship (e.g., annular pressure charts corresponding to different risk levels), field data from injection and production wells is collected. This field data should include at least the production dynamics data since well workover or completion (production rate, oil pressure, A and B annular pressures and temperatures within the evaluation period), as well as well structure, casing, and downhole tool performance parameters. Field test data, if available, can also be collected to assist in risk level assessment. Each evaluation should analyze dynamic data for at least one injection-production cycle.

[0055] Finally, based on the collected A-annular pressure and B-annular pressure during the evaluation period, the risk level of the injection and production wells during the evaluation period was determined by comparing them using the pre-established pressure risk relationship.

[0056] In this embodiment of the invention, the maximum permissible pressures of annulus A and annulus B are first determined; then, a pressure risk relationship is established based on these pressures; the pressures of annulus A and annulus B during the evaluation period of the injection-production well are collected; finally, based on the pressures of annulus A and annulus B during the evaluation period, the risk level of the injection-production well during the evaluation period is determined using the established pressure risk relationship. This embodiment of the invention pre-establishes a pressure risk relationship based on the maximum permissible pressures of annulus A and annulus B, and then determines the risk level of the injection-production well during the evaluation period based on the collected pressures of annulus A and annulus B using the established pressure risk relationship, achieving real-time risk assessment of injection-production wells and improving the accuracy of risk assessment based on the established pressure risk relationship.

[0057] Figure 2 The implementation flow of step 102 in the injection-production well risk assessment method provided in the second embodiment of the present invention is shown. For ease of description, only the parts related to the embodiment of the present invention are shown, and are detailed below:

[0058] In one embodiment of the present invention, in order to improve the accuracy of determining the low-risk level of A-ring space, such as... Figure 2As shown, step 102 establishes a pressure risk relationship based on the maximum permissible pressure of annulus A and the maximum permissible pressure of annulus B, including:

[0059] Step 201: In the A-annulus, the pressure fluctuates within the first pressure range of the maximum permissible pressure of the A-annulus, and the risk level of the injection-production well is determined to be the first low risk of the A-annulus.

[0060] Step 202: When the A annulus is pressurized, the A annulus pressure increases with the temperature during the gas production period, decreases with the temperature during the well shut-in or gas injection period, and the highest pressure of the A annulus does not exceed the upper limit of the thermally induced annulus pressure of the injection and production well, the risk level of the injection and production well is determined to be the second lowest risk of the A annulus.

[0061] When the annulus is pressurized:

[0062] (1) The A-annular pressure is stable or fluctuates slightly within the low value range.

[0063] If the annular pressure in well A fluctuates within the first pressure range (e.g., 20%-30%) of the maximum permissible pressure (MAP) of annulus A, then the current annular pressure of the well can be considered to be within the normal range, indicating a low-risk well. This first pressure range can also be 22% to 32% of the maximum permissible pressure (MAP) of annulus A, etc. Figure 2-1 The diagram shows a pressurized annulus A corresponding to the lowest risk level when the annulus A is pressurized. The horizontal axis represents time, and the vertical axis represents the pressure in the annulus A.

[0064] In some wells, a certain amount of nitrogen is injected into the A annulus to alleviate the thermally induced annulus pressure. This pressure value generally does not exceed 20%-30% of the maximum allowable pressure (MAP). Therefore, taking 20%-30% of the maximum permissible pressure (MAP) of the A annulus as the first pressure range can effectively avoid misjudgment of the annulus pressure of wells with nitrogen injection.

[0065] (2) The A-annular pressure fluctuates within a certain range as injection and production operations proceed.

[0066] The annular pressure A fluctuates within a certain range during injection and production operations. The highest pressure does not exceed the upper limit of the thermally induced annular pressure for that well. When the temperature rises during the gas production period, the annular pressure A rises; when the temperature decreases during the well shut-in or injection period, the annular pressure A decreases. If the pressure change trend is synchronous with or slightly lags behind the temperature change trend, then the current annular pressure of the well can be considered to be within the normal range, indicating a low-risk well. Figure 2-2 The diagram shows a pressure chart of the annulus A corresponding to the second lowest risk when the annulus A is pressurized. The horizontal axis represents time, and the vertical axis represents the pressure of the annulus A.

[0067] If the pressure in annulus A changes periodically with the wellbore temperature, and the pressure in annulus A returns to its initial value when the temperature decreases, then the pressure is considered to be annulus pressure caused by temperature effects.

[0068] In this embodiment of the invention, when the A annulus is pressurized, if the pressure of the A annulus fluctuates within the first pressure range of the maximum permissible pressure of the A annulus, the risk level is determined to be the first low risk of the A annulus; when the A annulus is pressurized, and the pressure of the A annulus changes in the same trend as the temperature and the highest pressure does not exceed the upper limit of the thermally induced annulus pressure, the risk level is determined to be the second low risk of the A annulus. Determining the risk level based on the above constraints can improve the accuracy of the judgment of the low risk level of the A annulus.

[0069] Figure 3 The implementation flow of step 102 in the injection-production well risk assessment method provided in the third embodiment of the present invention is shown. For ease of description, only the parts related to the embodiment of the present invention are shown, and are detailed below:

[0070] In one embodiment of the present invention, in order to improve the accuracy of the air risk level judgment for Ring A, such as Figure 3 As shown, step 102 establishes a pressure risk relationship based on the maximum permissible pressure of annulus A and the maximum permissible pressure of annulus B, including:

[0071] Step 301: When the pressure in the A annulus is pressurized, and the pressure change rate in the A annulus is not greater than the preset pressure change rate within the second pressure range of the maximum permissible pressure in the A annulus, and the pressure in the A annulus is less than the upper limit of the second pressure range of the maximum permissible pressure in the A annulus, the risk level of the injection-production well is determined to be risky in the A annulus.

[0072] Step 302: When the pressure in the A annulus is less than the upper limit of the second pressure range of the maximum permissible pressure in the A annulus but shows a gradual upward trend, the risk level of the injection-production well is determined to be high risk in the A annulus.

[0073] When the annulus is pressurized:

[0074] (3) The A-annular pressure is less than 80% MAP, and the stable value does not exceed 80% MAP.

