Monitoring and early warning method for operation risk of gas storage well and related device

Abstract

The invention discloses a gas storage well operation risk monitoring and early warning method and a related device. The method comprises the following steps: acquiring real-time monitoring data of a shaft; and according to the annulus pressure value in the real-time monitoring data of the wellbore, whether the wellbore has the safety risk or not is predicted, and corresponding early warning is carried out under the condition that it is predicted that the wellbore has the safety risk. Real-time monitoring, evaluation and early warning can be carried out on operation of the gas storage well, so that the safety problem caused by leakage of the gas storage well is effectively prevented.

Description

Technical Field

[0001] The present invention relates to the field of underground gas storage production and operation, and in particular to a monitoring and early warning method for gas storage well operation risks and related devices. Background Art

[0002] At present, my country's gas storage has entered a development stage where both large-scale construction and efficient operation are equally important. The underground system of gas storage has alternating loads, with many risk points. Some storages have been in operation for more than 30 years, and annular pressure is common, and well integrity issues are prominent. Once a leak occurs, the gas storage will be scrapped and seriously threaten public safety. The existing technology generally uses decentralized and single monitoring methods for the operation of gas storage wells.

[0003] There are problems with insufficient coverage of gas storage well operation monitoring types and lack of real-time monitoring and data collection methods. The existing method of post-evaluation through analysis of gas storage well information data is too delayed for the operation risk assessment of a large range of gas storage wells, and it is impossible to achieve real-time monitoring and early warning of gas storage wells. There is a problem of poor real-time warning. In the process of assessing the risks of gas storage wells, the existing technology uses the wellbore related data at the time of leaving the factory, resulting in low accuracy of risk assessment results. Therefore, there is an urgent need for a method for real-time monitoring of gas storage well operation and accurate evaluation and early warning, so as to prevent safety problems caused by leakage of gas storage wells in advance. Summary of the invention

[0004] In the prior art, there is insufficient coverage of gas storage well operation monitoring types, and a lack of real-time monitoring and data collection methods; and the operational risk assessment of a large range of gas storage wells is too lagging, and there is a lack of a real-time early warning integrated system for large-scale gas storage wells. In view of the above problems, an embodiment of the present invention provides a monitoring and early warning method and related devices for the operational risks of a gas storage well.

[0005] In a first aspect, an embodiment of the present invention provides a risk monitoring and early warning method for gas storage well operation, comprising:

[0006] Obtain real-time monitoring data of the wellbore;

[0007] Based on the annular pressure value in the real-time monitoring data of the wellbore, it is predicted whether the wellbore has a safety risk, and when it is predicted that the wellbore has a safety risk, a corresponding early warning is issued.

[0008] In one embodiment, the predicting whether the wellbore has a safety risk based on the annular pressure value in the real-time monitoring data of the wellbore, and issuing a corresponding early warning when predicting that the wellbore has a safety risk, includes:

[0009] If the annular pressure values ​​obtained for several consecutive times continue to rise and the annular pressure values ​​exceed the thermal pressure threshold, the risk of the wellbore is determined to be abnormal annular pressure; the thermal pressure threshold is determined based on the gas pressure generated by the expansion of the liquid and the compression of the gas in the annular space;

[0010] Accordingly, abnormal annular pressure analysis and early warning are carried out on the wellbore.

[0011] In one embodiment, the thermal stress threshold is determined by:

[0012] The thermal stress threshold is calculated using the following formula:

[0013]

[0014] In the above formula, P t is the thermal annular pressure threshold, T0 is the initial annular average temperature, P0 is the pressure, T1 is the average thermodynamic temperature of the gas in the current production annular space, h a is the gas height in the annulus, h1 is the liquid height in the annulus, α is the liquid expansion coefficient, and ΔT is the average temperature change.

[0015] In one embodiment, it further includes:

[0016] Obtain static data of wellbore construction and regular inspection data of wellbore;

[0017] According to the wellbore material data in the wellbore engineering construction static data and the periodic inspection data of the wellbore, respectively determining the residual strength of the oil tubing string, the residual strength of the casing string and the residual strength of the wellhead device of the wellbore;

[0018] Determine the pressure range of the wellbore according to the residual strength of the oil pipe string, the residual strength of the casing string and the residual strength of the wellhead device of the wellbore, wherein the pressure range represents the minimum value of the maximum allowable annular pressure of the wellbore;

[0019] Determine the risk level corresponding to the annular space pressure value according to the interval corresponding to the annular space pressure value in the pressure range;

[0020] According to the risk level corresponding to the annulus pressure value, an annulus pressure graded warning is performed on the wellbore, and the annulus pressure graded warning of the wellbore corresponds to the risk level corresponding to the annulus pressure value.

[0021] In one embodiment, the periodic detection data of the wellbore includes a casing string damage change value and an oil pipe string damage change value;

[0022] According to the wellbore material data in the wellbore engineering construction static data and the regular inspection data of the wellbore, the residual strength of the oil pipe string and the residual strength of the casing string are determined respectively, and further comprising:

[0023] Calculating the residual strength of the casing string according to the wellbore material data and the casing string damage change value, wherein the residual strength of the casing string is the strength of the casing string in the current state;

[0024] The remaining strength of the tubing string is calculated according to the wellbore material data and the damage change value of the tubing string, where the remaining strength of the tubing string is the strength of the tubing string in the current state.

