CN112328953B - Water invasion identification method, device and equipment for gas well and readable storage medium - Google Patents
Water invasion identification method, device and equipment for gas well and readable storage medium Download PDFInfo
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Abstract
The application provides a water invasion identification method, a device, equipment and a readable storage medium for a gas well, wherein the method comprises the following steps: calculating normalized pressure data and normalized gas production data of the gas well according to the production data of the gas well; acquiring pressure change trend information according to the normalized pressure data and the normalized gas production data; obtaining a pressure deviation point according to the pressure change trend information; a first time is determined from the pressure deviation point, the first time representing a time at which the gas well is water-immersed. The time of water invasion of the gas well can be known before the gas well becomes a water producing well through the production data of the gas well, so that a user can know the water invasion condition of the gas well in time.
Description
Technical Field
The present disclosure relates to the field of gas reservoir development, and in particular, to a method, an apparatus, a device, and a readable storage medium for water invasion identification of a gas well.
Background
The abnormal high-pressure gas reservoir is large in general reserves, high in yield and large in depth, the formation pressure gradually drops along with the development progress, the water body at the outer side bottom of the gas well gradually invades the gas well, once the gas well is water-filled into the water producing well, the difficulty of gas reservoir exploitation is increased, the productivity of the gas well is reduced, and the exploitation efficiency is reduced, so that the water invasion condition of the gas well needs to be identified.
The related art is to calculate the water invasion amount in the case that the gas well has already seen water, that is, to evaluate the water invasion condition in the case that the gas well of the current period has been determined to be in the water producing stage.
The technology can not identify the situation that the gas well is immersed in water but does not enter the water producing stage, and is difficult to identify the water immersed situation of the gas well in time.
Disclosure of Invention
The embodiment of the application provides a water invasion identification method and device for a gas well and a readable storage medium, so as to solve the problem that the water invasion condition of the gas well is difficult to identify in time in the related technology. The technical scheme is as follows:
in one aspect, embodiments of the present application provide a method for water invasion identification of a gas well, the method comprising:
carrying out data measurement on the gas well to obtain production data;
substituting the production data into a flowing material balance relation of an abnormally high pressure gas reservoir to obtain normalized pressure data and normalized gas yield data of the gas well, wherein the normalized pressure data comprises data used for representing the pressure condition of the gas well, and the normalized gas yield data comprises data used for representing the gas production condition of the gas well;
determining pressure change trend information of the gas well according to the normalized pressure data and the normalized gas production data;
Determining a pressure deviation point according to the pressure change trend information;
and determining the first moment corresponding to the pressure deviation point as the moment when the water invasion of the gas well occurs.
Optionally, the pressure change trend information includes a pressure curve, and the obtaining a pressure deviation point according to the pressure change trend information includes:
acquiring the slope of the pressure curve;
and taking the slope abrupt change point of the pressure curve as the pressure deviation point.
Optionally, the production data comprises: unit gas production data corresponding to each time node;
the determining the first moment corresponding to the pressure deviation point as the moment when the gas well is immersed in water comprises the following steps:
acquiring an normalized gas production value corresponding to the pressure deviation point;
acquiring a unit gas production value matched with the normalized gas production value from the unit gas production data;
and taking the time node corresponding to the unit gas production value as the first moment.
Optionally, the taking the target time node for obtaining the unit gas production value as the first moment includes:
and determining a time node corresponding to the unit gas production value in a gas well production dynamic graph as the first moment according to the unit gas production value, wherein the gas well production dynamic graph is generated according to the production data.
Optionally, the method further comprises:
fitting according to the normalized pressure data before the first moment to obtain fitting data of a non-water invasion period;
determining the water invasion amount of the gas well according to the pressure deviation between the normalized pressure data and the non-water invasion fitted data after the first moment.
Optionally, the water invasion amount of the gas well comprises a first water invasion amount of the gas well before entering a water production stage, the determining the water invasion amount of the gas well according to a pressure deviation amount between the normalized pressure data and the non-water invasion period fitting data after the first time comprises:
and determining a first water invasion amount of the gas well by using a preset first expression according to the pressure deviation amount between the normalized pressure data and the non-water invasion fitted data.
Optionally, the water invasion amount of the gas well comprises a second water invasion amount of the gas well in a water producing phase, the determining the water invasion amount of the gas well according to a pressure deviation amount between the normalized pressure data and the non-water invasion period fitting data after the first time comprises:
and determining a second water invasion amount of the gas well by using a preset second expression according to the pressure deviation amount between the normalized pressure data and the non-water invasion fitted data.
Optionally, the calculating the normalized pressure data and normalized gas production data for the gas well based on the production data for the gas well comprises:
inputting the production data into a normalization pressure calculation formula to obtain normalization pressure data;
and inputting the production data into a normalized gas production calculation formula to obtain the normalized gas production data.
In another aspect, embodiments of the present application provide a water invasion identification apparatus for a gas well, the apparatus comprising:
the acquisition module is used for acquiring production data of the gas well;
the calculation module is used for substituting the production data into the flowing material balance relation of the abnormal high-pressure gas reservoir to obtain the normalized pressure data and the normalized gas production data of the gas well;
the acquisition module is also used for acquiring pressure change trend information according to the normalized pressure data and the normalized gas production data;
the identification module is used for obtaining pressure deviation points according to the pressure change trend information;
the identification module is further configured to determine a first time from the pressure deviation point, the first time being indicative of a time at which the gas well is water-immersed.
In another aspect, an embodiment of the present application provides an electronic device, including: the system comprises a processor, a memory and a bus, wherein the memory stores machine-readable instructions executable by the processor, when the electronic equipment is running, the processor is communicated with the memory through the bus, and the machine-readable instructions are executed by the processor to realize the water invasion identification method of the gas well.
In another aspect, embodiments of the present application provide a computer readable storage medium having at least one instruction, at least one program, a set of codes, or a set of instructions stored therein, the at least one instruction, the at least one program, the set of codes, or the set of instructions being loaded and executed by a processor to implement the method for water invasion identification of a gas well described above.
