CN108180008B - Method and device for predicting collectable reserve, electronic device and storage medium - Google Patents
Method and device for predicting collectable reserve, electronic device and storage medium Download PDFInfo
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Abstract
The invention provides a method and a device for predicting recoverable reserves, electronic equipment and a storage medium, and relates to the technical field of oil-gas exploration. The method for predicting the recoverable reserves comprises the following steps: acquiring the pseudo-bottom flowing pressure of the shale gas well to be detected based on a relation curve of the pseudo-pressure difference of the shale gas well to be detected and the daily yield of the shale gas well to be detected multiplied by the arithmetic square root of time, wherein the pseudo-pressure difference is the difference between the pseudo-formation pressure and the pseudo-bottom flowing pressure; acquiring the accumulated yield when the bottom hole flow pressure reaches the actual output pressure of the shale gas well to be detected based on the simulated bottom hole flow pressure and the prestored daily yield of the shale gas well to be detected, and taking the accumulated yield as the accumulated yield of the prediction stable yield period; acquiring predicted decreasing stage accumulated yield based on a first ratio of shale gas layer adsorbed gas to free gas, a second ratio of the accumulated yield in the stable yield stage to the accumulated yield in the decreasing stage, a relation that the first ratio is equal to the second ratio and the predicted stable yield stage accumulated yield; and taking the sum of the predicted stationary phase cumulative yield and the predicted descending phase cumulative yield as the predicted recoverable reserves. The method can better predict the recoverable reserves.
Description
Technical Field
The invention relates to the technical field of computers, in particular to a method, device and electronic equipment for predicting collectable reserves and a storage medium.
Background
At present, the domestic prediction of the recoverable reserves of the shale gas technology is mostly started from two aspects of establishing a theoretical productivity model and deducing by referring to an empirical calculation formula, and an analytical method and a numerical simulation method are generally adopted to predict the production rule of the shale gas well so as to evaluate the recoverable reserves. The domestic prediction method only predicts the recoverable reserves of the shale gas technology by means of theoretical derivation, formula derivation, numerical simulation and the like, and meanwhile, a large number of theoretical research results do not consider the influences of different geological characteristics, fracturing modification scale difference and shale gas adsorption analysis on the recoverable reserves in different stages, so that the deviation of the prediction results and the actual situation is large.
Disclosure of Invention
In view of this, embodiments of the present invention provide a method and an apparatus for predicting an amount of recoverable resources, an electronic device, and a storage medium.
In order to achieve the purpose, the technical scheme adopted by the invention is as follows:
in a first aspect, an embodiment of the present invention provides a method for predicting recoverable reserves, where the method includes: acquiring the pseudo-bottom flowing pressure of the shale gas well to be detected based on a relation curve of the pseudo-pressure difference of the shale gas well to be detected and the daily yield of the shale gas well to be detected multiplied by the arithmetic square root of time, wherein the pseudo-pressure difference is the difference between the pseudo-formation pressure and the pseudo-bottom flowing pressure; acquiring the accumulated yield when the bottom hole flow pressure reaches the actual output pressure of the shale gas well to be detected based on the simulated bottom hole flow pressure and the prestored daily yield of the shale gas well to be detected, and taking the accumulated yield as the accumulated yield of the shale gas well to be detected in the stable yield period; acquiring the predicted decreasing period accumulative yield of the shale gas well to be detected based on a first ratio of adsorbed gas to free gas of the shale gas layer, a second ratio of accumulative yield of a steady production period to accumulative yield of a decreasing period, a relation that the first ratio is equal to the second ratio and the predicted stable production period accumulative yield; and taking the sum of the predicted steady-production period cumulative production and the predicted decline period cumulative production as the predicted recoverable reserves of the shale gas well to be detected.
In a second aspect, the embodiment of the invention provides a recoverable reserve predicting device, which comprises a pseudo-bottom flow pressure obtaining module, a stable period accumulated yield obtaining module, a decreasing period accumulated yield obtaining module and a recoverable reserve obtaining module, wherein the pseudo-bottom flow pressure obtaining module is used for obtaining the pseudo-bottom flow pressure of a shale gas well to be tested based on a relation curve of the pseudo-pressure difference of the shale gas well to be tested and the arithmetic square root of the daily yield of the shale gas well to be tested multiplied by time, wherein the pseudo-pressure difference is the difference between the pseudo-formation pressure and the pseudo-bottom flow pressure; the stable period accumulated yield acquisition module is used for acquiring the accumulated yield when the bottom hole flow pressure reaches the actual output pressure of the shale gas well to be detected based on the planned bottom hole flow pressure and the prestored daily yield of the shale gas well to be detected, and the accumulated yield is used as the predicted stable period accumulated yield of the shale gas well to be detected; the decreasing period accumulated yield acquisition module is used for acquiring the predicted decreasing period accumulated yield of the shale gas well to be detected based on a first ratio of adsorbed gas to free gas of the shale gas layer, a second ratio of steady-state accumulated yield to decreasing period accumulated yield, a relation that the first ratio is equal to the second ratio, and the predicted steady-state accumulated yield; and the recoverable reserves obtaining module is used for taking the sum of the predicted steady-production period accumulative production and the predicted decreasing period accumulative production as the predicted recoverable reserves of the shale gas well to be detected.