[0025] In one embodiment, the regular inspection data of the wellbore also includes the wellhead device leakage inspection value, the wellbore wall thickness, the wellbore leakage inspection value, the ultrasonic inspection result and the gamma spectrum logging result;

[0026] After obtaining the static data of wellbore construction and the regular inspection data of wellbore, it also includes:

[0027] Determine the remaining life of the casing string according to the casing string damage change value, and if the remaining life of the casing string is greater than a preset casing string remaining life threshold, and the remaining strength of the casing string is greater than a preset casing string remaining strength threshold, then judge that the casing string is in a safe state;

[0028] Determine the remaining life of the tubing string according to the tubing string damage change value; if the remaining life of the tubing string is greater than a preset remaining life threshold of the tubing string, and the remaining strength of the tubing string is greater than a preset remaining strength threshold of the tubing string, then determine that the tubing string is in a safe state;

[0029] According to the wellbore material data, a first wall thickness threshold of the wellbore is determined, wherein the first wall thickness threshold is a theoretical minimum wall thickness required for the wellbore internal pressure; according to the first wall thickness threshold and a preset wellbore corrosion allowance value, a second wall thickness threshold of the wellbore is obtained, and if the wall thickness of the wellbore is greater than the second wall thickness threshold, it is determined that the remaining wall thickness of the wellhead device reaches a preset standard;

[0030] Determining the buried defect level of the wellbore according to the ultrasonic detection result;

[0031] If the remaining wall thickness of the wellhead device reaches a preset standard and the buried defect level is less than a preset buried defect level threshold, it is judged that the wellhead device is in a safe state;

[0032] If the wellbore leakage detection value is less than a preset wellbore leakage threshold, it is determined that the tubing string and the casing string are in a sealed state;

[0033] If the wellhead device leakage detection value is less than a preset wellhead device leakage threshold, it is determined that the wellhead device is in a sealed state;

[0034] If the gamma spectroscopy logging result does not detect continuous flowable gas accumulation, it is determined that the cement sheath of the wellbore is in a sealed state.

[0035] In one embodiment, the method further comprises:

[0036] If the wellhead gas leakage value in the real-time monitoring data exceeds a preset wellhead leakage threshold, it is determined that the wellbore has a wellhead leakage risk; correspondingly, a wellhead leakage warning is issued for the wellbore;

[0037] If the wellhead uplift value in the real-time monitoring data exceeds a preset wellhead uplift threshold, it is determined that the wellbore has a wellhead uplift risk; correspondingly, a wellhead uplift warning is issued for the wellbore;

[0038] If the annulus liquid level value in the real-time monitoring data is lower than the preset annulus liquid level threshold, or the annulus liquid level value of the real-time monitoring data continues to decrease for several times, it is determined that the wellbore has an annulus liquid level risk, and accordingly, an annulus liquid level warning is issued for the wellbore.

[0039] In a second aspect, an embodiment of the present invention provides a risk monitoring and early warning device for gas storage well operation, comprising:

[0040] An acquisition module, used to acquire real-time monitoring data of the wellbore;

[0041] The risk monitoring and early warning module is used to predict whether the wellbore has a safety risk based on the annular space pressure value in the real-time monitoring data of the wellbore, and to issue a corresponding early warning when it is predicted that the wellbore has a safety risk.

[0042] In a third aspect, an embodiment of the present invention provides a computer storage medium, wherein the computer storage medium stores computer executable instructions, and when the computer executable instructions are executed by a processor, the above-mentioned risk monitoring and early warning method for gas storage well operation is implemented.

[0043] In a fourth aspect, an embodiment of the present invention provides a terminal device, comprising: a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein when the processor executes the program, the above-mentioned risk monitoring and early warning method for gas storage well operation is implemented.

[0044] In a fifth aspect, an embodiment of the present invention provides a computer program product, which includes a computer program, and when the computer program is executed by a processor, it implements the above-mentioned risk monitoring and early warning method for gas storage well operation.

[0045] The beneficial effects of the above technical solution provided by the embodiment of the present invention include at least:

[0046] The risk monitoring and early warning method for gas storage well operation provided by the embodiment of the present invention realizes real-time safety risk monitoring of the gas storage well according to the real-time monitoring data of the wellbore. When the gas storage well has safety risks, the gas storage well is given an early warning corresponding to the predicted safety risks. The risks existing in the wellbore can be predicted in time through the real-time monitoring data, which solves the problem of poor real-time prediction of gas storage safety risks in the prior art, and ensures the safe operation of the gas storage and improves the daily risk management and control capabilities.

[0047] Furthermore, the risk monitoring and early warning method for gas storage well operation provided by the embodiment of the present invention determines the remaining strength and remaining life of the casing string by obtaining the casing string damage change value in the regular inspection data of the wellbore, and then determines whether the casing string is in a safe state; obtains the oil tubing string damage change value, determines the remaining strength and remaining life of the oil tubing string, and then determines whether the oil tubing string is in a safe state; determines the second wall thickness threshold value according to the wellbore material data in the static data of the engineering construction of the wellbore, and if the remaining wall thickness of the wellhead device is greater than the second wall thickness threshold value, determines that the remaining wall thickness of the wellhead device reaches a preset standard; determines the sealing of the oil tubing string, casing string, wellhead device and cement ring according to the regular inspection data of the wellbore, and uses the data of the wellbore in the current state. Compared with the use of the initial data of the wellbore in the prior art, it can more accurately evaluate whether the oil tubing string, casing string and wellhead device of the wellbore are in a safe state, and more accurately evaluate whether the oil tubing string, casing string, wellhead device and cement ring are in a sealed state.

[0048] Other features and advantages of the present invention will be described in the following description, and partly become apparent from the description, or understood by practicing the present invention. The purpose and other advantages of the present invention can be realized and obtained by the structures particularly pointed out in the written description, claims, and drawings.