[0075] The rate of change of pressure in annulus A within the second pressure range of the maximum permissible pressure of annulus A is not greater than the preset rate of change of pressure, and the pressure in annulus A is less than the upper limit of the second pressure range of the maximum permissible pressure of annulus A but shows a gradual upward trend. For example, if the pressure in annulus A is basically stable in the range below 80% of MAP and there is no obvious upward trend, it proves that the pressure in annulus A will not exceed 80% of MAP, and the preset rate of change of pressure is 5% or 3%, etc. At the same time, if the pressure in annulus A does not belong to the above (1) and (2) conditions, it proves that the pressure in annulus A of the well is relatively high, there is a certain risk, and it belongs to a medium-risk well. Figure 3-1 The diagram shows the annular pressure corresponding to the risk in the annular space when the annular space is pressurized. The horizontal axis represents time, and the vertical axis represents the annular pressure in the annular space.

[0076] The gradual increase or stabilization of the pressure in annulus A at around 80% MAP indicates that there is a certain amount of minor leakage in annulus A. However, the pressure is stable and does not exceed the safety limit, so it is within a controllable range and no further serious phenomena have been observed.

[0077] (4) The A-annular pressure is less than 80% of MAP, but still shows an upward trend.

[0078] The annular pressure of well A is below 80% of the maximum mean arterial pressure (MAP), but its pressure value is stable and still has an upward trend, indicating that the annular pressure will continue to rise. Therefore, the well is considered to have a high annular pressure risk and belongs to the medium-to-high risk category. Figure 3-2 The diagram shows a high-risk annular pressure chart corresponding to annular pressure in annular A. The horizontal axis represents time, and the vertical axis represents annular pressure in annular A.

[0079] The gradual increase in annular pressure A indicates that there is some leakage in annular A. The leakage continues, and the annular pressure phenomenon will become more serious, which is very likely to exceed 80% MAP.

[0080] In this embodiment of the invention, when the A-annulus is pressurized, the pressure change in the A-annulus is small, and the pressure in the A-annulus is less than the upper limit of the second pressure range of the maximum permissible pressure of the A-annulus, it is determined to be of low risk in the A-annulus; when the A-annulus is pressurized, the pressure in the A-annulus is less than the upper limit of the second pressure range of the maximum permissible pressure of the A-annulus but shows a gradual upward trend, it is determined to be of high risk in the A-annulus. Determining the risk level based on the above constraints can improve the accuracy of the risk level judgment in the A-annulus.

[0081] Figure 4 The implementation flow of step 102 in the injection-production well risk assessment method provided in the fourth embodiment of the present invention is shown. For ease of description, only the parts related to the embodiment of the present invention are shown, and are detailed below:

[0082] In one embodiment of the present invention, in order to improve the accuracy of the high-risk level judgment of the A-ring airspace, such as... Figure 4 As shown, step 102 establishes a pressure risk relationship based on the maximum permissible pressure of annulus A and the maximum permissible pressure of annulus B, including:

[0083] Step 401: When the A-annulus is pressurized and the pressure in the A-annulus is in the third pressure range of the maximum permissible pressure in the A-annulus, the risk level of the injection-production well is determined to be the highest risk in the A-annulus.

[0084] Step 402: When the pressure in annulus A exceeds the maximum permissible pressure in annulus A, the risk level of the injection-production well is determined to be the second highest risk in annulus A.

[0085] Step 403: When the pressure difference between the A-annulus and the oil pressure is not greater than the preset pressure difference, the risk level of the injection-production well is determined to be the third highest risk in the A-annulus.

[0086] When the annulus is pressurized:

[0087] (5) A. Annular pressure exceeds 80% of MAP

[0088] When the annular pressure in annulus A is within the third pressure range of the maximum permissible pressure in annulus A, for example, if the annular pressure in annulus A exceeds 80% of the maximum allowable pressure (MAP) and stabilizes at a certain pressure value but does not exceed the MAP, the well is considered to have a significant risk and is classified as a medium-to-high risk well. When the annular pressure in annulus A exceeds 80% of the MAP and tends to stabilize, it indicates that there is some leakage in annulus A, and the leakage volume is relatively large, indicating a high risk. Figure 4-1 The diagram shows a pressure chart of the annulus A corresponding to the highest risk level when the annulus A is pressurized. The horizontal axis represents time, and the vertical axis represents the pressure of the annulus A.

[0089] (6) A. Annular pressure exceeds MAP

[0090] When the pressure in annulus A exceeds the maximum permissible pressure in annulus A. If the pressure in annulus A exceeds the maximum permissible pressure (MAP), it indicates that there is a significant leak in annulus A, and the pressure value exceeds the safety limit. Therefore, the well is considered to have extremely high risk and is classified as a high-risk well. Figure 4-2 The diagram shows a pressure chart of the annulus A corresponding to the second highest risk when the annulus A is pressurized. The horizontal axis represents time, and the vertical axis represents the pressure of the annulus A.

[0091] (7) A. The annular pressure is basically the same as the oil pressure.

[0092] When the difference between the annular pressure and the oil pressure is not greater than the preset pressure difference, it indicates that the annular pressure and oil pressure are basically the same, proving that the oil casing is basically connected and the tubing string has perforation. This indicates that the well has a very high risk and is considered a high-risk well. For example, the preset pressure difference should not be greater than 5% or 2% of the annular pressure, etc. Figure 4-3 The diagram shows a pressure chart of the annulus A corresponding to the third highest risk when the annulus A is pressurized. The horizontal axis represents time, and the vertical axis represents the pressure of the annulus A.

[0093] In this embodiment of the invention, when the pressure of the A-annulus is within the third pressure range of the maximum permissible pressure of the A-annulus, the risk level is determined to be the first high risk of the A-annulus; when the pressure of the A-annulus exceeds the maximum permissible pressure of the A-annulus, the risk level is determined to be the second high risk of the A-annulus; when the difference between the pressure of the A-annulus and the oil pressure is not greater than a preset pressure difference, the risk level is determined to be the third high risk of the A-annulus. Determining the risk level based on the above constraints can improve the accuracy of judging the high risk level of the A-annulus.

[0094] Figure 5 The implementation flow of step 102 in the injection-production well risk assessment method provided in the fifth embodiment of the present invention is shown. For ease of description, only the parts related to the embodiment of the present invention are shown, and are detailed below:

[0095] In one embodiment of the present invention, in order to improve the accuracy of the high-risk level judgment of the B-ring, such as Figure 5 As shown, step 102

[0096] Step 501: When the B annulus is pressurized and the pressure in the B annulus is within the first pressure range of the maximum permissible pressure in the B annulus, determine the risk level of the injection-production well as the low risk difference of the B annulus.