The beneficial effects that technical scheme that this application embodiment provided include at least:
the method is easy to realize and popularize, the first moment when the pressure deviation point appears is regarded as the moment when the water invasion of the gas well occurs, the gas well enters the water invasion early stage at the first moment, the condition of the gas well in the water invasion early stage can be known in advance, and the method has important significance for gas reservoir development engineering.
Drawings
In order to more clearly illustrate the technical solutions of the embodiments of the present application, the drawings that are needed in the embodiments of the present application will be briefly described below, it should be understood that the following drawings only illustrate some embodiments of the present application and should not be considered as limiting the scope, and other related drawings may be obtained according to these drawings without inventive effort for a person skilled in the art.
FIG. 1 is a flow chart of a method for water invasion identification of a gas well according to an exemplary embodiment of the present application;
FIG. 2 is a flow chart of a method for water invasion identification of a gas well provided in accordance with another exemplary embodiment of the present application;
FIG. 3 is a dynamic graph of gas well production in one example provided by an exemplary embodiment of the present application;
FIG. 4 is a water intrusion diagnostic chart provided based on the example shown in FIG. 3;
FIG. 5 is a schematic diagram of a water intrusion recognition result based on the example shown in FIG. 3;
FIG. 6 is a schematic illustration of a water intrusion diagnostic model provided in accordance with another exemplary embodiment of the present application;
FIG. 7 is a diagnostic chart of water intrusion in another example provided by another exemplary embodiment of the present application;
FIG. 8 is a water intrusion diagnostic chart in yet another example provided by another exemplary embodiment of the present application;
FIG. 9 is a functional block diagram of a water invasion identification device for a gas well according to another exemplary embodiment of the present application;
fig. 10 is a schematic structural diagram of an electronic device according to another exemplary embodiment of the present application.
Detailed Description
Reference will now be made in detail to exemplary embodiments, examples of which are illustrated in the accompanying drawings. The implementations described in the following exemplary examples are not representative of all implementations consistent with the present application. Rather, they are merely examples of methods that are consistent with some aspects of the present application as detailed in the accompanying claims.
Some concepts and principles in this application will be explained below for an understanding of the solution.
Abnormal high pressure gas reservoir: and the gas reservoir pressure is higher than the hydrostatic pressure, and the stratum pressure coefficient is larger than a fixed value. Wherein the fixed value may be 1, 1.27, 1.3, 1.4, 1.5, etc. For example, in some regions, a gas reservoir having a formation pressure coefficient of 1.3 or more is referred to as an abnormally high pressure gas reservoir, and in other regions, a gas reservoir having a formation pressure coefficient of 1.27 or more is referred to as an abnormally high pressure gas reservoir. The occurrence of water intrusion in abnormally high pressure reservoirs is a problem encountered in the actual development process.
Logging: typically referred to as geophysical or petroleum logging. Various logging instruments manufactured by using physical principles of electricity, magnetism, sound, heat, nuclear and the like are put into a well by logging cables, and various parameters changing along the depth are continuously recorded along a well shaft so as to measure physical parameters of stratum around the well hole. For example, formation characteristics such as formation permeability, saturation, etc. of the near wellbore region may be obtained by logging.
Testing the well: the method is a technology for evaluating the reservoir, is a mine field test for researching the characteristics of the well and the stratum, and comprises two parts of well test and well test explanation. The well test is to test an oil well, a gas well or a water well by using a plurality of test processes and test means, wherein the test contents comprise yield, pressure, temperature, sampling and the like. The well test interpretation is based on the seepage mechanics theory, and various physical parameters and production capacities reflecting the characteristics of the test well and stratum and the communication relation among the oil, gas and water layers and among the wells are determined through the research on the test information of the oil, gas and water wells.
For an abnormally high pressure reservoir (hereinafter referred to as a reservoir), a single well in the region of the reservoir typically undergoes three stages in sequence: a non-water-invasion stage (or non-water-invasion stage), an early water-invasion stage, and a water-production stage. The productivity of the gas well in the non-water invasion period and the early water invasion period is higher, but once the gas well enters the water production period to become a water production well, the production organization of the gas well is trapped in the passive state, the gas production capacity is reduced, the productivity of the gas well is reduced, and the exploitation difficulty of the gas well is increased.
In the related art, the water invasion situation is difficult to know in time, and the knowledge of the energy of the water in the gas reservoir is always lagged, mainly caused by the following reasons:
in the related art, the calculation of the water invasion amount is generally performed in the case that a gas well has already seen water, that is, conventionally, the water invasion condition is known only after a gas well has entered a water production stage, and in fact, the water invasion condition at this time has been serious. For example, the processing flow of the related art is: judging whether the daily water yield is obviously improved according to the acquired production data of the gas well, and if the production data shows that the water yield of the gas well is obviously improved, preparing to know the specific condition of the water invasion amount so as to obtain the specific water invasion amount.
This practice has hysteresis, it can be known that only the water intrusion phenomenon is relatively obvious and has been converted into the water intrusion quantity of the producing well.
Referring to fig. 1, fig. 1 is a flowchart of a method for identifying water invasion of a gas well according to an exemplary embodiment of the present application, the method comprising:
and step 101, performing data measurement on the gas well to obtain production data.
Wherein each gas well can obtain production data corresponding to the gas well, and the production data is obtained along with the development progress of the gas well.
Alternatively, the production data may be considered as dynamic data associated with a time node, which may vary with the development progress of the gas well. For production data, the acquisition may be performed at a preset period, which may be one hour, half day, one day, two days, one week, or the like. The production data may include measured gas production data, water production data, oil pressure data, and the like.
And 102, substituting the production data into a flowing material balance relation of the abnormal high-pressure gas reservoir to obtain normalized pressure data and normalized gas production data of the gas well.
Optionally, the normalized pressure data includes data indicative of a pressure condition of the gas well, and the normalized gas production data includes data indicative of a gas production condition of the gas well.