[0049] The technical solution of the present invention is further described in detail below through the accompanying drawings and embodiments. BRIEF DESCRIPTION OF THE DRAWINGS

[0050] The accompanying drawings are used to provide a further understanding of the present invention and constitute a part of the specification. Together with the embodiments of the present invention, they are used to explain the present invention and do not constitute a limitation of the present invention. In the accompanying drawings:

[0051] Figure 1 Flow chart of a method for risk monitoring and early warning of gas storage well operation in an embodiment of the present invention;

[0052] Figure 2 It is a flow chart of a method for early warning of annular pressure classification of a wellbore in an embodiment of the present invention;

[0053] Figure 3 This is a schematic diagram of the cloud diagram display effect of the safety factor of the well barrier in an embodiment of the present invention;

[0054] Figure 4 It is a schematic diagram of the annular pressure classification plate of a certain well in an embodiment of the present invention;

[0055] Figure 5 This is one of the structural schematic diagrams of a risk monitoring and early warning device for determining the operation of a gas storage well in an embodiment of the present invention;

[0056] Figure 6 This is the second structural schematic diagram of the risk monitoring and early warning device for determining the operation of a gas storage well in an embodiment of the present invention. DETAILED DESCRIPTION

[0057] The exemplary embodiments of the present disclosure will be described in more detail below with reference to the accompanying drawings. Although the exemplary embodiments of the present disclosure are shown in the accompanying drawings, it should be understood that the present disclosure can be implemented in various forms and should not be limited by the embodiments set forth herein. On the contrary, these embodiments are provided to enable a more thorough understanding of the present disclosure and to fully convey the scope of the present disclosure to those skilled in the art.

[0058] The inventors found in their work that, in the prior art, the operational risk assessment of a large-scale gas storage well is relatively lagging, and it is impossible to achieve real-time monitoring and early warning of the gas storage wells, resulting in poor real-time warning. After further research and development, the inventors made the present invention. The embodiments of the present invention provide a monitoring and early warning method and related devices for the operational risks of a gas storage well.

[0059] Example

[0060] The following is a detailed description of the risk monitoring and early warning method for gas storage well operation in conjunction with an embodiment.

[0061] The embodiment of the present invention provides a risk monitoring and early warning method for gas storage well operation, the process of which is as follows: Figure 1 As shown, the following steps are included:

[0062] Step S1: obtaining real-time monitoring data of the wellbore;

[0063] Step S2: predict whether the real-time monitoring data wellbore has a safety risk based on the annular pressure value in the real-time monitoring data wellbore, and issue a corresponding warning when it is predicted that the real-time monitoring data wellbore has a safety risk.

[0064] In some optional embodiments, in the above step S1, the real-time monitoring data of the wellbore is obtained through the monitoring hardware deployed at each wellhead and well site. The monitoring hardware is a device for real-time monitoring of the operation of the gas storage well. For example, the wellhead oil pressure detection equipment can monitor the wellhead oil pressure value of the wellbore in real time, the annular pressure monitoring equipment at each level can monitor the annular pressure at each level in real time, the wellhead gas leakage monitoring equipment can monitor the wellhead gas leakage value in real time, the wellhead lifting monitoring equipment can monitor the wellhead lifting value in real time, the annular liquid level monitoring equipment can monitor the annular liquid level value in real time, etc. Specifically, for example, the monitoring hardware shown in Table 1 is deployed at each wellhead and well site, and the data acquisition software is deployed at the site station. The data acquisition software can collect the data detected by the monitoring hardware in real time:

[0065] Table 1:

[0066]

[0067]

[0068] In some optional embodiments, the above step S2, predicting whether the wellbore has a safety risk according to the annular pressure value in the real-time monitoring data of the wellbore, and performing a corresponding early warning when predicting that the wellbore has a safety risk, can be implemented in the following manner:

[0069] If the annular pressure values ​​obtained for several consecutive times continue to rise and exceed the thermally induced pressure threshold, it is determined that the wellbore has the risk of abnormal annular pressure; the thermally induced pressure threshold is determined based on the gas pressure generated by the expansion of the liquid and the compression of the gas in the annulus; accordingly, the wellbore is evaluated and warned of abnormal annular pressure.

[0070] The remote pressure transmitter can be used to monitor the annular pressures at all levels at the wellhead in real time. By continuously monitoring the annular pressure values ​​of the wellbore for several times, the dynamic changes of the annular pressure can be obtained. At the same time, considering the influence of thermally induced annular pressure, abnormal annular pressure prompts can be given. If the annular pressure values ​​measured for several consecutive times continue to rise and exceed the thermally induced pressure threshold, it can be determined as abnormal annular pressure.

[0071] The thermal pressure threshold is the maximum gas pressure generated by the expansion of liquid and compression of gas in the closed annulus due to the temperature rise. The thermal pressure threshold can be calculated using the following formula:

[0072]

[0073] In the above formula, P tis the thermal annular pressure threshold, in MPa; T0 is the initial annular average temperature, which is the average thermodynamic temperature of the formation from the wellhead to the depth of the annular liquid surface, in K; P0 is the pressure, in MPa; T1 is the average thermodynamic temperature of the gas in the current production annular space, in K; h a is the gas height in the annulus; h1 is the liquid height in the annulus; α is the liquid expansion coefficient; ΔT is the average temperature change, and ΔT can be obtained by equalizing T1-T0.