[0097] Step 502: When the B annulus is pressurized and the pressure in the B annulus is in the second pressure range of the maximum permissible pressure in the B annulus, the risk level of the injection-production well is determined to be high risk in the B annulus.

[0098] Step 503: When the B annulus is pressurized and the pressure in the B annulus is in the third pressure range of the maximum permissible pressure in the B annulus, the risk level of the injection-production well is determined to be high risk in the B annulus.

[0099] When the B annulus is pressurized:

[0100] (1) The B-annular pressure is stable or fluctuates slightly within the low value range.

[0101] When the B-annular pressure is within the first pressure range of the maximum permissible pressure of the B-annular space, for example, if the B-annular pressure fluctuates within 10% of the maximum permissible pressure of the B-annular space (MAP), then the current well annular pressure can be considered to be within the normal range, indicating a low-risk well. Alternatively, the first pressure range can also be 5% to 15% of the maximum permissible pressure of the B-annular space, etc. Figure 5-1 The diagram shows a graph of the annulus pressure corresponding to the low risk of the B annulus under pressure. The horizontal axis represents time, and the vertical axis represents the pressure of the B annulus.

[0102] In some wells, the cementing reacted, producing a certain amount of gas that accumulated in the B annulus, creating a certain annulus pressure. However, this pressure was generally very small, and the B annulus itself did not leak.

[0103] (2) The annular pressure in circumference B does not exceed 60% of the maximum allowable pressure (MAP).

[0104] Handling pressurized B-annulus wells is more difficult, and leakage from the B-annulus to other formations, or even along faults to the surface, is more likely. Therefore, the limit values ​​for B-annulus pressure are more conservative. When the B-annulus pressure is within the second pressure range of the maximum permissible pressure of the B-annulus (e.g., 30% to 60% of the maximum permissible pressure), the upper limit of the second pressure range is taken as 60%. If the B-annulus pressure does not exceed 60% of the maximum permissible pressure (MAP), it indicates that there is some leakage in the B-annulus, classifying it as a medium-risk well. Figure 5-2 The diagram shows a graph of the annulus pressure corresponding to the low risk of the B annulus under pressure. The horizontal axis represents time, and the vertical axis represents the pressure of the B annulus.

[0105] (3) B-annular pressure exceeds 60% of MAP

[0106] The pressure in the B-annulus is within the third pressure range of the maximum permissible pressure of the B-annulus. This third pressure range is 60% to 100% of the maximum permissible pressure of the B-annulus, meaning the lower limit of the second pressure range is 60% and the upper limit is 100%. For example, if the pressure in the B-annulus exceeds 60% of the maximum permissible pressure (MAP), it indicates a significant leak in the B-annulus, posing a greater risk of leakage to the surface and classifying it as a high-risk well. Figure 5-3 The diagram shows a graph of the annulus pressure corresponding to the low risk of the B annulus under pressure. The horizontal axis represents time, and the vertical axis represents the pressure of the B annulus.

[0107] In this embodiment of the invention, when the B annulus is pressurized and the pressure in the B annulus is within the first pressure range of the maximum permissible pressure of the B annulus, the risk level is determined to be low risk difference of the B annulus; when the B annulus is pressurized and the pressure in the B annulus is within the second pressure range of the maximum permissible pressure of the B annulus, the risk level is determined to be medium risk of the B annulus; when the B annulus is pressurized and the pressure in the B annulus is within the third pressure range of the maximum permissible pressure of the B annulus, the risk level is determined to be high risk of the B annulus. Determining the risk level based on constraints can improve the accuracy of the B annulus risk level judgment.

[0108] Figure 6 The implementation flow of step 102 in the injection-production well risk assessment method provided in the sixth embodiment of the present invention is shown. For ease of description, only the parts related to the embodiment of the present invention are shown, and are detailed below:

[0109] In one embodiment of the present invention, in order to improve the accuracy of risk level judgment when both annulus A and annulus B are pressurized, such as... Figure 6 As shown, step 102 establishes a pressure risk relationship based on the maximum permissible pressure of annulus A and the maximum permissible pressure of annulus B, including:

[0110] Step 601: With annulus A and annulus B pressurized, determine whether annulus A and annulus B are connected.

[0111] Step 602: When annulus A and annulus B are pressurized and annulus A and annulus B are not connected, determine the risk level of injection-production wells based on the pressure of annulus A and the risk level of injection-production wells based on the pressure of annulus B, respectively.

[0112] Step 603: The higher risk level between the injection-production well risk level determined based on the A annular pressure and the injection-production well risk level determined based on the B annular pressure is taken as the risk level of the injection-production well.

[0113] Step 604: When annulus A and annulus B are pressurized, and annulus A and annulus B are connected, establish a pressure risk relationship by using the maximum permissible pressure of annulus B as the maximum permissible pressure of annulus A.

[0114] When annulus A is pressurized and annulus B is pressurized:

[0115] When both annulus A and annulus B are pressurized, it is necessary to determine whether annulus A and annulus B are connected. By analyzing historical annulus pressurization data, it is evaluated whether annulus A and annulus B have the same trend of change. That is, if the pressure of annulus A increases within a certain pressure range, the pressure of annulus B also increases accordingly or with a certain lag, then annulus A and annulus B are connected; otherwise, they are considered not connected.

[0116] (1) When the A annulus and the B annulus are not connected, the A annulus and the B annulus can be evaluated separately, and the highest risk level among the evaluation results is taken as the risk level of the well.

[0117] (2) When ring A and ring B are connected, take the MAP of ring B as the MAP of ring A and ring B, and then proceed as described above. Figures 2 to 5 The corresponding embodiments are evaluated.

[0118] In this embodiment of the invention, when both annulus A and annulus B are pressurized and annulus A and annulus B are not connected, the higher of the risk levels of the injection-production well determined based on the pressure of annulus A and the risk levels of the injection-production well determined based on the pressure of annulus B is taken as the risk level of the injection-production well. When both annulus A and annulus B are pressurized and annulus A and annulus B are connected, the maximum permissible pressure of annulus B is taken as the maximum permissible pressure of annulus A to establish a pressure-risk relationship. The risk level is determined based on the above constraints, which can improve the accuracy of risk level determination when both annulus A and annulus B are pressurized.