In a third aspect, an embodiment of the present invention provides an electronic device, which includes a memory and a processor, where the memory stores computer instructions, and when the computer instructions are read and executed by the processor, the computer instructions cause the processor to execute the method for predicting the recoverable reserve provided in the first aspect.
In a fourth aspect, an embodiment of the present invention provides a storage medium, where computer instructions are stored in the storage medium, where the computer instructions, when read and executed, perform the method for predicting the recoverable storage capacity provided in the first aspect.
The method, the device, the electronic equipment and the storage medium for predicting the recoverable reserve, provided by the embodiment of the invention, are used for acquiring the simulated bottom hole flow pressure of the shale gas well to be detected through a relation curve based on the simulated pressure difference of the shale gas well to be detected and the daily output of the shale gas well to be detected multiplied by the arithmetic square root of time, wherein the simulated pressure difference is the difference between the simulated formation pressure and the simulated bottom hole flow pressure, then the accumulated output when the bottom hole flow pressure reaches the actual output pressure of the shale gas well to be detected is acquired based on the simulated bottom hole flow pressure and the pre-stored daily output of the shale gas well to be detected and is used as the predicted steady-term accumulated output of the shale gas well to be detected, then the predicted steady-term accumulated output of the shale gas well to be detected is acquired based on the first ratio of adsorbed gas and free gas of the shale gas layer, the second ratio of the steady-term accumulated output and the descending-term accumulated output, the relation that the first ratio is equal to the second ratio and the predicted steady-term accumulated output, and the predicted steady-term accumulated output of the gas well to be predicted recoverable reserve to be detected is finally used as the predicted recoverable reserve of the shale gas well to be detected . The method for predicting the recoverable reserves considers the influence of the recoverable reserves in different stages, so that the recoverable reserves of the shale gas well to be tested are predicted accurately, and the problem that the recoverable reserves predicted by the method for predicting the recoverable reserves in the prior art have large errors is solved.
In order to make the aforementioned and other objects, features and advantages of the present invention comprehensible, preferred embodiments accompanied with figures are described in detail below.
Drawings
In order to make the objects, technical solutions and advantages of the embodiments of the present invention clearer, the technical solutions in the embodiments of the present invention will be clearly and completely described below with reference to the drawings in the embodiments of the present invention, and it is obvious that the described embodiments are some, but not all, embodiments of the present invention. All other embodiments, which can be derived by a person skilled in the art from the embodiments given herein without making any creative effort, shall fall within the protection scope of the present invention.
FIG. 1 is a block diagram of an electronic device provided by an embodiment of the invention;
FIG. 2 is a flow chart illustrating a method of predicting recoverable reserves provided by embodiments of the present invention;
FIG. 3 is a partial flow chart of a method for predicting recoverable reserves provided by embodiments of the present invention;
FIG. 4 is a schematic diagram showing a material equilibration time versus normalized yield curve provided by an embodiment of the present invention;
FIG. 5 is a schematic diagram showing a simulated pressure differential versus the arithmetic square root of daily production times time provided by an embodiment of the present invention;
FIG. 6 illustrates a fit graph of the pseudo-bottom hole flow pressure of a shale gas well provided by an embodiment of the present invention;
fig. 7 is a block diagram showing a device for predicting recoverable storage according to an embodiment of the present invention.
Detailed Description
The technical solutions in the embodiments of the present invention will be clearly and completely described below with reference to the drawings in the embodiments of the present invention, and it is obvious that the described embodiments are only a part of the embodiments of the present invention, and not all of the embodiments. The components of embodiments of the present invention generally described and illustrated in the figures herein may be arranged and designed in a wide variety of different configurations. Thus, the following detailed description of the embodiments of the present invention, presented in the figures, is not intended to limit the scope of the invention, as claimed, but is merely representative of selected embodiments of the invention. All other embodiments, which can be derived by a person skilled in the art from the embodiments of the present invention without making any creative effort, shall fall within the protection scope of the present invention.
It should be noted that: like reference numbers and letters refer to like items in the following figures, and thus, once an item is defined in one figure, it need not be further defined and explained in subsequent figures. Meanwhile, in the description of the present invention, the terms "first", "second", and the like are used only for distinguishing the description, and are not to be construed as indicating or implying relative importance.
Fig. 1 shows a block diagram of an electronic device applicable to an embodiment of the present invention. As shown in FIG. 1, electronic device 100 includes a memory 102, a memory controller 104, one or more processors 106 (only one shown), a peripherals interface 108, a radio frequency module 110, an audio module 112, a display unit 114, and the like. These components communicate with each other via one or more communication buses/signal lines 116.