[0074] The gas storage well has multiple annuli. The annular pressure values ​​of each level of annulus are monitored in real time by remote pressure transmitters. For the annular pressure values ​​of each level of annulus monitored in real time, if the annular pressure values ​​continue to rise and exceed the thermal pressure threshold, it is determined that the wellbore has the risk of abnormal annular pressure. In other words, by real-time monitoring of the annular pressure values, it is possible to determine in real time whether the wellbore has the risk of abnormal annular pressure. Furthermore, when it is predicted that the wellbore has the risk of abnormal annular pressure, the wellbore is evaluated and warned of the abnormal annular pressure corresponding to the risk of abnormal annular pressure in real time, thus realizing real-time monitoring and early warning of gas storage wells and solving the problems of lagging operation risk assessment and poor real-time warning of gas storage wells.

[0075] In some optional embodiments, the risk monitoring and early warning method for gas storage well operation provided by the embodiment of the present invention can also provide annular pressure classification early warning for the wellbore. Specifically, Figure 2 As shown, this can be achieved in the following ways:

[0076] Step S21: Obtaining static data of wellbore construction and regular inspection data of the wellbore;

[0077] Step S22: Determine the residual strength of the tubing string, the residual strength of the casing string, and the residual strength of the wellhead device according to the wellbore material data and the regular inspection data of the wellbore in the static data of the wellbore engineering construction;

[0078] Step S23: Determine the pressure range of the wellbore according to the residual strength of the tubing string, the residual strength of the casing string and the residual strength of the wellhead device, the pressure range represents the minimum value of the maximum allowable annular pressure of the wellbore;

[0079] Step S24: Determine the risk level corresponding to the annular pressure value according to the interval corresponding to the annular pressure value in the pressure range;

[0080] Step S25: According to the risk level corresponding to the annular pressure value, the wellbore is given an annular pressure graded warning, and the annular pressure graded warning of the wellbore corresponds to the risk level corresponding to the annular pressure value.

[0081] In some optional embodiments, in the above-mentioned step S21, the periodic inspection data of the wellbore is data obtained by regularly inspecting the wellbore during the operation of the gas storage well. For example, in accordance with relevant standards, the wellbore's tubing damage data (casing string damage data and oil tubing string damage data), cementing quality data, wellhead device strength and wellhead device sealing data, etc. can be regularly tested to obtain tubing damage changes, wellhead device leakage detection values, barrel wall thickness, wellbore leakage detection values, ultrasonic detection results and gamma spectroscopy logging results.

[0082] In contrast to the regular inspection data of the wellbore is the static data of the wellbore's engineering construction. The static data of the wellbore's engineering construction is obtained through the history of each drilling and completion well, geological summary and other information, so the static data of the wellbore's engineering construction does not change with time.

[0083] In some optional embodiments, the above step S22, based on the wellbore material data in the wellbore engineering construction static data and the wellbore periodic inspection data, respectively determines the remaining strength of the oil pipe string and the remaining strength of the casing string, which can be achieved in the following ways:

[0084] According to the wellbore material data and the casing string damage change value, the casing string residual strength is calculated. The casing string residual strength is the strength of the casing string in the current state.

[0085] The residual strength of the tubing string is calculated based on the wellbore material data and the damage change value of the tubing string. The residual strength of the tubing string is the strength of the tubing string in the current state.

[0086] In some optional embodiments, the above step is 23. Since the strength of the oil tubing string and the casing string of the wellbore will gradually decrease over time under the action of corrosion, the residual strength of the oil tubing string is the strength of the oil tubing string in the current state obtained by tubing damage detection, and the residual strength of the casing string is the strength of the casing string in the current state obtained by tubing damage detection. The residual strength of the oil tubing string and the residual strength of the casing string are reduced compared to the initial strength at the factory, which can reflect the current pressure-bearing capacity of the oil tubing string and the casing string; according to the verification of the residual strength of the oil tubing string, the casing string and the wellhead device of the wellbore, at the same time, the influence of the external squeezing force of the annular space liquid surface of the wellbore on the inner layer of the wellbore tubing and the internal pressure force of the outer layer of the tubing, within the preset safety margin, the pressure-bearing range of the wellbore can be obtained, and the pressure-bearing range can characterize the maximum allowable value of the annular space pressure at each level of the wellhead.

[0087] The pressure range is divided into intervals, and the level risk of the annulus pressure is determined according to the corresponding intervals of the annulus pressure values ​​in the real-time monitoring data within the pressure range; accordingly, a graded annulus pressure warning is carried out for the wellbore.

[0088] In some optional embodiments, the pressure range is divided into intervals. For example, the range less than 60% of the pressure range can be divided into an interval, which indicates that the annulus of the wellbore is in the normal pressure range during production and can be produced normally. The range between 60% of the pressure range and 70% of the pressure range is divided into an interval, which indicates that the annulus pressure value of the annulus needs to be monitored more intensively; the range between 70% of the pressure range and 80% of the pressure range is divided into an interval, which indicates that the annulus pressure is in a relatively high dangerous state and it is necessary to diagnose the annulus pressure type and analyze the leakage point and leakage flow; the range between 80% of the pressure range and the pressure range is divided into an interval, which indicates that the annulus pressure is in a dangerous state and certain control measures need to be taken, such as shutting in the well and repairing the well.