[0119] Figure 7 The implementation flow of the injection-production well risk assessment method provided in the seventh embodiment of the present invention is shown. For ease of description, only the parts related to the embodiments of the present invention are shown, and are detailed below:

[0120] In one embodiment of the present invention, the field data of the injection-production well also includes annular fluid level data and / or casing external test data. To improve the accuracy of annular leakage detection, such as... Figure 7 As shown, based on the above methodological steps, the risk assessment method for injection-production wells also includes:

[0121] Step 701: If the change value of the annular liquid level data in adjacent time intervals is not less than the preset change value, and / or the test data outside the casing reflects gas channeling outside the casing, it is determined that there is a leak in the annulus.

[0122] Field investigations revealed that wells with C-annular pressure are relatively rare. Evaluation of C-annular pressure wells can be conducted by analogy to the aforementioned examples. Data from annular fluid level testing, casing external testing, and cementing quality assessment can assist in risk level evaluation. If the change in annular fluid level data over adjacent time intervals is not less than a preset change value—for example, if comparing two consecutive years of annular fluid level data and finding a significant change exceeding the preset change value—it proves annular leakage; similarly, if casing external testing reveals gas channeling outside the casing, it proves annular leakage, etc. The preset change value could be 0.3% or 0.2% of the annular fluid level data, etc.

[0123] In this embodiment of the invention, if the change value of the annular liquid level data in adjacent time intervals is not less than a preset change value, and / or the test data outside the casing reflects the presence of gas channeling outside the casing, it is determined that there is a leak in the annulus; judging whether there is a leak in the annulus based on the above constraints can improve the accuracy of annular leak judgment.

[0124] Furthermore, the entire invention can be integrated to construct an annular pressure early warning system based on a field dynamic database. First, the typical diagrams of this invention are solidified. By retrieving field database data in real time, the MAP of different wells and different annulus areas is determined, typical diagrams of different blocks are automatically drawn, and the annular pressure risk level is automatically assessed. Once an abnormal risk occurs, an early warning can be issued in real time, improving the speed of field response.

[0125] The basic principle of this invention will now be explained using a gas storage facility as an example:

[0126] Based on actual data from injection and production wells, the MAP of annulus A was determined to be 18 MPa, and the MAP of annulus B to be 10 MPa. Typical plots were then created. Production dynamic data were collected and compared with the typical plots. Figure 7-1 The diagram shown is a schematic representation of the annular pressure zone of an injection and production well in a gas storage facility. Figure 7-1 It is known that annular pressure exists in well A, while the pressure in annular B is 0 MPa. Therefore, the evaluation is based on the annular pressure chart for well A. In the initial production phase, the pressure in annular A changes periodically with the oil pressure and can be reduced to its original value, which is consistent with... Figure 2-2 The annular pressure chart shown corresponds to the second lowest risk level in annular A when annulus A is pressurized, which represents thermally induced annular pressure. Furthermore, in the injection-production cycle preceding the evaluation time, the annular pressure in annulus A was essentially 0 MPa, consistent with... Figure 2-1 The annulus pressure chart shown here, corresponding to the first low-risk annulus in annulus A, indicates a low-risk well. Both evaluations for this well resulted in a low-risk rating. In case of conflicting evaluation results, the evaluation result most recently obtained will prevail.

[0127] This invention also provides a risk assessment device for injection-production wells, as described in the following embodiments. Since the principles underlying these devices are similar to those of the risk assessment methods for injection-production wells, the implementation of these devices can be referred to the implementation of the methods, and repeated details will not be elaborated further.

[0128] Figure 8 The functional modules of the injection-production well risk assessment device provided in the eighth embodiment of the present invention are shown. For ease of explanation, only the parts related to the embodiments of the present invention are shown, and are described in detail below:

[0129] refer to Figure 8 The injection-production well risk assessment device comprises various modules used for execution. Figure 1 For details of each step in the corresponding embodiment, please refer to [link / reference]. Figure 1 as well as Figure 1 The relevant descriptions in the corresponding embodiments will not be repeated here. In this embodiment of the invention, the injection-production well risk assessment device includes a maximum permissible pressure determination module 801, a pressure-risk relationship establishment module 802, a data acquisition module 803, and a risk level determination module 804.

[0130] The maximum permissible pressure determination module 801 is used to determine the maximum permissible pressure of annulus A and the maximum permissible pressure of annulus B, respectively.

[0131] The pressure risk relationship establishment module 802 is used to establish a pressure risk relationship based on the maximum permissible pressure of annulus A and the maximum permissible pressure of annulus B; the pressure risk relationship reflects the relationship between annulus pressure and risk level.

[0132] The data acquisition module 803 is used to collect field data from injection and production wells; the field data includes at least the A annulus pressure and B annulus pressure during the evaluation period.

[0133] The risk level determination module 804 is used to determine the risk level of injection and production wells within the evaluation period based on the A annulus pressure and B annulus pressure within the evaluation period and by utilizing the established pressure risk relationship.

[0134] In this embodiment of the invention, the maximum permissible pressure determination module 801 first determines the maximum permissible pressure of annulus A and annulus B, respectively; then, the pressure risk relationship establishment module 802 establishes a pressure risk relationship based on the maximum permissible pressures of annulus A and annulus B; the data acquisition module 803 acquires the pressures of annulus A and annulus B during the evaluation period of the injection-production well; finally, the risk level determination module 804 determines the risk level of the injection-production well during the evaluation period based on the pressures of annulus A and annulus B during the evaluation period, using the established pressure risk relationship. In this embodiment of the invention, the pressure risk relationship establishment module 802 pre-establishes a pressure risk relationship based on the maximum permissible pressures of annulus A and annulus B, and then the risk level determination module 804 determines the risk level of the injection-production well during the evaluation period based on the acquired pressures of annulus A and annulus B, using the established pressure risk relationship, thereby achieving real-time risk assessment of the injection-production well and improving the accuracy of risk assessment based on the established pressure risk relationship.