It should be noted that, the produced water data in the produced water data is not equal to the water invasion amount of the gas well, because in a practical scenario, it is possible that the gas well has been water-invaded, but the gas well has not been converted into a produced water well to produce water, and it is difficult to determine the water invasion amount of the gas well and only identify the produced water data.
The normalized pressure data and the normalized gas production data can be calculated by utilizing production data, the original pressure of the gas well, the high-pressure physical property experimental result, the well test interpretation data and the productivity well test data in the early development stage of the gas well and combining the flowing material balance relation of the abnormal high-pressure gas reservoir. After obtaining the normalized pressure data and the normalized gas production data, step 103 is performed. Wherein the normalized pressure data and the normalized gas production data are mutually corresponding.
And step 103, determining pressure change trend information of the gas well according to the normalized pressure data and the normalized gas production data.
The pressure change trend information can be presented in the form of data expression of a table, a scatter diagram, a graph and the like. Alternatively, in the embodiment of the present application, the pressure change trend information is described by way of example in terms of a representation of a graph, that is, the pressure change trend information includes a pressure curve.
And 104, determining a pressure deviation point according to the pressure change trend information.
Wherein, the pressure deviation point can be determined according to the pressure change amount and the slope in the pressure change trend information. As an embodiment, the normalized pressure data/pressure change trend information may be automatically identified using a preset computer program to determine the pressure deviation point.
Step 105, determining the first moment corresponding to the pressure deviation point as the moment when the water invasion of the gas well occurs.
Wherein, since the pressure deviation point is determined by the normalized pressure data and the normalized gas production data, which are calculated according to the production data (time-related dynamic data) of the gas well, the first moment of occurrence of the pressure deviation point can be further obtained after the pressure deviation point is determined.
In summary, in the technical solution provided in the embodiments of the present application, the time when the gas well is immersed in water may be known before the gas well enters the water producing stage. For example, in the process of continuously acquiring production data of a gas well, from the perspective of the production data, there is no significant change in the production data or the production data is always below a water volume threshold, but in practice, the gas well has entered an early stage of water invasion, and it is conventionally unknown whether the gas well has been water-invaded or not, and by the method, the time when the water invasion of the gas well occurs can be identified. That is, the above method can identify the timing of the entry of water into the gas well early in advance, as compared with the related art.
Further, early knowledge of gas well inflow water invasion has important significance for the whole gas reservoir development project. Because if the time of the gas well entering the water invasion early stage can be known in advance, the development strategy can be adjusted in advance. For example, if the moment of entering the water invasion early stage of the gas well is identified, an active production reduction measure can be adopted for the corresponding gas well, after the active production reduction, the production pressure difference can be changed, so that the pressure influence is reduced, the time of the water invasion early stage can be prolonged, and the production stage of the gas well is shifted backwards, so that the recovery ratio is improved.
In short, knowing the early moment of gas well entering water invasion in advance can prompt the user to start calculating the water invasion amount in advance, and is beneficial to the user to actively adjust the development strategy so as to improve the recovery ratio.
The term "normalization" means normalization of data (for example, the original pressure of a gas reservoir, the results of high-pressure physical experiments, and the like) other than production data, to obtain comprehensive data suitable for any gas well in the entire gas reservoir development area. Wherein data/material other than production data can be determined at the beginning of gas reservoir development. The calculated normalized pressure data and normalized gas production data are more accurate through the comprehensive data applicable to any gas well in the whole gas reservoir development area and the production data applicable to the designated well.
Referring to fig. 2, fig. 2 is a flow chart of a method for identifying water invasion of a gas well according to another exemplary embodiment of the present application, the method includes:
step 201, performing data measurement on a gas well to obtain production data.
In an actual application scenario, before step 201 is executed, a well may be drilled in the initial stage of development to obtain a core, an permeability experiment and a high-pressure physical experiment may be performed based on the core to obtain some characteristic parameters (including permeability, compression coefficients of various media, volume coefficients of various media, etc.) of a gas reservoir development project, and a well may be well-tested and tested in the initial stage of development to obtain well-test interpretation data and capacity well-test data in the initial stage of development. These characteristic parameters, well test interpretation data at the initial stage of development and production capacity well test data will be used to determine the flow material balance relationship applicable to the abnormally high pressure gas reservoir, and the relationship between the normalized gas production and the normalized pressure can be obtained based on the flow material balance relationship of the abnormally high pressure gas reservoir.
And 202, substituting the production data into a flowing material balance relation of the abnormal high-pressure gas reservoir to obtain normalized pressure data and normalized gas production data of the gas well.
Alternatively, the relationship between normalized gas production and normalized pressure may be obtained based on the flowing material balance relationship of the abnormally high pressure gas reservoir, thereby calculating normalized gas production data and normalized pressure data.
The flow material balance relationship of the abnormal high-pressure gas reservoir is presented through the flow material balance equation of the abnormal high-pressure gas reservoir provided by the embodiment of the present application, and the flow material balance equation of the abnormal high-pressure gas reservoir is shown in the following formula (1):
in the above equation for balancing the flowing material of the abnormal high-pressure gas reservoir, the expression on the left of the equal sign is used as the normalized pressure calculation formula in the embodiment of the present application, and the expression on the right of the equal sign is used as the normalized gas production calculation formula in the embodiment of the present application. In the non-water invasion period of the gas well, the normalized pressure data and the normalized gas production data are in a linear relation. It should be noted that the above equation is only one expression form of the balance relation of the flowing materials of the abnormal high-pressure gas reservoir, and the equation may have other expression forms, for example, other equations may be obtained after the transformation of the equation such as term transfer, scaling with the same proportion, and the like.
Based on the equation of flow material balance of the abnormally high pressure gas reservoir provided in the embodiment of the present application, the step 202 may specifically include: based on the production data, determining normalized pressure data using a normalized pressure calculation formula, and determining normalized gas production data using a normalized gas production calculation formula.
The normalized pressure calculation formula is shown in the following formula (2):
wherein Y represents normalized pressure data. P is p i The raw pressure of the gas well is represented and can be measured in the early stages of gas well development. P is p wf The representation of the bottom hole flow pressure may be obtained using a pipe flow calculation method or a mine site empirical formula, for example, the bottom hole flow pressure may be determined using wellhead oil pressure tested at the mine site in combination with the pipe flow calculation method. qsc the yield in the production dataThe gas quantity can be daily gas production data.