The memory 102 may be used to store software programs and modules, such as program instructions/modules corresponding to the method and apparatus for predicting the recoverable resource in the embodiment of the present invention, and the processor 106 executes various functional applications and data processing, such as the method for predicting the recoverable resource provided in the embodiment of the present invention, by executing the software programs and modules stored in the memory 102.
The memory 102 may include high speed random access memory, and may also include non-volatile memory, such as one or more magnetic storage devices, flash memory, or other non-volatile solid-state memory. Access to the memory 102 by the processor 106, and possibly other components, may be under the control of the memory controller 104.
The peripheral interface 108 couples various input/output devices to the processor 106 as well as to the memory 102. In some embodiments, the peripheral interface 108, the processor 106, and the memory controller 104 may be implemented in a single chip. In other examples, they may be implemented separately from the individual chips.
The rf module 110 is used for receiving and transmitting electromagnetic waves, and implementing interconversion between the electromagnetic waves and electrical signals, so as to communicate with a communication network or other devices.
The display unit 114 provides a display interface between the electronic device 100 and a user. In particular, display unit 114 displays video output to the user, the content of which may include text, graphics, video, and any combination thereof.
It will be appreciated that the configuration shown in FIG. 1 is merely illustrative and that electronic device 100 may include more or fewer components than shown in FIG. 1 or have a different configuration than shown in FIG. 1. The components shown in fig. 1 may be implemented in hardware, software, or a combination thereof.
First embodiment
Fig. 2 is a flowchart illustrating a method for predicting the recoverable storage capacity according to an embodiment of the present invention. Referring to fig. 2, the method for predicting the recoverable reserve comprises:
step S110: and acquiring the pseudo-bottom flowing pressure of the shale gas well to be detected based on a relation curve of the pseudo-pressure difference of the shale gas well to be detected and the arithmetic square root of the daily yield of the shale gas well to be detected multiplied by time, wherein the pseudo-pressure difference is the difference between the pseudo-formation pressure and the pseudo-bottom flowing pressure.
In the embodiment of the invention, when the steady production period accumulation of the shale gas well to be detected is measured, whether the stable generation stage of the shale gas well to be detected is the unstable linear flow stage or not can be judged firstly, so that when the stable production stage of the shale gas well to be detected is the unstable linear flow stage, the unstable linear flow factor is considered, and the predicted steady production period accumulation is accurate.
Therefore, in the embodiment of the present invention, before step S110, the method for predicting the recoverable storage capacity may further include:
judging whether the stable production period production stage of the shale gas well to be detected is an unstable linear flow stage; when yes, the simulated pressure differential is plotted against the arithmetic square root of daily production times time.
It can be understood that whether the steady production stage of the shale gas well to be tested is an unstable linear flow stage or not is judged, so that whether the prediction of the accumulated production corresponding to the unstable linear flow stage is executed or not is determined according to the result.
In the embodiment of the present invention, referring to fig. 3, judging whether the production stage of the steady production period of the shale gas well to be tested is an unstable linear flow stage may include:
step S101: and acquiring a relation curve of normalized yield and material balance time in a log-log coordinate system based on the daily yield, the accumulated yield and the bottom hole flow pressure of the shale gas well to be detected, wherein the normalized yield is the ratio of the daily yield to the pressure difference, and the material balance time is the ratio of the accumulated yield to the daily yield of the time corresponding to the accumulated yield.
In the embodiment of the invention, the daily yield, the accumulated yield and the bottom hole flow pressure of the shale gas well to be detected can be data input by a user or data acquired from other terminal equipment. Of course, the method for acquiring the daily output, the cumulative output and the bottom hole flow pressure of the shale gas well to be measured is not limited in the embodiment of the invention.
In the embodiment of the invention, the daily yield, the accumulated yield and the bottom hole flow pressure of the shale gas well to be detected can be actual measurement data during the production of the shale gas well to be detected.
In an embodiment of the present invention, the pressure difference is a difference between a bottom layer pressure and a bottom hole flowing pressure. The normalized yield is the daily yield corresponding to an actually measured flow pressure point divided by the pressure difference corresponding to the actually measured flow pressure point, and the cumulative yield corresponding to each day is divided by the daily yield corresponding to the day, so that the material balance time can be obtained.
Therefore, a relation curve between the normalized yield and the material balance time can be established based on the normalized yield and the material balance time, and particularly, a change curve of the normalized yield and the material balance time can be obtained by taking the ordinate as the normalized yield and the abscissa as the material balance time in a double logarithmic coordinate system.
Step S102: and judging whether the slope of the characteristic line segment corresponding to the relation curve of the normalized yield and the material balance time is a preset slope or not.
After obtaining a normalized yield versus time for material equilibrium, the characteristic line segment of the curve can be determined. And then, acquiring the slope of a characteristic line segment corresponding to the relationship curve of the normalized yield and the material equilibrium time.