[0135] Figure 9 The diagram illustrates the structure of the pressure risk relationship establishment module 802 in the injection-production well risk assessment device provided in the ninth embodiment of the present invention. For ease of explanation, only the parts related to the embodiments of the present invention are shown, and are described in detail below:

[0136] In one embodiment of the present invention, in order to improve the accuracy of the low-risk level judgment of the A-ring, refer to Figure 9 The pressure risk relationship establishment module 802 includes various units used for execution. Figure 2 For details of each step in the corresponding embodiment, please refer to [link / reference]. Figure 2 as well as Figure 2 The relevant descriptions in the corresponding embodiments will not be repeated here. In this embodiment of the invention, the pressure risk relationship establishment module 802 includes an A-annular first low-risk determination unit 901 and an A-annular second low-risk determination unit 902.

[0137] Unit 901 for determining the first low risk of annulus A is used to determine the risk level of injection and production wells as the first low risk of annulus A when the annulus A is pressurized and the pressure of annulus A fluctuates within the first pressure range of the maximum permissible pressure of annulus A.

[0138] The A-annulus second lowest risk determination unit 902 is used to determine the risk level of the injection-production well as the second lowest risk of the A-annulus when the A-annulus is pressurized, the A-annulus pressure increases with the temperature during the gas production period, the A-annulus pressure decreases with the temperature during the shut-in or gas injection period, and the highest pressure of the A-annulus does not exceed the upper limit of the thermally induced annulus pressure of the injection-production well.

[0139] In this embodiment of the invention, when the annulus A is pressurized, if the pressure of the annulus A fluctuates within the first pressure range of the maximum permissible pressure of the annulus A, the risk level of the annulus A is determined to be the first low risk. When the annulus A is pressurized, and the pressure and temperature of the annulus A change in the same trend and the maximum pressure does not exceed the upper limit of the thermally induced annulus pressure, the risk level of the annulus A is determined to be the second low risk. Determining the risk level based on the above constraints can improve the accuracy of the judgment of the low risk level of the annulus A.

[0140] Figure 10 The diagram shows the structure of the pressure risk relationship establishment module 802 in the injection-production well risk assessment device provided in the tenth embodiment of the present invention. For ease of explanation, only the parts related to the embodiment of the present invention are shown, and are described in detail below:

[0141] In one embodiment of the present invention, in order to improve the accuracy of the air risk level judgment for Ring A, reference is made to... Figure 10 The pressure risk relationship establishment module 802 includes various units used for execution. Figure 3 For details of each step in the corresponding embodiment, please refer to [link / reference]. Figure 3 as well as Figure 3 The relevant descriptions in the corresponding embodiments will not be repeated here. In this embodiment of the invention, the pressure risk relationship establishment module 802 includes an A-ring air risk determination unit 1001 and an A-ring air high risk determination unit 1002.

[0142] The risk determination unit 1001 in the A-annulus is used to determine the risk level of the injection-production well as the risk level in the A-annulus when the A-annulus is pressurized, the pressure change rate of the A-annulus pressure is not greater than the preset pressure change rate within the second pressure range of the maximum permissible pressure of the A-annulus, and the A-annulus pressure is less than the upper limit of the second pressure range of the maximum permissible pressure of the A-annulus.

[0143] The high-risk determination unit 1002 in the A-annulus is used to determine the risk level of the injection-production well as high-risk in the A-annulus when the A-annulus is pressurized and the pressure in the A-annulus is less than the upper limit of the second pressure range of the maximum permissible pressure in the A-annulus but shows a gradual upward trend.

[0144] In this embodiment of the invention, the risk determination unit 1001 in the A-ring space determines the A-ring space to be at risk when the A-ring space is pressurized, the pressure change in the A-ring space is small, and the pressure in the A-ring space is less than the upper limit of the second pressure range of the maximum permissible pressure in the A-ring space; the high risk determination unit 1002 in the A-ring space determines the A-ring space to be at high risk when the A-ring space is pressurized, the pressure in the A-ring space is less than the upper limit of the second pressure range of the maximum permissible pressure in the A-ring space but shows a gradual upward trend. Determining the risk level based on the above constraints can improve the accuracy of the risk level judgment in the A-ring space.

[0145] Figure 11 The diagram shows the structure of the pressure risk relationship establishment module 802 in the injection-production well risk assessment device provided in the eleventh embodiment of the present invention. For ease of explanation, only the parts related to the embodiment of the present invention are shown, and are described in detail below:

[0146] In one embodiment of the present invention, in order to improve the accuracy of the high-risk level judgment of the A-ring airspace, reference is made to... Figure 11 The pressure risk relationship establishment module 802 includes various units used for execution. Figure 4 For details of each step in the corresponding embodiment, please refer to [link / reference]. Figure 4 as well as Figure 4 The relevant descriptions in the corresponding embodiments will not be repeated here. In this embodiment of the invention, the pressure risk relationship establishment module 802 includes an A-annular first high-risk determination unit 1101, an A-annular second high-risk determination unit 1102, and an A-annular third high-risk determination unit 1103.

[0147] The A-annulus first high-risk determination unit 1101 is used to determine the risk level of the injection-production well as the first high-risk annulus when the A-annulus is pressurized and the pressure of the A-annulus is in the third pressure range of the maximum permissible pressure of the A-annulus.

[0148] The A-annulus second highest risk determination unit 1102 is used to determine the risk level of the injection-production well as the second highest risk of the A-annulus when the A-annulus is pressurized and the pressure of the A-annulus exceeds the maximum permissible pressure of the A-annulus.

[0149] The A-annulus third highest risk determination unit 1103 is used to determine the risk level of the injection-production well as the third highest risk in the A-annulus when the A-annulus is pressurized and the difference between the A-annulus pressure and the oil pressure is not greater than the preset pressure difference value.

[0150] In this embodiment of the invention, the A-annular first high-risk determination unit 1101 determines the risk level as the first high risk of the A-annular space when the A-annular pressure is in the third pressure range of the maximum permissible pressure of the A-annular space; the A-annular second high-risk determination unit 1102 determines the risk level as the second high risk of the A-annular space when the A-annular pressure exceeds the maximum permissible pressure of the A-annular space; and the A-annular third high-risk determination unit 1103 determines the risk level as the third high risk of the A-annular space when the difference between the A-annular pressure and the oil pressure is not greater than a preset pressure difference. Determining the risk level based on the above constraints can improve the accuracy of the A-annular high-risk level judgment.