The calculation formula of the normalized gas production is shown in the following formula (3).
Wherein X represents the normalized gas production data of the gas well. B (B) g Representing the volume coefficient of the gas after being affected by pressure, B g i represents the original volume coefficient of the gas, and can be obtained by high-pressure physical property experiments. G p The cumulative gas production in the production data is shown as qsc. C (C) c The gas reservoir comprehensive compression coefficient can be obtained through high-pressure physical property experiments. a "represents the Darcy seepage coefficient of a gas well, b" represents the non-Darcy seepage coefficient of the gas well, a "and b" can be determined by well test data in the early stage of gas reservoir development before the water production of the gas well, and a "and b" can be corrected after the water production of the gas well.
By the method, the normalized pressure and the normalized gas yield which meet the balance relation of the flowing substances of the abnormal high-pressure gas reservoir can be calculated. Based on the calculated normalized pressure data and normalized gas production data, the time of the gas well entering the water invasion early stage can be determined, the recognition result is accurate and reliable, the water invasion amount of the gas well in different periods can be calculated, and the method has important significance in the field of gas reservoir development.
And 203, determining pressure change trend information of the gas well according to the normalized pressure data and the normalized gas production data.
As an embodiment, the normalized gas yield may be taken as an abscissa, and the normalized pressure may be taken as an ordinate, so as to obtain a pressure curve corresponding to the normalized pressure data and the normalized gas yield data.
Alternatively, the normalized pressure may be taken as an abscissa, and the normalized gas yield may be taken as an ordinate, so as to obtain pressure curves corresponding to the normalized pressure data and the normalized gas yield data.
Step 204, obtaining a slope of the pressure curve.
Optionally, a preset computer program can be utilized to automatically identify the slope of the pressure curve, and obtain the slope of the pressure curve and the slope change condition thereof.
And step 205, taking the slope abrupt change point of the pressure curve as the pressure deviation point.
If the slope of the pressure curve is suddenly changed, judging that a pressure deviation point exists in the pressure curve. It should be noted that, the "abrupt change in slope" may indicate that the overall trend of the normalized pressure data changes. For example, if the slope as a whole tends to a constant value within one month or three months, it is considered that the slope is not mutated.
At step 206, the first time corresponding to the pressure deviation point is determined as the time when the water invasion of the gas well occurs.
Wherein a first pressure deviation point occurs when the gas well enters the early water invasion phase from the non-water invasion phase and a second pressure deviation point occurs when the gas well enters the water production phase from the early water invasion phase. The second moment can be obtained through the second pressure deviation point, and the second moment represents the moment when the gas well enters the water producing stage (or called water producing period).
For the determination of the second pressure deviation point and the second moment, please refer to the related description about the second pressure deviation point and the first moment, which are not described herein.
By the method, not only can the moment when the gas well enters the water invasion early stage from the non-water invasion period be identified, but also the moment when the gas well enters the water production stage from the water invasion early stage can be identified.
In order to avoid the problem that the real pressure deviation point is difficult to identify due to the fact that the slope continuously changes, pretreatment such as filtering can be performed on the normalized pressure data and/or fitting can be performed on the normalized pressure data to obtain a pressure curve, so that interference caused by abnormal data is reduced, and accuracy of a water invasion identification result is improved.
In addition, since the normalized pressure data and the normalized gas production data are obtained by normalizing part of the data, even if few abnormal data exist, the judgment result of the pressure change trend is not affected, and the identified first moment has reliability.
As an embodiment, the first instant may be determined directly from the pressure deviation point. Since the calculation process of the normalized pressure data and the normalized gas production data is associated with the production data, the production data is necessarily obtained at various time nodes in the gas well development process. The normalized pressure data and the normalized gas production data can be understood as functions of the time nodes, and in general, the value of the normalized gas production data can be increased along with the development progress, and the first moment can be directly obtained after the pressure deviation point is determined.
As an embodiment, the production data may include: the unit gas production data and the time node for measuring the unit gas production data can be daily gas production data, weekly gas production data, accumulated gas production data, and the accumulated gas production data can represent gas production data obtained by accumulating daily gas production data, weekly gas production data and the like. Accordingly, the step 206 may specifically include the following steps:
and step one, obtaining the normalized gas production value corresponding to the pressure deviation point.
Wherein the normalized gas yield value is one of the values of the normalized gas yield data.
And secondly, acquiring a unit gas production value matched with the normalized gas production value from the unit gas production data.
And thirdly, taking the time node corresponding to the obtained unit gas production value as a first moment.
If the unit gas production data is daily gas production data, acquiring a daily gas production value matched with the normalized gas production value from the daily gas production data according to the normalized gas production value, and taking a time node of the daily gas production value as a first moment; if the unit gas production data is accumulated gas production data, an accumulated gas production value matched with the normalized gas production value can be obtained from the accumulated gas production data according to the normalized gas production value, and a time node for measuring the accumulated gas production value is taken as a first moment.
Alternatively, as an implementation manner, a time node corresponding to the unit gas production value may be determined in a dynamic graph of gas well production according to the unit gas production value, as the first time. Wherein the gas well production dynamics graph is generated from production data.
In one example, a gas well production dynamics graph generated from production data for one gas well is shown in FIG. 3. In fig. 3, "(7)" indicates hydraulic pressure data of one gas well, the upper left axis in fig. 3 (in MPa), "(8)" indicates daily gas production data of the gas well, the lower left axis in fig. 3 (in ten thousand cubic meters), and "(9)" indicates daily water production data of the gas well, the right axis in fig. 3 (in cubic meters), and the abscissa in fig. 3 is time, for example, "16.9.6" indicates 2016, 9, 6 days. From the data in fig. 3, it can be known that the water production data at the time node corresponding to the point B is significantly improved, but it cannot be known when the water invasion is early. After the pressure deviation point is determined by the method, a normalized gas production value corresponding to the pressure deviation point can be obtained according to the pressure deviation point, the normalized gas production value is matched with daily gas production data in a gas well production dynamic graph, so that a daily gas production value corresponding to the normalized gas production value is determined from the daily gas production data, and a time node for measuring the daily gas production value is taken as a first moment.