In an embodiment of the present invention, the predetermined slope may be-1/2. Of course, the specific value of the predetermined slope is not limited in the embodiment of the present invention.
FIG. 4 is a graph of material equilibration time versus normalized yield corresponding to characteristic line segment slope-1/2.
Therefore, whether the slope of the characteristic line segment corresponding to the relation curve of the normalized yield and the material balance time is a preset slope or not can be judged, and whether the steady production stage of the shale gas well to be detected is an unstable linear flow stage or not can be determined according to the judgment result.
Step S103: if so, judging that the stable production period production stage of the shale gas well to be tested is an unstable linear flow stage; and if not, judging that the stable production period production stage of the shale gas well to be tested is not an unstable linear flow stage.
It can be understood that when the slope of the characteristic line segment corresponding to the relation curve between the normalized yield and the material balance time is determined to be the preset slope in step S102, the stable production period production stage of the shale gas well to be tested is determined to be the unstable linear flow stage; and when the slope of the characteristic line segment corresponding to the relation curve of the normalized yield and the material balance time is not the preset slope in the step S102, judging that the stable production period production stage of the shale gas well to be tested is not the unstable linear flow stage.
And when the stable production stage of the shale gas well to be tested is judged to be an unstable linear flow stage, acquiring a relation curve of the simulated pressure difference and the daily output multiplied by the arithmetic square root of time for subsequent determination of the simulated bottom hole flow pressure.
In an embodiment of the present invention, obtaining the relationship between the pseudo pressure difference and the daily production multiplied by the arithmetic square root of time may include:
and acquiring a relation curve of the arithmetic square root of the daily output multiplied by the time according to a preset Darcy equation, a preset continuity equation, a preset gas compression equation, a preset number of cracks and a preset contact area of the total matrix and the crack surface, wherein the simulated pressure difference is the difference between the simulated formation pressure and the simulated bottom hole flowing pressure.
In an embodiment of the present invention, the preset darcy equation may be:
the continuity equation may be:
the gas compression equation may be: pv ═ znRT.
Based on the preset darcy equation, the preset continuity equation and the preset gas compression equation, the following can be obtained:
and for the segmented pressure horizontal well, setting the number of the fractures of the shale gas well to be tested after large-scale fracturing to nf, namely presetting the number of the fractures. And setting the contact area of the total fractured matrix of the shale gas well to be tested and the fracture surface to be A, namely presetting the contact area. Thereby, it is possible to obtain:
wherein m is set to
It is possible to obtain:
Thus, a plot of the pseudo-differential pressure versus the arithmetic square root of the daily production multiplied by time is obtained. FIG. 5 is a graphical representation of an exemplary simulated pressure differential versus the arithmetic square root of daily production times time.
Thus, according to
Can obtain
Thus, can be based on
And predicting the pseudo-bottom hole flow pressure of the shale gas well to be tested. FIG. 6 is a graph showing a fit of the pseudo-bottom hole flow pressure of an exemplary one-page wellAnd the bottom hole flowing pressure corresponding to different time can be obtained.
Step S120: and acquiring the accumulated yield when the bottom hole flow pressure reaches the actual output pressure of the shale gas well to be detected based on the simulated bottom hole flow pressure and the prestored daily yield of the shale gas well to be detected, and taking the accumulated yield as the accumulated yield of the shale gas well to be detected in the stable yield period.
It can be understood that, the time when the bottom hole flow pressure reaches the actual output pressure can be obtained according to the pseudo bottom hole flow pressure obtained in step S110, and then the product obtained by multiplying the given daily output of the shale gas well to be tested by the time is the accumulated output when the bottom hole flow pressure reaches the actual output pressure of the shale gas well to be tested. And the accumulated yield is the predicted stable yield of the shale gas well to be detected.
Step S130: and acquiring the predicted decreasing period accumulative yield of the shale gas well to be detected based on a first ratio of the shale gas layer adsorbed gas to the free gas, a second ratio of the stable-yield period accumulative yield to the decreasing period accumulative yield, a relation that the first ratio is equal to the second ratio and the predicted stable-yield period accumulative yield.
In an embodiment of the present invention, a first ratio of shale gas formation adsorbed gas to free gas may be calculated. And then calculating the predicted decreasing period cumulative yield of the shale gas well to be detected based on a second ratio of the steady-state cumulative yield to the decreasing period cumulative yield, wherein the second ratio is equal to the first ratio. Namely, the steady production period cumulative yield obtained in the step S120 is divided by the first ratio, so as to obtain the predicted decreasing period cumulative yield of the shale gas well to be tested.
Step S140: and taking the sum of the predicted steady-production period cumulative production and the predicted decline period cumulative production as the predicted recoverable reserves of the shale gas well to be detected.
