Method, system and equipment for judging gas storage effect of gas injection development oil reservoir and medium

Abstract

The invention discloses a method, a system, equipment and a medium for judging the gas storage effect of a gas injection development oil reservoir, and the method comprises the following steps: calculating to obtain a stage accumulated gas injection underground volume and a stage accumulated gas production underground volume, and further calculating to obtain a stage gas storage ratio; calculating to obtain the underground volume of the stage accumulated oil production and the underground volume of the stage accumulated water production, and adding to obtain the total stage accumulated yield; a stage injection-production ratio is calculated according to the underground volume of the stage accumulated gas injection amount and the stage accumulated total yield; calculating an underground volume gas-liquid ratio according to the underground volume of the stage accumulated oil production, the underground volume of the stage accumulated water production and the underground volume of the stage accumulated gas production; the stage injection-production ratio and the underground volume gas-liquid ratio are substituted into stage gas storage ratio calculation, and then a gas storage ratio chart is obtained; and calculating the phase gas storage proportions of other production cycles, adding the result into the gas storage proportion chart, observing the phase gas storage proportions corresponding to different production cycles, and judging the gas storage effects and trends of different production cycles.

Description

Technical Field

[0001] The invention belongs to the technical field of oil reservoir development, and relates to a method, system, equipment and medium for judging the gas storage effect of oil reservoir development by gas injection. Background Art

[0002] For gas-driven reservoirs, the purpose of gas injection is to maximize the oil recovery rate of the reservoir. Gas injection is a reservoir gas injection process for improving oil recovery. Gas is injected into the reservoir through a series of injection wells to drive the residual crude oil into the surrounding production wells; therefore, the injected gas needs to be stored underground as much as possible to give full play to the miscibility of the injected gas and crude oil, component mass transfer, reduce crude oil viscosity, increase crude oil volume coefficient, and increase crude oil fluidity.

[0003] However, the gas injection reservoir development industry has been lacking methods to judge the gas storage effect, which is not conducive to the development of gas injection development. Summary of the invention

[0004] The purpose of the present invention is to overcome the shortcomings of the above-mentioned prior art and provide a method, system, equipment and medium for judging the gas storage effect of gas injection development oil reservoirs, which can accurately judge the gas storage effect of gas injection oil reservoirs.

[0005] In order to achieve the above object, the present invention adopts the following technical solutions:

[0006] A method for judging the gas storage effect of gas injection development in oil reservoirs includes the following steps:

[0007] The underground volume of the cumulative gas injection volume and the underground volume of the cumulative gas production volume in each stage are calculated, and then the gas storage ratio in each stage is calculated;

[0008] The underground volume of the cumulative oil production in the stage and the underground volume of the cumulative water production in the stage are calculated, and the cumulative total production in the stage is obtained by adding the underground volume of the cumulative oil production in the stage, the underground volume of the cumulative water production in the stage and the underground volume of the cumulative gas production in the stage;

[0009] The injection-production ratio of each stage is calculated based on the underground volume of the cumulative gas injection and the cumulative total production of each stage;

[0010] The underground volume gas-liquid ratio is calculated according to the underground volume of the cumulative oil production in the stage, the underground volume of the cumulative water production in the stage and the underground volume of the cumulative gas production in the stage;

[0011] The stage injection-production ratio and underground volume gas-liquid ratio are brought into the calculation of the stage gas storage ratio, and then the gas storage ratio chart is obtained. The horizontal axis of the gas storage ratio chart is the underground volume gas-liquid ratio, and the vertical axis is the stage gas storage ratio.

[0012] Calculate the gas storage ratio of other production cycles, add the results to the gas storage ratio chart, observe the gas storage ratio of different production cycles, and judge the gas storage effect and trend of different production cycles.

[0013] Preferably, the underground volume of the cumulative gas injection amount in a stage is obtained by multiplying the surface volume of the cumulative gas injection amount in the stage by the injected gas volume coefficient:

[0014] ΔG inj =G inj *B ginj

[0015] Where: ΔG inj G is the underground volume of the cumulative gas injection volume in the stage; inj B is the surface volume of the cumulative gas injection volume in the stage; ginj is the volume coefficient of injected gas;

[0016] The underground volume of the cumulative gas production in a stage is obtained by multiplying the surface volume of the cumulative gas production in the stage by the produced gas volume coefficient:

[0017] ΔQ g =G p *B gp

[0018] Where: ΔQ g G is the underground volume of the cumulative gas production in the stage; p B is the ground volume of the cumulative gas production in the stage; gp is the volume coefficient of produced gas.