[0151] Figure 12 The diagram shows the structure of the pressure risk relationship establishment module 802 in the injection-production well risk assessment device provided in the twelfth embodiment of the present invention. For ease of explanation, only the parts related to the embodiments of the present invention are shown, and are described in detail below:

[0152] In one embodiment of the present invention, in order to improve the accuracy of the high-risk level judgment of the B-ring, reference is made to... Figure 12 The pressure risk relationship establishment module 802 includes various units used for execution. Figure 5 For details of each step in the corresponding embodiment, please refer to [link / reference]. Figure 5 as well as Figure 5 The relevant descriptions in the corresponding embodiments will not be repeated here. In this embodiment of the invention, the pressure risk relationship establishment module 802 includes a B-ring low-risk determination unit 1201, a B-ring high-risk determination unit 1202, and a B-ring high-risk determination unit 1203.

[0153] The B-annulus low-risk determination unit 1201 is used to determine the risk level of the injection-production well as the B-annulus low-risk difference when the B-annulus is pressurized and the B-annulus pressure is in the first pressure range of the maximum permissible pressure of the B-annulus.

[0154] The risk determination unit 1202 for the B-annulus is used to determine the risk level of the injection-production well as the risk level of the B-annulus when the B-annulus is pressurized and the pressure of the B-annulus is in the second pressure range of the maximum permissible pressure of the B-annulus.

[0155] The B-annulus high-risk determination unit 1203 is used to determine the risk level of injection-production wells as B-annulus high-risk when the B-annulus is pressurized and the B-annulus pressure is in the third pressure range of the maximum permissible pressure of the B-annulus.

[0156] In this embodiment of the invention, the low-risk determination unit 1201 of the B-annulus determines the risk level as the low-risk difference of the B-annulus when the B-annulus is pressurized and the pressure of the B-annulus is within the first pressure range of the maximum permissible pressure of the B-annulus; the medium-risk determination unit 1202 of the B-annulus determines the risk level as medium-risk when the B-annulus is pressurized and the pressure of the B-annulus is within the second pressure range of the maximum permissible pressure of the B-annulus; and the high-risk determination unit 1203 of the B-annulus determines the risk level as high-risk when the B-annulus is pressurized and the pressure of the B-annulus is within the third pressure range of the maximum permissible pressure of the B-annulus. Determining the risk level based on constraints can improve the accuracy of the B-annulus risk level judgment.

[0157] Figure 13 The diagram illustrates the structure of the pressure risk relationship establishment module 802 in the injection-production well risk assessment device provided in the thirteenth embodiment of the present invention. For ease of explanation, only the parts related to the embodiments of the present invention are shown, and are described in detail below:

[0158] In one embodiment of the present invention, in order to improve the accuracy of risk level judgment when both annulus A and annulus B are pressurized, reference is made to... Figure 13 The pressure risk relationship establishment module 802 includes various units used for execution. Figure 6 For details of each step in the corresponding embodiment, please refer to [link / reference]. Figure 6 as well as Figure 6 The relevant descriptions in the corresponding embodiments will not be repeated here. In this embodiment of the invention, the pressure risk relationship establishment module 802 includes a connectivity determination unit 1301, a disconnectivity risk level determination unit 1302, a disconnectivity risk level determination unit 1303, and a connectivity pressure risk relationship establishment unit 1304.

[0159] The connectivity determination unit 1301 is used to determine whether annulus A and annulus B are connected when annulus A is pressurized and annulus B is pressurized.

[0160] The non-connected risk level determination unit 1302 is used to determine the risk level of the injection-production well based on the pressure of the annulus A and the annulus B, respectively, when the annulus A and the annulus B are pressurized and are not connected.

[0161] The non-connected risk level determination unit 1303 is used to take the higher risk level of the injection-production well determined based on the A annular pressure and the B annular pressure as the risk level of the injection-production well.

[0162] The pressure risk relationship establishment unit 1304 is used to establish a pressure risk relationship by taking the maximum permissible pressure of the B annulus as the maximum permissible pressure of the A annulus when both the A annulus and the B annulus are pressurized and the A annulus and the B annulus are connected.

[0163] In this embodiment of the invention, when the annulus A and the annulus B are pressurized and the annulus A and the annulus B are not connected, the non-connectivity risk level determination unit 1303 takes the higher of the injection-production well risk level determined based on the pressure of the annulus A and the injection-production well risk level determined based on the pressure of the annulus B as the risk level of the injection-production well; when the annulus A and the annulus B are pressurized and the annulus A and the annulus B are connected, the connection pressure risk relationship establishment unit 1304 uses the maximum permissible pressure of the annulus B as the maximum permissible pressure of the annulus A to establish a pressure risk relationship. Based on the above constraints, the risk level is determined, which can improve the accuracy of the risk level determination when the annulus A and the annulus B are pressurized.

[0164] Figure 14 The functional modules of the injection-production well risk assessment device provided in the fourteenth embodiment of the present invention are shown. For ease of explanation, only the parts related to the embodiments of the present invention are shown, and are described in detail below:

[0165] In one embodiment of the present invention, the field data of the injection-production well also includes annular fluid level data and / or casing external test data. To improve the accuracy of annular leakage detection, refer to... Figure 14 The injection-production well risk assessment device comprises various units used for execution. Figure 7For details of each step in the corresponding embodiment, please refer to [link / reference]. Figure 7 as well as Figure 7 The relevant descriptions in the corresponding embodiments will not be repeated here. In this embodiment of the invention, based on the above functional modules, the injection-production well risk assessment device further includes a leakage determination module 1401.

[0166] The leakage determination module 1401 is used to determine that there is a leak in the annulus if the change value of the annulus liquid level data in adjacent time intervals is not less than a preset change value, and / or the test data outside the casing reflects that there is gas channeling outside the casing.

[0167] In this embodiment of the invention, if the change value of the annular liquid level data between adjacent time intervals is not less than a preset change value, and / or the test data outside the casing reflects gas channeling outside the casing, the leakage determination module 1401 determines that there is a leak in the annulus; judging whether there is a leak in the annulus based on the above constraints can improve the accuracy of annular leakage judgment.

[0168] This invention also provides a computer device, including a memory, a processor, and a computer program stored in the memory and executable on the processor. When the processor executes the computer program, it implements the above-described injection-production well risk assessment method.