After the predicted steady-production period accumulative production and the predicted decreasing-period accumulative production corresponding to the shale gas well to be tested are obtained, the predicted recoverable reserve of the shale gas well to be tested can be obtained based on the sum of the predicted steady-production period accumulative production and the predicted decreasing-period accumulative production, namely the predicted recoverable reserve of the shale gas well to be tested is obtained by adding the predicted accumulative productions of the two stages.
For example, the recoverable reserve prediction method is applied to a shale gas horizontal well JY1HF well of a Fuling coke dam block in the Sichuan basin. The process flow is as follows: JY1HF well produced 6 million square/Tianding for 4 years, and the well produced mainly in a fixed-yield depressurization mode. By using the daily output, the accumulated output and the bottom hole flow pressure data of the well, a normalized output and material balance time flow characteristic identification chart of the daily output corresponding to the measured flow pressure point is drawn in a log-log coordinate system, the slope can be seen to be-1/2, and the flow state of the shale gas well is judged to be in an unstable linear flow stage within a long period of time, namely the flow of fluid flowing from a stratum to a crack or flowing from the crack to a shaft. Drawing a simulated differential pressure and a time productivity evaluation chart of multiplying the daily generated gas by the root number on a rectangular coordinate graph, and calculating a slope m so as to accurately predict the bottom hole flowing pressure; the accumulative yield is predicted to be the stable-yield-stage accumulative yield when the bottom hole flow pressure reaches the output pressure according to the given daily yield of the shale gas well, the stable-yield-stage accumulative yield of the JY1HF well is 0.866 million square, the accumulative yield of the JY1HF well is predicted to be 0.664 square when the contribution ratio of free gas and adsorbed gas and the established stable-yield-stage and descending-stage accumulative yield rule under the analysis condition of adsorbed gas are considered, and the recoverable yield of the JY1HF well technology is predicted to be 1.53 million square.
As another example, the invention is applied to a shale gas level JY6-2HF well in a Fuling Jordan block of the Sichuan basin. The process flow is as follows: JY6-2HF well produced according to constant pressure drop production mode. By using the daily output, the accumulated output and the bottom hole flow pressure data of the well, a normalized output and material balance time flow characteristic identification chart of the daily output corresponding to the measured flow pressure point is drawn in a log-log coordinate system, the slope can be seen to be-1/2, and the flow state of the shale gas well produced by constant pressure drop production is judged to be in an unstable linear flow stage within a long period of time, namely the flow of fluid flowing from a stratum to a crack or flowing from the crack to a shaft. Drawing a simulated differential pressure and a time productivity evaluation chart of multiplying the daily generated gas by the root number on a rectangular coordinate graph, and calculating a slope m so as to accurately predict the bottom hole flowing pressure; and a corresponding yield decreasing analysis model is established according to actual production data of the JY6-2HF well, and the recoverable storage capacity of the JY6-2HF well technology is predicted to be 3.74 billion square.
According to the method for predicting the recoverable reserves, the recoverable reserves at different stages are predicted, the influence of the recoverable reserves at different stages is considered, and adsorption analysis adjustment is considered, so that the recoverable reserves of the shale gas well to be tested can be predicted accurately, and the problem that the recoverable reserves predicted by the method for predicting the recoverable reserves in the prior art have large errors is solved.
Second embodiment
Referring to fig. 7, the apparatus 200 for predicting recoverable reserves includes a pseudo-bottom stream pressure obtaining module 210, a stable period accumulated yield obtaining module 220, a decreasing period accumulated yield obtaining module 230, and a recoverable reserves obtaining module 240. The pseudo-bottom flowing pressure obtaining module 210 is configured to obtain a pseudo-bottom flowing pressure of the shale gas well to be tested based on a relation curve of a pseudo-pressure difference of the shale gas well to be tested and an arithmetic square root of a daily yield of the shale gas well to be tested multiplied by time, where the pseudo-bottom flowing pressure is a difference between a pseudo-formation pressure and the pseudo-bottom flowing pressure; the steady-phase accumulated yield obtaining module 220 is configured to obtain an accumulated yield when the bottom hole flow pressure reaches the actual output pressure of the shale gas well to be detected based on the planned bottom hole flow pressure and the prestored daily yield of the shale gas well to be detected, and use the accumulated yield as a predicted steady-phase accumulated yield of the shale gas well to be detected; the decreasing period cumulative yield obtaining module 230 is configured to obtain a predicted decreasing period cumulative yield of the shale gas well to be tested based on a first ratio of adsorbed gas to free gas in the shale gas layer, a second ratio of steady-state cumulative yield to decreasing period cumulative yield, a relation that the first ratio is equal to the second ratio, and the predicted steady-state cumulative yield; the recoverable reserves obtaining module 240 is configured to use the sum of the predicted steady-production period cumulative yield and the predicted decline period cumulative yield as the predicted recoverable reserves of the shale gas well to be tested.