By the above embodiment, after the pressure deviation point is identified, a time node at which the pressure deviation point occurs can be further obtained, and the time node is taken as the first time. Therefore, water invasion identification is realized, and the early moment of water invasion entering the gas outlet well is identified.
Optionally, prior to performing step 202, the method further comprises determining from the production data whether the gas well is in a water producing stage; if the gas well is not in the water producing phase, step 202 is performed.
And when the daily water production data in the production data obviously suddenly changes or the daily water production data is higher than the water quantity threshold value, judging that the gas well is in the water production stage.
It should be noted that, in the case that the water producing stage occurs after the identification has been performed by the above method, the identification may still be continued to calculate the water invasion amount.
Optionally, to calculate the water invasion of the gas well, embodiments of the present application may further include steps 207 to 208.
Step 207, fitting to obtain non-water intrusion phase fitting data according to the normalized pressure data before the first time.
And fitting according to the partial normalization pressure data to obtain non-water invasion fitting data. For example, the normalized pressure data fit may be taken for one week/half month/month after the start of production of the gas well to obtain non-water invasion fit data. A non-water-invasion fitted line can be obtained according to non-water-invasion fitted data, and the slope value of the non-water-invasion fitted line can be different according to actual production data of different gas wells.
Step 208, determining the water invasion amount of the gas well according to the pressure deviation between the normalized pressure data and the non-water invasion fitted data after the first moment.
The steps 207 to 208 may be performed after the pressure deviation point is obtained, or may be performed earlier.
The water invasion amount of the gas well in each stage can be calculated by the method. The water invasion amount calculated after the first pressure deviation point and before the second pressure deviation point can reflect the water invasion condition of the gas well in the early stage of water invasion, and the water invasion amount calculated after the second pressure deviation point can reflect the water invasion condition of the gas well in the water production stage.
As an embodiment, a pressure curve obtained from the normalized pressure data or a fitted straight line of the non-water intrusion period may be displayed in the water intrusion diagnostic map, and a pressure deviation amount (or pressure difference) between the pressure curve and the fitted straight line of the non-water intrusion period may be used as the pressure deviation amount between the normalized pressure data and the fitted data of the non-water intrusion period. The water intrusion amount calculated using the pressure deviation amount may also be displayed in the water intrusion diagnostic map.
As shown in FIG. 4, a water invasion diagnostic chart corresponding to the example of FIG. 3 is shown, the abscissa in FIG. 4 is normalized gas yield (in MPa/ten thousand cubic meters) and the ordinate is normalized pressure (in MPa/ten thousand cubic meters), and the pressure deviation amount after the pressure deviation point A is obtained by determining the pressure deviation point at the point A by the above-mentioned method. Wherein, only the pressure scattered points obtained according to partial pressure data of one gas well and the fitted straight line without water invasion obtained by fitting are shown in fig. 4, and the pressure curve can be obtained according to a plurality of pressure scattered points.
After the point A is matched with daily gas production data in the graph 3, the time when the pressure deviation point occurs can be obtained, namely, the first moment is determined, and the water invasion recognition result is obtained. The time corresponding to the left vertical dashed line in fig. 5 represents a first moment, and the time corresponding to the right vertical dashed line in fig. 5 represents a second moment when the gas well enters the water production stage.
After determining the pressure deviation point, point a in fig. 4, the water invasion amount of the gas well can be calculated from the pressure deviation amount.
Optionally, the water invasion amount of the gas well comprises a first water invasion amount of the gas well before entering the water production stage. To calculate the first water intrusion, the step 208 may specifically include: and determining a first water invasion amount of the gas well by using a preset first expression according to the pressure deviation amount between the normalized pressure data and the non-water invasion period fitting data.
For the first expression please refer to the following formula (4):
wherein DeltaY 1 Representing a first pressure differential obtained at any point in time prior to entry of the gas well into the water producing stage, is derived from the normalized pressure data described above or is derived using a graphical method. W (W) e1 Representing the first water intrusion sought. B (B) w Representing the volume coefficient of water, B gi The raw volume coefficient representing the gas can be found experimentally or measured at the beginning of the development of the gas well. G represents the dynamic reserve of a gas well and can be obtained by using a pressure drop method, an elastic two-phase method, a yield instability analysis method and the like in the early stage of gas well development.
Optionally, the water invasion amount of the gas well may further comprise a second water invasion amount of the gas well in a water producing phase. To calculate the second water intrusion, the step 208 may specifically include: and determining a second water invasion amount of the gas well by using a preset second expression according to the pressure deviation amount between the normalized pressure data and the non-water invasion period fitting data.
For the second expression please refer to the following formula (5):
wherein DeltaY 2 And a second pressure difference obtained at any time point when the gas well is in the water production stage is obtained according to the normalized pressure data or obtained by using a graphical method. W (W) e2 Representing the second water intrusion sought. W (W) p Representing the cumulative water production in the production data, W as one embodiment p Can be obtained by accumulating daily water production data in the production data.
The second water invasion amount is generally larger than the first water invasion amount, but if special conditions such as local water sealing exist, the water invasion condition of the gas well may change, so that the second water invasion amount is equal to or smaller than the first water invasion amount.