[0169] This invention also provides a computer-readable storage medium storing a computer program that performs the above-described injection-production well risk assessment method.

[0170] In summary, in this embodiment of the invention, the maximum permissible pressures of annulus A and annulus B are first determined; then, a pressure risk relationship is established based on these pressures; the pressures of annulus A and annulus B during the evaluation period of the injection-production well are collected; finally, based on the pressures of annulus A and annulus B during the evaluation period, the risk level of the injection-production well during the evaluation period is determined using the established pressure risk relationship. This embodiment of the invention pre-establishes a pressure risk relationship based on the maximum permissible pressures of annulus A and annulus B, and then determines the risk level of the injection-production well during the evaluation period based on the collected pressures of annulus A and annulus B using the established pressure risk relationship, achieving real-time risk assessment of injection-production wells and improving the accuracy of risk assessment based on the established pressure risk relationship.

[0171] Those skilled in the art will understand that embodiments of the present invention can be provided as methods, systems, or computer program products. Therefore, the present invention can take the form of a completely hardware embodiment, a completely software embodiment, or an embodiment combining software and hardware aspects. Furthermore, the present invention can take the form of a computer program product embodied on one or more computer-usable storage media (including, but not limited to, disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0172] This invention is described with reference to flowchart illustrations and / or block diagrams of methods, apparatus (systems), and computer program products according to embodiments of the invention. It will be understood that each block of the flowchart illustrations and / or block diagrams, and combinations of blocks in the flowchart illustrations and / or block diagrams, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, special-purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, generate instructions for implementing the flowchart illustrations and / or block diagrams. Figure 1 One or more processes and / or boxes Figure 1 A device that provides the functions specified in one or more boxes.

[0173] These computer program instructions may also be stored in a computer-readable storage medium that can direct a computer or other programmable data processing device to function in a particular manner, such that the instructions stored in the computer-readable storage medium produce an article of manufacture including instruction means, which are implemented in a process Figure 1 One or more processes and / or boxes Figure 1 The function specified in one or more boxes.

[0174] These computer program instructions may also be loaded onto a computer or other programmable data processing equipment to cause a series of operational steps to be performed on the computer or other programmable equipment to produce a computer-implemented process, thereby providing instructions that execute on the computer or other programmable equipment for implementing the process. Figure 1 One or more processes and / or boxes Figure 1 The steps of the function specified in one or more boxes.

[0175] The specific embodiments described above further illustrate the purpose, technical solution, and beneficial effects of the present invention. It should be understood that the above descriptions are merely specific embodiments of the present invention and are not intended to limit the scope of protection of the present invention. Any modifications, equivalent substitutions, improvements, etc., made within the spirit and principles of the present invention should be included within the scope of protection of the present invention.

Claims

1. A method for risk assessment of injection-production wells, characterized in that, include: Determine the maximum permissible pressure of annulus A and annulus B respectively; Establish a pressure risk relationship based on the maximum permissible pressure of annulus A and the maximum permissible pressure of annulus B; Pressure-risk relationship reflects the relationship between annular pressure and risk level; Collect field data from injection and production wells; the field data should include at least the A annulus pressure and B annulus pressure during the evaluation period; Based on the pressure of annulus A and annulus B during the evaluation period, the risk level of injection and production wells during the evaluation period is determined using the established pressure risk relationship. Establish a pressure risk relationship based on the maximum permissible pressure of annulus A and the maximum permissible pressure of annulus B, including: In the A-annulus, the pressure fluctuates within the first pressure range of the maximum permissible pressure of the A-annulus, and the risk level of the injection-production well is determined to be the first low risk of the A-annulus. When the A-annulus is pressurized, the A-annulus pressure increases with the temperature during the gas production period, decreases with the temperature during the well shut-in or gas injection period, and the highest pressure of the A-annulus does not exceed the upper limit of the thermally induced annulus pressure of the injection-production well, the risk level of the injection-production well is determined to be the second lowest risk of the A-annulus. If the pressure in annulus A changes periodically with the wellbore temperature, and the pressure in annulus A returns to its initial value when the temperature decreases, then the pressure is considered to be annulus pressure caused by temperature effects. Field data for injection-production wells also includes annular fluid level data and / or external casing test data. Risk assessment methods for injection-production wells also include: If the change in annular liquid level data between adjacent time intervals is not less than the preset change value, and / or the test data outside the casing reflects gas channeling outside the casing, it is determined that there is a leak in the annulus.

2. The risk assessment method for injection-production wells as described in claim 1, characterized in that, Establish a pressure risk relationship based on the maximum permissible pressure of annulus A and the maximum permissible pressure of annulus B, including: When the pressure in annulus A is pressurized, and the rate of change of pressure in annulus A within the second pressure range of the maximum permissible pressure in annulus A is not greater than the preset rate of change of pressure, and the pressure in annulus A is less than the upper limit of the second pressure range of the maximum permissible pressure in annulus A, the risk level of the injection-production well is determined to be risky in annulus A. When the pressure in annulus A is less than the upper limit of the second pressure range of the maximum permissible pressure in annulus A, but shows a gradual upward trend, the risk level of the injection-production well is determined to be high risk in annulus A.

3. The risk assessment method for injection-production wells as described in claim 1, characterized in that, Establish a pressure risk relationship based on the maximum permissible pressure of annulus A and the maximum permissible pressure of annulus B, including: When the pressure in annulus A is within the third pressure range of the maximum permissible pressure in annulus A, the risk level of the injection-production well is determined to be the highest risk in annulus A. When the pressure in annulus A exceeds the maximum permissible pressure in annulus A, the risk level of the injection-production well is determined to be the second highest risk in annulus A. When the pressure difference between the A-annulus and the oil pressure is not greater than the preset pressure difference, the risk level of the injection-production well is determined to be the third highest risk in the A-annulus.

4. The risk assessment method for injection-production wells as described in claim 1, characterized in that, Establish a pressure risk relationship based on the maximum permissible pressure of annulus A and the maximum permissible pressure of annulus B, including: When the B annulus is pressurized and the pressure in the B annulus is within the first pressure range of the maximum permissible pressure in the B annulus, the risk level of the injection-production well is determined to be low risk in the B annulus. When the B annulus is pressurized and the pressure in the B annulus is in the second pressure range of the maximum permissible pressure in the B annulus, the risk level of the injection-production well is determined to be high risk in the B annulus. When the B annulus is pressurized and the pressure in the B annulus is within the third pressure range of the maximum permissible pressure in the B annulus, the risk level of the injection-production well is determined to be high risk in the B annulus.