In an embodiment of the present invention, the device for predicting the recoverable storage capacity may further include a first determining module and a first curve obtaining module. The first judging module is used for judging whether the steady production stage of the shale gas well to be detected is an unstable linear flow stage; the first curve obtaining module is used for obtaining a relation curve of the simulated pressure difference and the arithmetic square root of the daily output multiplied by the time when the steady production stage of the shale gas well to be tested is an unstable linear flow stage.
In an embodiment of the present invention, the first determining module includes a curve obtaining unit, a determining executing unit, and a determining executing unit. The curve obtaining unit is used for obtaining a relation curve of normalized yield and material balance time in a log-log coordinate system based on the daily yield, the accumulated yield and the bottom hole flow pressure of the shale gas well to be detected, wherein the normalized yield is a ratio of the daily yield to a pressure difference, the material balance time is a ratio of the accumulated yield to the daily yield of time corresponding to the accumulated yield, and the judgment execution unit is used for judging whether the slope of a characteristic line segment corresponding to the relation curve of the normalized yield and the material balance time is a preset slope or not; the judgment execution unit is used for judging that the stable production period production stage of the shale gas well to be detected is an unstable linear flow stage when the slope of a characteristic line segment corresponding to the relation curve of the normalized yield and the material balance time is a preset slope; and when the slope of the characteristic line segment corresponding to the relation curve of the normalized yield and the material balance time is not a preset slope, judging that the stable production period production stage of the shale gas well to be tested is not an unstable linear flow stage.
In an embodiment of the invention, the first curve obtaining module is specifically configured to, when the steady-production period production stage of the shale gas well to be tested is an unstable linear flow stage, obtain a relation curve of an arithmetic square root of a pseudo-pressure difference and a daily output multiplied by time based on a preset darcy equation, a preset continuity equation, a preset gas compression equation, a preset number of fractures and a preset contact area between a total matrix and a fracture surface, where the pseudo-pressure difference is a difference between a pseudo-formation pressure and a pseudo-bottom flow pressure.
Third embodiment
Referring to fig. 1, the electronic device 100 includes a memory 102 and a processor 106, where the memory 102 stores computer instructions, and when the computer instructions are read and executed by the processor 106, the processor 106 executes the method for predicting the recoverable resource according to the first embodiment of the present invention.
Fourth embodiment
A fourth embodiment of the present invention provides a storage medium having stored therein computer instructions, wherein the computer instructions, when read and executed, perform the method for predicting the recoverable storage provided by the first embodiment of the present invention.
In summary, according to the method, the apparatus, the electronic device and the storage medium for predicting recoverable reserves provided in the embodiments of the present invention, the pseudo-bottom flow pressure of the shale gas well to be tested is obtained through a relation curve based on the pseudo-pressure difference of the shale gas well to be tested and the daily output of the shale gas well to be tested multiplied by the arithmetic square root of time, where the pseudo-pressure difference is a difference between the pseudo-formation pressure and the pseudo-bottom flow pressure, then the accumulated output when the bottom flow pressure reaches the actual output pressure of the shale gas well to be tested is obtained based on the pseudo-bottom flow pressure and the pre-stored daily output of the shale gas well to be tested, and is used as the predicted steady output of the shale gas well to be tested, and then based on the first ratio of the shale gas layer adsorbed gas and the free gas, the second ratio of the steady output and the decreased output, the relation that the first ratio is equal to the second ratio and the predicted steady output, the predicted steady output of the shale gas well to be tested is obtained, and finally, taking the sum of the predicted steady-production period accumulative production and the predicted decreasing period accumulative production as the predicted recoverable reserves of the shale gas well to be detected. The method for predicting the recoverable reserves considers the influence of the recoverable reserves in different stages, so that the recoverable reserves of the shale gas well to be tested are predicted accurately, and the problem that the recoverable reserves predicted by the method for predicting the recoverable reserves in the prior art have large errors is solved.
It should be noted that, in the present specification, the embodiments are all described in a progressive manner, each embodiment focuses on differences from other embodiments, and the same and similar parts among the embodiments may be referred to each other. For the device-like embodiment, since it is basically similar to the method embodiment, the description is simple, and for the relevant points, reference may be made to the partial description of the method embodiment.
In the embodiments provided in the present application, it should be understood that the disclosed apparatus and method can be implemented in other ways. The apparatus embodiments described above are merely illustrative, and for example, the flowchart and block diagrams in the figures illustrate the architecture, functionality, and operation of possible implementations of apparatus, methods and computer program products according to various embodiments of the present invention. In this regard, each block in the flowchart or block diagrams may represent a module, segment, or portion of code, which comprises one or more executable instructions for implementing the specified logical function(s). It should also be noted that, in some alternative implementations, the functions noted in the block may occur out of the order noted in the figures. For example, two blocks shown in succession may, in fact, be executed substantially concurrently, or the blocks may sometimes be executed in the reverse order, depending upon the functionality involved. It will also be noted that each block of the block diagrams and/or flowchart illustration, and combinations of blocks in the block diagrams and/or flowchart illustration, can be implemented by special purpose hardware-based systems which perform the specified functions or acts, or combinations of special purpose hardware and computer instructions.