[0019] Preferably, the gas storage ratio of a stage is obtained by dividing the difference between the underground volume of the cumulative gas injection volume of the stage and the underground volume of the cumulative gas production volume of the stage by the underground volume of the cumulative gas injection volume of the stage:

[0020]

[0021] Where: ΔSR g is the gas storage ratio in the stage; ΔG inj ΔQ is the underground volume of the cumulative gas injection volume in the stage; g It is the underground volume of cumulative gas production in that stage.

[0022] Preferably, the underground volume of the cumulative oil production of the stage is obtained by dividing the cumulative oil production of the stage by the density of the ground crude oil and then multiplying it by the crude oil volume coefficient:

[0023]

[0024] Where: ΔQ o is the underground volume of the cumulative oil production in the stage, N p is the cumulative surface volume of oil production in the stage, ρ o is the density of crude oil on the ground, Boi is the crude oil volume coefficient;

[0025] The underground volume of the cumulative water production in a stage is obtained by dividing the cumulative water production in a stage by the formation water density and then multiplying it by the formation water volume coefficient:

[0026]

[0027] Where: ΔQ w is the underground volume of the cumulative water production in the stage, W p is the cumulative water production volume at the stage, ρ w is the formation water density, B w is the formation water volume coefficient.

[0028] Preferably, the stage injection-production ratio is calculated by dividing the underground volume of the cumulative gas injection volume of the stage by the cumulative total production of the stage:

[0029] ΔQ owg =ΔQ o +ΔQ w +ΔQ g

[0030] Where: ΔQ g ΔQ is the underground volume of the cumulative gas production in the stage; o is the underground volume of the cumulative oil production in the stage; ΔQ w is the underground volume of the cumulative water production in that stage.

[0031] Preferably, the underground volume gas-liquid ratio is calculated by dividing the underground volume of the cumulative gas production in the stage by the underground volume of the cumulative liquid production in the stage, and the underground volume of the cumulative liquid production in the stage is the sum of the underground volume of the cumulative oil production in the stage and the underground volume of the cumulative water production in the stage:

[0032]

[0033] Where: GLR is the underground volume gas-liquid ratio, ΔQ g ΔQ is the underground volume of the cumulative gas production in the stage; o is the underground volume of the cumulative oil production in the stage; ΔQ w is the underground volume of the cumulative water production in that stage.

[0034] Preferably, the stage injection-production ratio and the underground volume gas-liquid ratio are brought into the calculation of the stage gas storage ratio:

[0035]

[0036] Where ΔSR g is the gas storage ratio in the stage, ΔZ inj-p Stage injection-production ratio, GLR is the underground volume gas-liquid ratio.

[0037] A system for judging the gas storage effect of gas injection development in oil reservoirs, comprising:

[0038] The stage gas storage ratio calculation module is used to calculate the underground volume of the stage cumulative gas injection and the underground volume of the stage cumulative gas production, and then calculate the stage gas storage ratio;

[0039] The stage cumulative total production calculation module is used to calculate the stage cumulative oil production underground volume and the stage cumulative water production underground volume, and add the stage cumulative oil production underground volume, the stage cumulative water production underground volume and the stage cumulative gas production underground volume to obtain the stage cumulative total production;

[0040] The stage injection-production ratio calculation module is used to calculate the stage injection-production ratio according to the underground volume of the stage cumulative gas injection volume and the stage cumulative total production;

[0041] An underground volume gas-liquid ratio calculation module is used to calculate the underground volume gas-liquid ratio according to the underground volume of the cumulative oil production in a stage, the underground volume of the cumulative water production in a stage, and the underground volume of the cumulative gas production in a stage;

[0042] The gas storage ratio chart establishment module is used to bring the stage injection-production ratio and the underground volume gas-liquid ratio into the stage gas storage ratio calculation, and then obtain the gas storage ratio chart. The horizontal axis of the gas storage ratio chart is the underground volume gas-liquid ratio, and the vertical axis is the stage gas storage ratio.

[0043] The gas storage effect judgment module is used to calculate the gas storage ratio of the stages of other production cycles, and add the results to the gas storage ratio chart, observe the gas storage ratios of the stages corresponding to different production cycles, and judge the gas storage effects and trends of different production cycles.

[0044] A computer device comprises a memory, a processor and a computer program stored in the memory and executable on the processor. When the processor executes the computer program, the steps of the method for determining the gas storage effect of gas injection development in oil reservoirs are implemented.