In addition, in the related art, the qualitative analysis process of water invasion monitoring generally needs to develop multiple pressure recovery well tests, and the advancing position of the water invasion front edge is judged by comparing the pressure derivative curve at the rear end of the double logarithmic curve; the quantitative evaluation of the water intrusion in the related art is usually based on a generalized material balance equation to indirectly calculate the water intrusion, or directly calculate the water intrusion by using an unsteady water intrusion model, a quasi-steady water intrusion model and a steady water intrusion model. Whether qualitative or quantitative monitoring is performed, the system is continuously dependent on the static pressure test data at the bottom of the well or the pressure recovery well test data, and each equation for calculating the water invasion amount is continuously dependent on the pressure data (namely, the well closing pressure measurement is required to be performed for a plurality of times), so that once the pressure data are lost, the phenomenon of gas well water invasion is difficult to know. In the actual production process, the logging data are difficult to shut in at any time, the well shut in time is long, the production organization of a gas well is influenced, the productivity of the gas well is influenced, and even the well under the working condition cannot be recovered. In the embodiment of the application, the initial pressure data can be obtained only by performing well closing operation at the initial development stage of the gas well, the times of well closing are small, and the well closing operation is not needed to be performed for multiple times in the subsequent development process so as to record the pressure data. Once the gas well is formally mined, the well closing operation is not needed to be carried out to record the pressure data, the water invasion phenomenon can be described only through the pressure data obtained at the initial stage of development, the comprehensive data, the characteristic parameters and the information recorded by the production data in the subsequent development process, and the water invasion amount is calculated, so that compared with the related art, the well closing frequency is reduced, and the dependence on the mode of recording the pressure data during well closing is reduced.
Alternatively, in the embodiment of the present application, after a well has undergone a complete non-water invasion phase, an early water invasion phase, and entered a water production phase, the obtained water invasion diagnostic chart may be compared with a preset water invasion diagnostic model (see fig. 6), so as to learn the type of the corresponding gas well.
In fig. 6, "(1)" represents a characteristic curve of the non-water-invasion period, "(2)" represents a characteristic curve of the early-stage water-invasion period, "(3)", "(4)", "(5)", and "(6)", which are four lines, represent characteristic curves that may occur in the water-producing period. Any combination of the characteristic curves (1) to (6) may occur during actual production and development of the gas well. Pure gas wells with limited water energy generally exhibit the form of characteristic curves (1) or (1) - (2) far from the bottom water or under-developed cracks; wells closer to the bottom water or where cracks develop generally exhibit the morphology of characteristic curves (1) - (2) - (3)/(4)/(5)/(6). For the water production period, the characteristic curves corresponding to the water bodies with different energies may show the forms (3) to (6), and the energy of the water bodies sequentially corresponds to the strong energy to the weak energy. The conditions corresponding to (3) and (4) can show that the water invasion amount of the gas well is larger than the water drainage amount, and the water invasion is aggravated, wherein (3) is mostly represented by crack water channeling or bottom water coning, which indicates that the water body is more active, and (4) is mostly represented by tongue water invasion-weak tongue water invasion, which indicates that the water energy is relatively weak; (5) parallel to the curve of (1), the water yield and the water discharge reach balance, and the water invasion is not changed any more; (6) indicating that the displacement is greater than the water intrusion, indicating that the water intrusion is decreasing.
By the method, if the water invasion diagnosis map obtained according to the normalized pressure data and the normalized gas production data is compared with the water invasion diagnosis model, whether the water invasion condition of the gas well is aggravated or relieved can be known.
The theoretical basis of the embodiments of the present application will be described below to obtain the relationship between normalized pressure and normalized gas production.
When the production state of the gas well reaches a stable state, the following flow equation is satisfied, please refer to the following formula (6).
In the formula (6), ψ represents the pseudo pressure of the real gas, MPa 2 /(mPa·s)。q sc Representing gas production, 10 4 m 3 /d; a' represents the Darcy seepage term coefficient of the gas well and MPa 2 (10 4 m 3 /d) -1 /(mPas); b' represents the non-Darcy seepage term coefficient of the gas well, MPa 2 (10 4 m 3 /d) -2 /(mPas); subscript e denotes gas well, subscript wf denotes downhole flow, e.g., ψ e Represents the original pseudo pressure of the gas well, psi wf Representing the bottom hole flow pseudopressure.
For the pseudo-pressure expression of the gas well, please refer to the following formula (7).
In formula (7), p is pressure, MPa. P is p 0 The reference pressure can be selected according to actual needs, for example, zero or 0.1MPa can be adopted. Mu represents the viscosity of the gas, mPas; z is a natural gas deviation factor, dimensionless.
Through research on typical natural gas, it is considered that when the gas pressure is high (for example, greater than 14 MPa), the pseudo pressure is approximately in a linear relationship with the pressure, and then the formula (6) can be simplified into the formula (8) suitable for the mine.
The expression (8) has a relationship between the expressions (9) and (10).
a' represents the Darcy seepage term coefficient of the gas well, MPa/(10) 4 m 3 D); b' represents the non-Darcy seepage term coefficient of the gas well, MPa/(10) 4 m 3 /d) 2 . K represents the gas reservoir permeability, mD. h is the reservoir thickness, m; t represents temperature, K; r represents the well radius, m; s represents a epidermis factor or epidermis coefficient, dimensionless; subscript i represents the original state, subscript SC represents a standard condition (e.g., standard atmospheric pressure), and subscript w represents the wellbore.
For the gas well with the capacity test, a 'and b' can be obtained by fitting the capacity equation, and for the gas well without the capacity test, the gas well can be obtained by calculation through logging and pressure recovery test interpretation data in the initial stage of gas reservoir development, and the well closing operation is not required to be carried out for a plurality of times in the later stage.
For a material balance equation of a closed gas reservoir, considering rock elastic energy of an abnormally high pressure gas reservoir, a relational expression between gas production and gas output of a gas well and formation pressure is shown as a formula (11), and the formula (11) is a representation form of the material balance equation.
In the formula (11), C c Is the comprehensive compression coefficient of the gas reservoir, MPa -1 Can be obtained by high-pressure physical property experiment. G is dynamic reserve, 10 8 m 3 。G p To accumulate gas production, 10 8 m 3 。
Considering that the volume coefficient of the gas is affected by pressure change in the natural gas exploitation process, the original volume coefficient B of the gas is combined gi The volume coefficient B of the gas affected by the pressure can be obtained g The expression of (2) is shown in the formula (12).
Assuming that the gas well is developed as isothermal seepage, B gi Substituting the formula (12) into the formula (11) allows the formula (11) to be rewritten into the formula (13).