In addition, the functional modules in the embodiments of the present invention may be integrated together to form an independent part, or each module may exist separately, or two or more modules may be integrated to form an independent part.
The 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 invention may be embodied in the form of a software product, which is stored in a storage medium and includes instructions for causing a computer device (which may be a personal computer, a server, or a network device) to execute all or part of the steps of the method according to the embodiments of the present invention. And the aforementioned storage medium includes: a U-disk, a removable hard disk, a Read-Only Memory (ROM), a Random Access Memory (RAM), a magnetic disk or an optical disk, and other various media capable of storing program codes. It is noted that, herein, relational terms such as first and second, and the like may be used solely to distinguish one entity or action from another entity or action without necessarily requiring or implying any actual such relationship or order between such entities or actions. Also, 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 an … …" does not exclude the presence of other identical elements in a process, method, article, or apparatus that comprises the element.
The above description is only a preferred embodiment of the present invention and is not intended to limit the present invention, and various modifications and changes may be made by those skilled in the art. Any modification, equivalent replacement, or improvement made within the spirit and principle of the present invention should be included in the protection scope of the present invention. It should be noted that: like reference numbers and letters refer to like items in the following figures, and thus, once an item is defined in one figure, it need not be further defined and explained in subsequent figures.
The above description is only for the specific embodiments of the present invention, but the scope of the present invention is not limited thereto, and any person skilled in the art can easily conceive of the changes or substitutions within the technical scope of the present invention, and all the changes or substitutions should be covered within the scope of the present invention. Therefore, the protection scope of the present invention shall be subject to the protection scope of the claims.
Claims (10)
1. A method of predicting recoverable reserves, the method comprising:
acquiring the pseudo-bottom flowing pressure of the shale gas well to be detected based on a relation curve of the pseudo-pressure difference of the shale gas well to be detected and the daily yield of the shale gas well to be detected multiplied by the arithmetic square root of time, wherein the pseudo-pressure difference is the difference between the pseudo-formation pressure and the pseudo-bottom flowing pressure;
acquiring the accumulated yield when the bottom hole flow pressure reaches the actual output pressure of the shale gas well to be detected based on the simulated bottom hole flow pressure and the prestored daily yield of the shale gas well to be detected, and taking the accumulated yield as the accumulated yield of the shale gas well to be detected in the stable yield period; obtaining the time when the bottom hole flow pressure reaches the actual output pressure according to the simulated bottom hole flow pressure, taking the product of the daily output of the shale gas well to be detected and the time when the bottom hole flow pressure reaches the actual output pressure as the accumulated output when the bottom hole flow pressure reaches the actual output pressure of the shale gas well to be detected, and taking the accumulated output as the accumulated output of the predicted steady production period;
acquiring the predicted decreasing period accumulative yield of the shale gas well to be detected based on a first ratio of adsorbed gas to free gas of the shale gas layer, a second ratio of accumulative yield of a steady production period to accumulative yield of a decreasing period, a relation that the first ratio is equal to the second ratio and the predicted stable production period accumulative yield;
and taking the sum of the predicted steady-production period cumulative production and the predicted decline period cumulative production as the predicted recoverable reserves of the shale gas well to be detected.
2. The method of claim 1, wherein before predicting the bottom hole flow pressure of the shale gas well under test based on a plot of the well pseudo pressure difference of the shale gas under test versus the daily production of the shale gas well under test multiplied by the arithmetic square root of time, the method further comprises:
judging whether the stable production period production stage of the shale gas well to be detected is an unstable linear flow stage;
when yes, the simulated pressure differential is plotted against the arithmetic square root of daily production times time.
3. The method of claim 2, wherein the judging whether the steady production stage of the shale gas well to be tested is an unstable linear flow stage comprises:
acquiring a relation curve of normalized yield and material balance time in a log-log coordinate system based on the daily yield, the accumulated yield and the bottom hole flow pressure of the shale gas well to be detected, wherein the normalized yield is the ratio of the daily yield to the pressure difference, and the material balance time is the ratio of the accumulated yield to the daily yield of the time corresponding to the accumulated yield;
judging whether the slope of a characteristic line segment corresponding to the relationship curve of the normalized yield and the material balance time is a preset slope or not;
if so, judging that the stable production period production stage of the shale gas well to be tested is an unstable linear flow stage;
and if not, judging that the stable production period production stage of the shale gas well to be tested is not an unstable linear flow stage.