[0089] In addition, each divided interval can be represented by a different color, such as Figure 3 As shown in Table 3, the annular pressure classification chart of the well is formed. According to the interval corresponding to the annular pressure value and the oil pressure value, the risk level of the annular pressure is determined, and the risk warning of the well is given by the interval color corresponding to the annular pressure value, as shown in Table 3:

[0090] Table 3:

[0091] Pressure threshold range color 80%*Maximum allowable pressure < annular pressure ≤ Maximum allowable pressure red 70%*maximum allowable pressure < annular pressure ≤ 80%*maximum allowable pressure orange color 60%*maximum allowable pressure<annular pressure≤70*maximum allowable pressure yellow Annular pressure ≤ 60%* maximum allowable pressure green

[0092] The annular pressure is graded and distinguished by color in the above table. The green area is the recommended pressure range. When entering the yellow area, the annular pressure needs to be closely monitored. When entering the orange area, the pressure needs to be relieved and the cause of the annular pressure needs to be diagnosed. Once entering the red area, the wellbore integrity risk will be very high and well repair measures need to be taken. During production operation, it should be ensured that the wellhead annular pressure of the injection and production well is in the green area in the figure. When the annular pressure enters the orange area, diagnostic tests need to be carried out to analyze the source of the annular pressure and the leakage flow and location. When the actual annular pressure is in the red area, control measures should be taken and the well should be repaired in time.

[0093] It should be noted that the residual strength of the wellhead device, the residual strength of the casing string and the residual strength of the tubing string obtained through regular wellbore inspection data can also be used as basic data for predicting risk warnings.

[0094] In some optional embodiments, based on the real-time monitoring data of the wellbore, predicting whether the wellbore has a safety risk, and in the case of predicting that the wellbore has a safety risk, issuing a corresponding warning, including:

[0095] If the wellhead gas leakage value exceeds the preset wellhead leakage threshold, it is determined that the wellbore has a wellhead leakage risk; accordingly, a wellhead leakage warning is issued for the wellbore;

[0096] If the wellhead uplift value exceeds the preset wellhead uplift threshold, it is determined that the wellbore has a wellhead uplift risk; accordingly, a wellhead uplift warning is issued for the wellbore;

[0097] If the annular liquid level value is lower than the preset annular liquid level threshold, or the annular liquid level value of several real-time monitoring data continues to decrease, it is determined that the wellbore has an annular liquid level risk, and accordingly, an annular liquid level warning is issued for the wellbore.

[0098] The annulus liquid level threshold can be calculated by the depth of the packer*annulus filling coefficient. For example, the filling coefficient can be 0.9 to 0.96.

[0099] Among them, the continuous decrease in the annular liquid level values ​​of several real-time monitoring data may mean that the difference between two measured values ​​of the annular liquid level within one year exceeds 100m.

[0100] In some optional embodiments, after obtaining the static data of the wellbore construction and the regular inspection data of the wellbore, it is also possible to evaluate whether the wellbore is in a safe state and whether the wellbore is in a sealed state in the following manner:

[0101] (1) Determine the remaining life of the casing string according to the change value of the casing string damage. If the remaining life of the casing string is greater than a preset remaining life threshold of the casing string, and the remaining strength of the casing string is greater than a preset remaining strength threshold of the casing string, then it is determined that the casing string is in a safe state;

[0102] (2) Determine the remaining life of the tubing string based on the change value of the tubing string damage. If the remaining life of the tubing string is greater than a preset remaining life threshold of the tubing string, and the remaining strength of the tubing string is greater than a preset remaining strength threshold of the tubing string, then the tubing string is judged to be in a safe state;

[0103] (3) Determine a first wall thickness threshold of the wellbore based on the wellbore material data, where the first wall thickness threshold is the theoretical minimum wall thickness required for the wellbore internal pressure; obtain a second wall thickness threshold of the wellbore based on the first wall thickness threshold and a preset wellbore corrosion allowance value; if the wellbore wall thickness is greater than the second wall thickness threshold, determine that the remaining wall thickness of the wellhead device meets the preset standard;

[0104] The corrosion allowance S can be an empirical value, for example, S=4.5mm.

[0105] (4) Determine the buried defect level of the wellbore based on the ultrasonic testing results;

[0106] If the remaining wall thickness of the wellhead device reaches the preset standard and the buried defect level is less than the preset buried defect level threshold, the wellhead device is judged to be in a safe state;

[0107] (5) If the wellbore leakage detection value is less than a preset wellbore leakage threshold, it is determined that the tubing string and the casing string are in a sealed state;

[0108] (6) If the wellhead device leakage detection value is less than a preset wellhead device leakage threshold, it is determined that the wellhead device is in a sealed state;

[0109] (7) If the gamma spectroscopy logging results do not show continuous flowable gas accumulation, it is judged that the cement sheath of the wellbore is in a sealed state.

[0110] Among them, in the process of calculating the residual strength of the casing string and the residual strength of the oil tubing string, the residual internal pressure resistance, external collapse resistance and tensile strength of the production casing string or oil tubing string in the entire well section are safely checked by using the principles of material mechanics and tubing mechanics. In other words, the safety factor = actual maximum load / residual strength, and the indicators are the residual internal pressure resistance safety factor ≥ 1.1, the residual external collapse resistance safety factor ≥ 1.0, and the residual internal pressure resistance safety factor ≥ 1.3.

[0111] The remaining life calculation is mainly to obtain the minimum wall thickness required for the safe operation of the pipe string under a certain internal pressure condition through the principles of material mechanics, etc. This wall thickness is added with a certain safety margin (the empirical value can be 1.5mm) as the critical wall thickness. The remaining life is the time required for the pipe string to corrode from the current wall thickness to the critical wall thickness under uniform corrosion conditions (i.e. T = (current wall thickness - critical wall thickness) / corrosion rate). According to experience, the remaining life is generally required to be ≥10 years. If it is less than 10 years, more frequent inspections are required, or the internal pressure is reduced.