5. The risk assessment method for injection-production wells as described in claim 1, characterized in that, Establish a pressure risk relationship based on the maximum permissible pressure of annulus A and the maximum permissible pressure of annulus B, including: Determine whether annulus A and annulus B are connected under pressure. When annulus A and annulus B are pressurized, and annulus A and annulus B are not connected, the risk level of injection and production wells is determined based on the pressure of annulus A and the risk level of injection and production wells is determined based on the pressure of annulus B, respectively. The higher of the risk levels of the injection-production well determined based on the A-annular pressure and the risk levels of the injection-production well determined based on the B-annular pressure is taken as the risk level of the injection-production well. When annulus A and annulus B are pressurized, and annulus A and annulus B are connected, the maximum permissible pressure of annulus B is used as the maximum permissible pressure of annulus A to establish a pressure risk relationship.

6. A risk assessment device for injection-production wells, characterized in that, include: The maximum permissible pressure determination module is used to determine the maximum permissible pressure of annulus A and the maximum permissible pressure of annulus B, respectively. The pressure risk relationship establishment module is used to establish pressure risk relationships based on the maximum permissible pressure of annulus A and the maximum permissible pressure of annulus B. Pressure-risk relationship reflects the relationship between annular pressure and risk level; The data acquisition module is used to collect field data from injection and production wells; the field data includes at least the A annulus pressure and B annulus pressure during the evaluation period. The risk level determination module is used to determine the risk level of injection and production wells within the evaluation period based on the A annulus pressure and B annulus pressure within the evaluation period, using the established pressure risk relationship. The stress-risk relationship establishment module includes: The A-annulus first low-risk determination unit is used to determine the risk level of injection and production wells as the A-annulus first low-risk unit when the A-annulus is pressurized and the pressure of the A-annulus fluctuates within the first pressure range of the maximum permissible pressure of the A-annulus. The A-annulus second lowest risk determination unit is used to determine the risk level of the injection-production well as the second lowest risk of the A-annulus when the A-annulus is pressurized, the A-annulus pressure increases with the temperature during the gas production period, the A-annulus pressure decreases with the temperature during the shut-in or gas injection period, and the highest pressure of the A-annulus does not exceed the upper limit of the thermally induced annulus pressure of the injection-production well. Field data for injection-production wells also includes annular fluid level data and / or external casing test data. The risk assessment device for injection-production wells also includes: The leakage determination module is used to determine that there is a leak in the annulus if the change value of the annulus liquid level data in adjacent time intervals is not less than a preset change value, and / or the test data outside the casing reflects that there is gas channeling outside the casing.

7. The injection-production well risk assessment device as described in claim 6, characterized in that, The stress-risk relationship establishment module includes: The risk determination unit in the A-annulus is used to determine the risk level of the injection-production well as the risk level in the A-annulus when the A-annulus is pressurized, the pressure change rate of the A-annulus pressure is not greater than the preset pressure change rate within the second pressure range of the maximum permissible pressure of the A-annulus, and the A-annulus pressure is less than the upper limit of the second pressure range of the maximum permissible pressure of the A-annulus. The high-risk determination unit in annulus A is used to determine the risk level of injection-production wells as high-risk in annulus A when the annulus A pressure is less than the upper limit of the second pressure range of the maximum permissible pressure of annulus A but shows a gradual upward trend.

8. The injection-production well risk assessment device as described in claim 6, characterized in that, The stress-risk relationship establishment module includes: The A-annulus first high-risk determination unit is used to determine the risk level of injection and production wells as the A-annulus first high-risk unit when the A-annulus is pressurized and the pressure of the A-annulus is in the third pressure range of the maximum permissible pressure of the A-annulus. The A-annulus second highest risk determination unit is used to determine the risk level of injection and production wells as the A-annulus second highest risk when the A-annulus is pressurized and the pressure of the A-annulus exceeds the maximum permissible pressure of the A-annulus. The A-annulus third highest risk determination unit is used to determine the risk level of the injection-production well as the third highest risk in the A-annulus when the A-annulus is pressurized and the difference between the A-annulus pressure and the oil pressure is not greater than a preset pressure difference.

9. The injection-production well risk assessment device as described in claim 6, characterized in that, The stress-risk relationship establishment module includes: The B-annulus low-risk determination unit is used to determine the risk level of injection-production wells as low-risk in the B-annulus when the B-annulus is pressurized and the B-annulus pressure is in the first pressure range of the maximum permissible pressure of the B-annulus. The B-annular risk determination unit is used to determine the risk level of injection and production wells as B-annular risk when the B-annular pressure is pressurized and the B-annular pressure is in the second pressure range of the maximum permissible pressure of the B-annular. The B-annulus high-risk determination unit is used to determine the risk level of injection-production wells as B-annulus high-risk when the B-annulus is pressurized and the B-annulus pressure is in the third pressure range of the maximum permissible pressure of the B-annulus.

10. The injection-production well risk assessment device as described in claim 6, characterized in that, The stress-risk relationship establishment module includes: The connectivity determination unit is used to determine whether annulus A and annulus B are connected when annulus A and annulus B are pressurized. The separate risk level determination unit is used to determine the risk level of injection and production wells based on the pressure of annulus A and annulus B, respectively, when annulus A and annulus B are pressurized and are not connected. The non-connected risk level determination unit is used to take the higher risk level of the injection-production well determined based on the A annular pressure and the B annular pressure as the risk level of the injection-production well. The pressure risk relationship establishment unit is used to establish a pressure risk relationship by taking the maximum permissible pressure of the B annulus as the maximum permissible pressure of the A annulus when both the A annulus and the B annulus are pressurized and the A annulus and the B annulus are connected.

11. A computer device, comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, characterized in that, When the processor executes the computer program, it implements the risk assessment method for injection and production wells as described in any one of claims 1 to 5.

12. A computer-readable storage medium, characterized in that, The computer-readable storage medium stores a computer program that executes the risk assessment method for injection and production wells according to any one of claims 1 to 5.

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