Wherein p is e Is "p" in the formula (11).
From the above formula (8) and formula (13), formula (3) in the above method can be obtained, and a flow mass balance equation suitable for an abnormally high pressure gas reservoir can be obtained.
Before the gas well produces water, the equation coefficient of the gas well is unchanged, and correction of a 'and b' is not needed. For the middle and later stages of water invasion, the formation water is produced by the gas well, the change of the well bottom seepage rule causes the change of the gas well production equation coefficient, and the correction of a 'and b' is needed to obtain the production equation coefficients a and b when the gas well produces water. The present application is not limited with respect to the correction process of the capacity equation coefficient when the gas well produces water.
Through example verification, most gas wells can be subjected to water invasion evaluation by using the principle and the method, and the early time of water invasion of the gas well is obtained. For the gas well corresponding to the example shown in fig. 3, it was found in conjunction with the water invasion diagnostic chart of fig. 4 that the normalized pressure of the gas well deviated from the fitted straight line for the non-water invasion period, entering the early water invasion period at the end of month 5 in 2016. Since the gas well is identified as entering the early stage of water invasion at this time, the development strategy is adjusted to prolong the early stage of water invasion Is a length of (c). As development progress progresses, the normalized pressure does not deviate from the early water invasion data until 7 months of 2017 after one year, and a second pressure deviation point (not labeled in fig. 4 because it can also be found by fig. 3) is identified, indicating that the gas well enters the water production stage. Comparing the water invasion diagnostic chart of the gas well with a preset water invasion diagnostic model, and knowing that the gas well shows the forms of (1) - (2) - (4) in the water invasion diagnostic model, and shows the characteristic of tongue water invasion. From the time of production of the gas well to the beginning of 2018, the gas well is produced for 1947 days and the accumulated gas production is 8.47 multiplied by 10 8 m 3 The accumulated water yield is 2.08X10 4 m 3 The water intrusion amount reaches 650 multiplied by 10 4 m 3 。
Besides being capable of identifying the 'tongue water invasion' well, the method can also be suitable for identifying and calculating the 'weak tongue water invasion', 'bottom water coning-weak tongue water invasion' well and other types. Diagnostic water invasion diagrams for the "weak tongue water invasion", "bottom water coning-weak tongue water invasion" type wells are shown in fig. 7 and 8, respectively. The pressure deviation point a can still be derived from fig. 7, whereas for the well in the example of fig. 8, the pressure deviation point is not indicated in fig. 8, since the well has not actually been characterized early in water invasion since the time of production. In fig. 7 and 8, the left ordinate represents the normalized pressure (unit: MPa/ten thousand cubic meters), the right ordinate represents the calculated water intrusion (unit: ten thousand cubic meters), and the bottom abscissa represents the normalized gas production. As can be seen from the water intrusion data in fig. 8, the calculated water intrusion values are much lower than those in fig. 7, and are substantially negligible, since the gas well corresponding to fig. 8 has not actually exhibited early water intrusion characteristics.
Referring to fig. 9, fig. 9 is a functional block diagram of a water invasion recognition device 900 for a gas well according to an embodiment of the present application. The device is used for executing the water invasion identification method of the gas well.
As shown in fig. 9, the apparatus includes: an acquisition module 910, a calculation module 920, an identification module 930.
An acquisition module 910 for acquiring production data of a gas well;
the calculation module 920 is configured to substitute the production data into a flowing material balance relationship of the abnormally high pressure gas reservoir to obtain normalized pressure data and normalized gas production data of the gas well;
the obtaining module 910 is further configured to obtain pressure variation trend information according to the normalized pressure data and the normalized gas production data;
an identification module 930, configured to determine a pressure deviation point according to the pressure variation trend information;
the identification module 930 is further configured to determine a first time indicative of a time at which the gas well is water-immersed based on the pressure deviation point.
Optionally, the pressure change trend information includes a pressure curve, and the obtaining module 910 is further configured to: and acquiring the slope of the pressure curve, and taking the abrupt change point of the slope of the pressure curve as a pressure deviation point.
Optionally, the production data includes unit gas production data corresponding to each time node, and the identification module 930 is further configured to: acquiring an normalized gas production value corresponding to the pressure deviation point; acquiring a unit gas production value matched with the normalized gas production value from the unit gas production data; and taking the time node corresponding to the unit gas production value as a first moment.
Optionally, the identification module 930 is further configured to: and determining a time node corresponding to the unit gas production value in a gas well production dynamic graph as a first moment according to the unit gas production value, wherein the gas well production dynamic graph is generated according to production data.
Optionally, the acquiring module 910 is further configured to: fitting according to the normalized pressure data before the first moment to obtain fitting data of a non-water invasion period; the water invasion amount of the gas well is determined according to the pressure deviation between the normalized pressure data after the first moment and the non-water invasion fitted data.
Optionally, the water invasion amount of the gas well includes a first water invasion amount of the gas well before entering the water production phase, the calculation module 920 is further configured to: and determining a first water invasion amount of the gas well by using a preset first expression according to the pressure deviation amount between the normalized pressure data and the non-water invasion period fitting data.
Optionally, the water invasion amount of the gas well includes a second water invasion amount of the gas well in a water production phase, the calculation module 920 is further configured to: and determining a second water invasion amount of the gas well by using a preset second expression according to the pressure deviation amount between the normalized pressure data and the non-water invasion period fitting data.
Optionally, the computing module 920 is further configured to: inputting the production data into a normalization pressure calculation formula to obtain normalization pressure data; and inputting the production data into a normalized gas production calculation formula to obtain normalized gas production data.
In addition to the above embodiments, the present embodiment also provides an electronic device 1000. As shown in fig. 10, the electronic device 1000 includes: the system comprises a processor 1020, a memory 1010 and a bus, wherein the memory 1010 stores machine-readable instructions executable by the processor 1020, and when the electronic device 1000 is running, the processor 1020 and the memory 1010 are communicated through the bus, and the machine-readable instructions are executed by the processor 1020 to realize the water invasion identification method of the gas well.