[0112] In contrast to the existing methods of obtaining residual strength, such as selecting the minimum wall thickness data for two-dimensional verification, the embodiments of the present invention comprehensively use theories such as material mechanics, tubular mechanics, and finite element analysis to carry out calculations, establish a three-dimensional model of field detection data, and realize visual three-dimensional evaluation. For example, by using logging methods such as "multi-arm wellbore + electromagnetic flaw detection", the orientation, wellbore, wall thickness and other information reflected by dozens of "multi-arm wellbore + electromagnetic flaw detection" curves are analyzed to establish a three-dimensional model of tubular inner diameter damage, which can more accurately reflect the actual tubular damage. On this basis, the residual strength and remaining life evaluation calculations of the tubular can be carried out to more accurately predict whether there are safety risks in the wellbore and provide risk warnings.

[0113] The above judgment on whether the casing string and the oil tubing string are in a sealed state can be determined by downhole leakage detection instruments (noise, ultrasonic type); it can also be qualitatively judged by the annulus liquid level and the annulus pressure: the specific method is; if the annulus liquid level drops by more than 50m for two consecutive tests, it is determined that the A annulus oil tubing string-packer is leaking; in the annulus pressure relief recovery test, the A annulus is kept sealed and pressurized, and the B annulus is closed after being emptied. If the pressure of the B annulus rises slowly and the pressure of the A annulus drops, and they change synchronously, the pressures of the A and B annulus will eventually become consistent; when the A annulus is emptied, the pressure of the B annulus drops during the release of the A annulus, but the rate of decrease is lower than that of the A annulus, it can be determined that the production casing is not sealed.

[0114] In the process of judging whether the cement ring of the wellbore is in a sealed state, the commonly used acoustic amplitude / variable density and ultrasonic logging methods for cementing quality detection can be used. This type of logging method detects whether the bonding surface between the cement ring and the casing, and between the cement ring and the formation is tightly fitted. If the cementing quality of the cap layer section in the logging result is continuously high-quality and exceeds the preset threshold, it is considered that the cement ring has good sealing performance. For example, the preset threshold is 25m. In addition, radioactive logging methods such as gamma spectroscopy can be used. This logging method can be detected in the oil pipe to detect whether there is gas accumulation outside the casing. In the embodiment of the present invention, the radioactive logging methods such as gamma spectroscopy, specifically, are as follows: detection is performed respectively when the B annulus is pressurized and when the B annulus is emptied, so as to compare whether there is flowable gas accumulation outside the casing. If no continuous flowable gas accumulation is detected in the cap layer section of the gas storage reservoir, it is considered that the cement ring has good sealing performance.

[0115] In addition, the detection data of the casing string, the oil pipe string and the cement ring of the wellbore can be used to build a three-dimensional model, and the cloud map of the wellbore barrier safety factor can be displayed on the established three-dimensional model. The display effect is as follows: Figure 3 shown.

[0116] Based on the regular inspection data of the wellbore, the safety and sealing status of the gas storage well are evaluated. The evaluation object, inspection data source and algorithm are shown in Table 2.

[0117] Table 2 Evaluation objects, detection data sources and algorithms

[0118]

[0119] Based on the same inventive concept, the embodiment of the present invention also provides a risk monitoring and early warning device for gas storage well operation. The structure of the device is as follows: Figure 4 As shown, including:

[0120] An acquisition module 31 is used to acquire real-time monitoring data of the wellbore;

[0121] A risk warning module 32 is used to predict whether the wellbore has a safety risk based on the annular pressure value in the real-time monitoring data of the wellbore, and to issue a corresponding warning when it is predicted that the wellbore has a safety risk;

[0122] In some optional embodiments, the acquisition module includes a monitoring hardware module, a data acquisition module and a database module, wherein the monitoring hardware module is provided with equipment for real-time monitoring of the operation of the gas storage well, capable of realizing the functions of real-time measurement of data and remote communication transmission, wherein the equipment for real-time monitoring includes a wellhead oil pressure monitor and various levels of annular pressure monitors, a wellhead gas leakage monitor, a wellhead lift monitor, annular liquid level monitor, etc.

[0123] The data acquisition module can collect the real-time monitoring data monitored in the monitoring hardware module and transmit the real-time monitoring data to the database module.

[0124] The database module is used to call the static data of engineering construction of each wellbore and real-time monitoring and dynamic data of engineering construction, etc. The database module can be a tree-like hierarchy, and its hierarchy includes: gas storage type, gas storage group, gas storage and single well.

[0125] The evaluation module and the risk warning module can interact and communicate with the database module to issue early warnings and conduct well integrity evaluation on the real-time monitoring data stored in the database module.

[0126] In some optional embodiments, such as Figure 5 As shown, the risk monitoring and early warning device for gas storage well operation can also include a decision support module, which can form an intelligent diagnosis workflow through big data analysis, machine learning and other algorithms, diagnose and analyze risk causes, quantitatively evaluate risk levels, predict potential risk factors, etc., and provide management and control measures for high-risk wells.

[0127] Among them, the data provided for machine learning of the decision support module are the data of previous wellbore inspections, and the integrity evaluations are the data of previous integrity evaluations. Specifically, the wellbore of the gas storage reservoir needs to be inspected and evaluated for integrity every 3-5 years. If it is carried out 4 times within 20 years, then these four times are the results of previous inspections.

[0128] Regarding the risk monitoring and early warning device for gas storage well operation in the above-mentioned embodiment, the specific manner in which each module performs operations has been described in detail in the embodiment of the method, and will not be elaborated here.

[0129] Based on the same inventive concept, an embodiment of the present invention further provides a computer storage medium, in which computer executable instructions are stored. When the computer executable instructions are executed by a processor, the above-mentioned method for evaluating the effectiveness of cathodic protection of a pipeline in a blind area of ​​a crossing section or the above-mentioned method for constructing a polarization potential threshold table for a pipeline in a blind area of ​​a crossing section can be implemented.