4. The method of claim 2, wherein when yes, obtaining the pseudo-pressure differential versus daily production multiplied by the arithmetic square root of time comprises:
if so, acquiring a relation curve of the arithmetic square root of the simulated differential pressure and the daily output multiplied by the time based on a preset Darcy equation, a preset continuity equation, a preset gas compression equation, a preset number of cracks and a preset contact area of the total matrix and the crack surface, wherein the simulated differential pressure is the difference between the simulated formation pressure and the simulated bottom hole flowing pressure.
5. A device for predicting recoverable reserves, which is characterized by comprising a simulated bottom hole flow pressure acquisition module, a stable period accumulated yield acquisition module, a decreasing period accumulated yield acquisition module and a recoverable reserves acquisition module,
the simulated bottom hole flowing pressure obtaining module is used for obtaining the simulated bottom hole flowing pressure of the shale gas well to be detected based on a relation curve of the simulated pressure difference of the shale gas well to be detected and the arithmetic square root of the daily output of the shale gas well to be detected multiplied by time, wherein the simulated pressure difference is the difference between the simulated formation pressure and the simulated bottom hole flowing pressure;
the stable period accumulated yield acquisition module is used for acquiring the accumulated yield when the bottom hole flow pressure reaches the actual output pressure of the shale gas well to be detected based on the planned bottom hole flow pressure and the prestored daily yield of the shale gas well to be detected, and the accumulated yield is used as the predicted stable period accumulated yield of the shale gas well to be detected; obtaining the time when the bottom hole flow pressure reaches the actual output pressure according to the simulated bottom hole flow pressure, taking the product of the daily output of the shale gas well to be detected and the time when the bottom hole flow pressure reaches the actual output pressure as the accumulated output when the bottom hole flow pressure reaches the actual output pressure of the shale gas well to be detected, and taking the accumulated output as the accumulated output of the predicted steady production period;
the decreasing period accumulated yield acquisition module is used for acquiring the predicted decreasing period accumulated yield of the shale gas well to be detected based on a first ratio of adsorbed gas to free gas of the shale gas layer, a second ratio of steady-state accumulated yield to decreasing period accumulated yield, a relation that the first ratio is equal to the second ratio, and the predicted steady-state accumulated yield;
and the recoverable reserves obtaining module is used for taking the sum of the predicted steady-production period accumulative production and the predicted decreasing period accumulative production as the predicted recoverable reserves of the shale gas well to be detected.
6. The apparatus of claim 5, further comprising a first determining module and a first curve obtaining module, wherein,
the first judging module is used for judging whether the stable production stage of the shale gas well to be detected is an unstable linear flow stage;
the first curve obtaining module is used for obtaining a relation curve of the simulated pressure difference and the arithmetic square root of the daily output multiplied by the time when the steady production stage of the shale gas well to be tested is an unstable linear flow stage.
7. The apparatus of claim 6, wherein the first determining module comprises a curve obtaining unit, a determining executing unit and a determining executing unit, wherein,
the curve obtaining unit is used for obtaining a relation curve of normalized yield and material balance time in a log-log coordinate system based on the daily yield, the accumulated yield and the bottom hole flow pressure of the shale gas well to be detected, wherein the normalized yield is the ratio of the daily yield to the pressure difference, and the material balance time is the ratio of the accumulated yield to the daily yield of the time corresponding to the accumulated yield;
the judgment execution unit is used for judging whether the slope of a characteristic line segment corresponding to the relationship curve of the normalized yield and the material balance time is a preset slope or not;
the judgment execution unit is used for judging that the stable production period production stage of the shale gas well to be detected is an unstable linear flow stage when the slope of a characteristic line segment corresponding to the relation curve of the normalized yield and the material balance time is a preset slope; and when the slope of the characteristic line segment corresponding to the relation curve of the normalized yield and the material balance time is not a preset slope, judging that the stable production period production stage of the shale gas well to be tested is not an unstable linear flow stage.
8. The device of claim 6, wherein the first curve obtaining module is specifically configured to, when the steady-state production phase of the shale gas well to be tested is an unstable linear flow phase, obtain a relation curve of a pseudo-pressure difference and an arithmetic square root of a daily production multiplied by time based on a preset darcy equation, a preset continuity equation, a preset gas compression equation, a preset number of fractures and a preset contact area of a total matrix and a fracture surface, wherein the pseudo-pressure difference is a difference between a pseudo-formation pressure and a pseudo-bottom flow pressure.
9. An electronic device, comprising a memory and a processor, the memory storing computer instructions that, when read and executed by the processor, cause the processor to perform the method of any of claims 1-4.
10. A storage medium having stored thereon computer instructions, wherein the computer instructions, when read and executed, perform the method of any one of claims 1-4.
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| CN111101930B (en) * | 2019-12-19 | 2022-05-20 | 西南石油大学 | Single-well exploitation production-increasing potential evaluation method in gas reservoir development mode |
| CN113222204B (en) * | 2020-02-06 | 2024-03-05 | 中国石油天然气股份有限公司 | Fracture-cavity type oil reservoir stable production well yield prediction method, device, equipment and storage medium |
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