In practical applications, the electronic device 1000 may further include a display unit 1030, where the display unit 1030 is configured to display various data and graphs in the water invasion recognition method of the gas well, for example, a water invasion diagnosis graph, a first moment, a calculated water invasion amount, and the like.
The embodiment of the application also provides a computer readable storage medium, wherein at least one instruction, at least one section of program, a code set or an instruction set is stored in the readable storage medium, and the at least one instruction, the at least one section of program, the code set or the instruction set is loaded and executed by a processor to realize the water invasion identification method of the gas well.
In summary, the embodiments of the present application provide a method, an apparatus, an electronic device, and a readable storage medium for identifying water invasion of a gas well, which not only can identify that a water invasion occurs in a gas well and enter a time at which the water invasion is early, but also can calculate the water invasion amount of the gas well at each stage, so as to obtain the accumulated water invasion amount of the gas well from the start of production to the current time. In addition, the water invasion type satisfied by the gas well can be obtained by comparing the water invasion diagnostic chart obtained by the method with the water invasion diagnostic model. Therefore, the method can bring important effects to practical gas reservoir development engineering, is beneficial to providing technical support for users, is convenient for the users to formulate and adjust subsequent development strategies, and can save a large amount of manpower, material resources and financial resources in the long term.
In the several embodiments provided in this application, it should be understood that the disclosed apparatus and method may be implemented in other manners as well. The device embodiments described above are merely illustrative.
In addition, the functional modules in the embodiments of the present application may be integrated together to form a single part, or each module may exist alone, or two or more modules may be integrated to form a single part.
The above functions, if implemented in the form of software functional modules and sold or used as a stand-alone product, may be stored in a computer readable storage medium. Based on such understanding, the technical solution of the present application may be embodied in the form of a software product in essence or a part contributing to the related art or a part of the technical solution.
The foregoing is merely a specific embodiment of the present application, but the protection scope of the present application is not limited thereto, and any person skilled in the art can easily think about changes or substitutions within the technical scope of the present application, and the changes or substitutions are covered in the protection scope of the present application. Therefore, the protection scope of the present application shall be subject to the protection scope of the claims.
It should be noted that, in this document, the terms "comprises," "comprising," or any other variation thereof, are intended to cover a non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements does not include only those elements but may include other elements not expressly listed or inherent to such process, method, article, or apparatus. Without further limitation, an element defined by the phrase "comprising one … …" does not exclude the presence of other like elements in a process, method, article, or apparatus that comprises the element.
Claims (7)
1. A method of water invasion identification for a gas well, the method comprising:
carrying out data measurement on a gas well to obtain production data, wherein the production data comprises unit gas production data corresponding to each time node;
substituting the production data into a flowing material balance relation of an abnormally high pressure gas reservoir to obtain normalized pressure data and normalized gas yield data of the gas well, wherein the normalized pressure data comprises data used for representing the pressure condition of the gas well, and the normalized gas yield data comprises data used for representing the gas production condition of the gas well;
Determining pressure change trend information of the gas well according to the normalized pressure data and the normalized gas production data, wherein the pressure change trend information comprises a pressure curve;
acquiring the slope of the pressure curve, wherein the slope abrupt change point of the pressure curve is a pressure deviation point;
acquiring an normalized gas production value corresponding to the pressure deviation point;
acquiring a unit gas production value matched with the normalized gas production value from the unit gas production data;
according to the unit gas production value, determining a first moment corresponding to the unit gas production value as the moment of sounding water invasion of the gas well in a gas well production dynamic graph generated according to the production data;
fitting according to the normalized pressure data before the first moment to obtain fitting data of a non-water invasion period;
determining the water invasion amount of the gas well according to the pressure deviation between the normalized pressure data and the non-water invasion fitted data after the first moment.
2. The method of claim 1, wherein the water invasion amount of the gas well comprises a first water invasion amount of the gas well before entering a water production stage, the determining the water invasion amount of the gas well from a pressure offset between the normalized pressure data and the non-water invasion period fitting data after the first time comprises:
And determining a first water invasion amount of the gas well by using a preset first expression according to the pressure deviation amount between the normalized pressure data and the non-water invasion fitted data.
3. The method of claim 1, wherein the water invasion amount of the gas well comprises a second water invasion amount of the gas well in a water producing phase, the determining the water invasion amount of the gas well from a pressure offset between the normalized pressure data and the non-water invasion fitted data after the first time, comprising:
and determining a second water invasion amount of the gas well by using a preset second expression according to the pressure deviation amount between the normalized pressure data and the non-water invasion fitted data.
4. A method according to any one of claims 1 to 3, wherein the determining of normalized pressure data and normalized gas production data for the gas well from the production data comprises:
inputting the production data into a normalization pressure calculation formula to obtain normalization pressure data;
and inputting the production data into a normalized gas production calculation formula to obtain the normalized gas production data.
5. A water invasion identification device for a gas well, wherein the device is used for realizing the water invasion identification method for a gas well according to any one of the preceding claims 1 to 4, the device comprising:
The acquisition module is used for acquiring production data of the gas well;
the calculation module is used for substituting the production data into the flowing material balance relation of the abnormal high-pressure gas reservoir to obtain the normalized pressure data and the normalized gas production data of the gas well;
the acquisition module is also used for acquiring pressure change trend information according to the normalized pressure data and the normalized gas production data;
the identification module is used for obtaining pressure deviation points according to the pressure change trend information;
the identification module is further used for determining the first moment corresponding to the pressure deviation point as the moment when the gas well is immersed in water.
6. An electronic device, the electronic device comprising: a processor, a memory and a bus, the memory storing machine-readable instructions executable by the processor, the processor in communication with the memory via the bus when the electronic device is operating, the machine-readable instructions being executed by the processor to implement the water invasion identification method of a gas well according to any one of claims 1 to 4.
7. A computer readable storage medium having stored therein a computer program loaded and executed by a processor to implement a method of water invasion identification of a gas well according to any one of claims 1 to 4.
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