[0130] Based on the same inventive concept, an embodiment of the present invention also provides a terminal device, including: a memory, a processor, and a computer program stored in the memory and executable on the processor. When the processor executes the program, the method for evaluating the effectiveness of cathodic protection of a pipeline in a blind area of ​​a crossing section or the method for constructing a polarization potential threshold table for a pipeline in a blind area of ​​a crossing section is implemented.

[0131] Based on the same inventive concept, an embodiment of the present invention also provides a computer program product, characterized in that the computer program product includes a computer program, and when the computer program is executed by a processor, it implements the above-mentioned method for evaluating the effectiveness of cathodic protection of a pipeline in a blind area of ​​a crossing section or the above-mentioned method for constructing a polarization potential threshold table for a pipeline in a blind area of ​​a crossing section.

[0132] Unless otherwise specifically stated, terms such as processing, computing, calculating, determining, displaying, etc. may refer to the actions and / or processes of one or more processing or computing systems, or similar devices, which operate and convert data represented as physical (e.g., electronic) quantities within registers or memories of a processing system into other data similarly represented as physical quantities within memories, registers, or other such information storage, transmission, or display devices of the processing system. Information and signals may be represented using any of a variety of different techniques and methods. For example, data, instructions, commands, information, signals, bits, symbols, and chips mentioned throughout the above description may be represented by voltages, currents, electromagnetic waves, magnetic fields or particles, light fields or particles, or any combination thereof.

[0133] It should be understood that the specific order or hierarchy of steps in the disclosed process is an example of an exemplary method. Based on design preferences, it should be understood that the specific order or hierarchy of steps in the process can be rearranged without departing from the scope of protection of the present disclosure. The attached method claims present the elements of the various steps in an exemplary order and are not intended to be limited to the specific order or hierarchy described.

[0134] In the above detailed description, various features are grouped together in a single embodiment to simplify the disclosure. This method of disclosure should not be interpreted as reflecting an intention that the embodiments of the claimed subject matter require more features than are clearly stated in each claim. On the contrary, as reflected in the appended claims, the invention is in a state of having less than all the features of the disclosed individual embodiments. Therefore, the appended claims are hereby expressly incorporated into the detailed description, with each claim standing on its own as a separate preferred embodiment of the invention.

[0135] Those skilled in the art will also appreciate that the various illustrative logic blocks, modules, circuits, and algorithmic steps described in conjunction with the embodiments herein can all be implemented as electronic hardware, computer software, or a combination thereof. In order to clearly illustrate the interchangeability between hardware and software, various illustrative components, blocks, modules, circuits, and steps are generally described above around their functions. Whether such functions are implemented as hardware or software depends on specific applications and the design constraints imposed on the entire system. A skilled person can implement the described functions in an alternative manner for each specific application, but such implementation decisions should not be interpreted as departing from the scope of protection of the present disclosure.

[0136] The steps of the method or algorithm described in conjunction with the embodiments herein may be directly embodied as hardware, a software module executed by a processor, or a combination thereof. The software module may be located in a RAM memory, a flash memory, a ROM memory, an EPROM memory, an EEPROM memory, a register, a hard disk, a mobile disk, a CD-ROM, or any other form of storage medium well known in the art. An exemplary storage medium is connected to the processor so that the processor can read information from the storage medium and can write information to the storage medium. Of course, the storage medium may also be an integral part of the processor. The processor and the storage medium may be located in an ASIC. The ASIC may be located in a user terminal. Of course, the processor and the storage medium may also be present in a user terminal as discrete components.

[0137] For software implementation, the techniques described in this application can be implemented with modules (e.g., procedures, functions, etc.) that perform the functions described in this application. These software codes can be stored in a memory unit and executed by a processor. The memory unit can be implemented within the processor or outside the processor. In the latter case, it is coupled to the processor in a communication manner via various means, which are well known in the art.

[0138] The above description includes examples of one or more embodiments. Of course, it is impossible to describe all possible combinations of components or methods for the purpose of describing the above embodiments, but it should be recognized by those skilled in the art that the various embodiments may be further combined and arranged. Therefore, the embodiments described herein are intended to cover all such changes, modifications and variations that fall within the scope of protection of the appended claims. In addition, with respect to the term "comprising" used in the specification or claims, the word is covered in a manner similar to the term "including", just as "including," is explained as a transitional word in the claims. In addition, any term "or" used in the specification of the claims is intended to mean "non-exclusive or".

Claims

1. A risk monitoring and early warning method for gas storage well operation, characterized in that: include: Obtain real-time monitoring data of the wellbore; Based on the annular pressure value in the real-time monitoring data of the wellbore, it is predicted whether the wellbore has a safety risk, and when it is predicted that the wellbore has a safety risk, a corresponding early warning is issued.

2. The method according to claim 1, characterized in that The method of predicting whether the wellbore has a safety risk according to the annular pressure value in the real-time monitoring data of the wellbore, and issuing a corresponding early warning when predicting that the wellbore has a safety risk, includes: If the annular pressure values ​​obtained for several consecutive times continue to rise and the annular pressure values ​​exceed the thermal pressure threshold, it is determined that the wellbore has the risk of abnormal annular pressure; the thermal pressure threshold is determined based on the gas pressure generated by the expansion of liquid and compression of gas in the annular space; Accordingly, abnormal annular pressure analysis and early warning are carried out on the wellbore.

3. The method according to claim 2, characterized in that The thermally induced stress threshold is determined in the following manner: The thermal stress threshold is calculated using the following formula: In the above formula, P t is the thermal annular pressure threshold, T0 is the initial annular average temperature, P0 is the pressure, T1 is the average thermodynamic temperature of the gas in the current production annular space, h a is the gas height in the annulus, h l is the height of the liquid in the annulus, α is the liquid expansion coefficient, and ΔT is the average temperature change.

4. The method according to claim 1, characterized in that Also includes: Obtain static data of wellbore construction and regular inspection data of wellbore; According to the wellbore material data in the wellbore engineering construction static data and the periodic inspection data of the wellbore, respectively determining the residual strength of the oil tubing string, the residual strength of the casing string and the residual strength of the wellhead device of the wellbore; Determine the pressure range of the wellbore according to the residual strength of the oil pipe string, the residual strength of the casing string and the residual strength of the wellhead device of the wellbore, wherein the pressure range represents the minimum value of the maximum allowable annular pressure of the wellbore; Determine the risk level corresponding to the annular space pressure value according to the interval corresponding to the annular space pressure value in the pressure range; According to the risk level corresponding to the annulus pressure value, an annulus pressure graded warning is performed on the wellbore, and the annulus pressure graded warning of the wellbore corresponds to the risk level corresponding to the annulus pressure value.

5. The method according to claim 4, characterized in that The regular inspection data of the wellbore includes the damage change value of the casing string and the damage change value of the oil pipe string; According to the wellbore material data in the wellbore engineering construction static data and the regular inspection data of the wellbore, the residual strength of the oil pipe string and the residual strength of the casing string are determined respectively, and further comprising: Calculating the residual strength of the casing string according to the wellbore material data and the casing string damage change value, wherein the residual strength of the casing string is the strength of the casing string in the current state; The remaining strength of the tubing string is calculated according to the wellbore material data and the damage change value of the tubing string, where the remaining strength of the tubing string is the strength of the tubing string in the current state.

6. The method according to claim 5, characterized in that The regular inspection data of the wellbore also includes the leakage detection value of the wellhead device, the wall thickness, the leakage detection value of the wellbore, the ultrasonic inspection results and the gamma spectrum logging results; After obtaining the static data of the wellbore construction and the regular inspection data of the wellbore, it also includes: Determine the remaining life of the casing string according to the casing string damage change value, and if the remaining life of the casing string is greater than a preset casing string remaining life threshold, and the remaining strength of the casing string is greater than a preset casing string remaining strength threshold, then judge that the casing string is in a safe state; Determine the remaining life of the tubing string according to the tubing string damage change value; if the remaining life of the tubing string is greater than a preset remaining life threshold of the tubing string, and the remaining strength of the tubing string is greater than a preset remaining strength threshold of the tubing string, then determine that the tubing string is in a safe state; According to the wellbore material data, a first wall thickness threshold of the wellbore is determined, wherein the first wall thickness threshold is a theoretical minimum wall thickness required for the wellbore internal pressure; according to the first wall thickness threshold and a preset wellbore corrosion allowance value, a second wall thickness threshold of the wellbore is obtained, and if the wall thickness of the wellbore is greater than the second wall thickness threshold, it is determined that the remaining wall thickness of the wellhead device reaches a preset standard; Determining the buried defect level of the wellbore according to the ultrasonic detection result; If the remaining wall thickness of the wellhead device reaches a preset standard and the buried defect level is less than a preset buried defect level threshold, it is judged that the wellhead device is in a safe state; If the wellbore leakage detection value is less than a preset wellbore leakage threshold, it is determined that the tubing string and the casing string are in a sealed state; If the wellhead device leakage detection value is less than a preset wellhead device leakage threshold, it is determined that the wellhead device is in a sealed state; If the gamma spectroscopy logging result does not detect continuous flowable gas accumulation, it is determined that the cement sheath of the wellbore is in a sealed state.

7. The method according to claim 1, characterized in that The method further comprises: If the wellhead gas leakage value in the real-time monitoring data exceeds a preset wellhead leakage threshold, it is determined that the wellbore has a wellhead leakage risk; correspondingly, a wellhead leakage warning is issued for the wellbore; If the wellhead uplift value in the real-time monitoring data exceeds a preset wellhead uplift threshold, it is determined that the wellbore has a wellhead uplift risk; correspondingly, a wellhead uplift warning is issued for the wellbore; If the annulus liquid level value in the real-time monitoring data is lower than the preset annulus liquid level threshold, or the annulus liquid level value of the real-time monitoring data continues to decrease for several times, it is determined that the wellbore has an annulus liquid level risk, and accordingly, an annulus liquid level warning is issued for the wellbore.

8. A risk monitoring and early warning device for gas storage well operation, comprising: An acquisition module, used to acquire real-time monitoring data of the wellbore; The risk monitoring and early warning module is used to predict whether the wellbore has a safety risk based on the annular space pressure value in the real-time monitoring data of the wellbore, and to issue a corresponding early warning when it is predicted that the wellbore has a safety risk.

9. A computer storage medium, characterized in that: The computer storage medium stores computer executable instructions, and when the computer executable instructions are executed by the processor, the risk monitoring and early warning method for gas storage well operation described in any one of claims 1-7 is implemented.

10. A terminal device, characterized in that: include: A memory, a processor, and a computer program stored in the memory and executable on the processor, wherein when the processor executes the program, a risk monitoring and early warning method for gas storage well operation as described in any one of claims 1 to 7 is implemented.

11. A computer program product, characterized in that The computer program product comprises a computer program, and when the computer program is executed by a processor, the method for risk monitoring and early warning of gas storage well operation as claimed in any one of claims 1 to 7 is implemented.

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