[0045] A computer-readable storage medium stores a computer program, which, when executed by a processor, implements the steps of the method for determining the gas storage effect of gas injection development in an oil reservoir.

[0046] Compared with the prior art, the present invention has the following beneficial effects:

[0047] The present invention creatively derives and establishes a gas storage ratio chart, that is, a chart showing the relationship between the stage gas storage ratio and the stage injection-production ratio and the underground volume gas-liquid ratio; when the injection-production ratio and the gas-liquid ratio take different values, the corresponding stage gas storage ratio is calculated; the corresponding curve under the injection-production ratio is obtained by connecting the calculated data points; according to the same method, the stage gas storage ratios under different injection-production ratios and different gas-liquid ratios are connected, so as to establish a theoretical chart of the gas storage ratio and the underground gas-liquid ratio. With the general theoretical chart of the gas storage ratio, the gas storage effect of the actual gas injection development reservoir can be evaluated, specifically, the gas storage ratio and the gas-liquid ratio of the actual gas injection development reservoir are calculated, and the actual gas injection data is put into the general chart of the gas storage ratio to determine the size of the gas storage ratio; and according to the change trend of the gas storage ratio and the gas-liquid ratio data points, the change in the gas production volume can be further determined, thereby determining the change in the gas storage ratio and the gas storage effect. BRIEF DESCRIPTION OF THE DRAWINGS

[0048] Figure 1 A gas storage ratio chart for gas injection development of oil reservoirs according to the present invention;

[0049] Figure 2 This is the X gas injection development reservoir gas storage ratio chart of the present invention. DETAILED DESCRIPTION

[0050] The technical solutions in the embodiments of the present invention will be clearly and completely described below in conjunction with the drawings in the embodiments of the present invention. Obviously, the described embodiments are only part of the embodiments of the present invention, rather than all the embodiments; based on the embodiments of the present invention, all other embodiments obtained by ordinary technicians in this field without making creative work are within the scope of protection of the present invention.

[0051] It should be noted that the words "front", "rear", "left", "right", "up" and "down" used in the following description refer to directions in the drawings, and the words "inside" and "outside" refer to directions toward or away from the geometric center of a specific component, respectively.

[0052] Unless otherwise defined, all technical and scientific terms used herein have the same meaning as those generally understood by those skilled in the art of the present invention. The terms used herein in the specification of the present invention are only for the purpose of describing specific embodiments and are not intended to limit the present invention. The term "and / or" used herein includes any and all combinations of one or more related listed items.

[0053] The method for judging the gas storage effect of gas injection development in oil reservoirs of the present invention comprises the following steps:

[0054] (1) Calculation of underground volume of cumulative gas injection in each stage.

[0055] The cumulative gas injection volume in each stage in the report data is in ten thousand cubic meters and is the surface volume; for subsequent calculations, it needs to be converted into underground volume, that is, multiplied by the injected gas volume coefficient.

[0056] ΔG inj =G inj *B ginj (1)

[0057] Where: ΔG inj The underground volume of the cumulative gas injection volume in the stage, ten thousand cubic meters; G inj B is the ground volume of the cumulative gas injection volume in the stage, ten thousand cubic meters; ginj is the injected gas volume coefficient, dimensionless.

[0058] (2) Calculation of underground volume of cumulative gas production in each stage.

[0059] The cumulative gas production in each stage in the report data is in units of ten thousand cubic meters and is the surface volume; for subsequent calculations, it needs to be converted into underground volume, that is, multiplied by the produced gas volume coefficient.

[0060] ΔQ g =G p *B gp (2)

[0061] Where: ΔQ g The underground volume of the cumulative gas production in the stage, 10,000 cubic meters; G p The ground volume of the cumulative gas production in the stage, ten thousand cubic meters; B gp is the volume coefficient of produced gas, dimensionless.

[0062] (3) Calculation of gas storage ratio in each stage.

[0063] Stage gas storage ratio ΔSR g It is defined as the difference between the underground volume of the cumulative gas injection volume at a stage and the underground volume of the cumulative gas production at a stage, divided by the underground volume of the cumulative gas injection volume at a stage. The definition is as follows:

[0064]

[0065] Where: ΔSR g is the gas storage ratio in the stage; ΔG inj ΔQ is the underground volume of the cumulative gas injection volume in the stage; g It is the underground volume of cumulative gas production in that stage.

[0066] Substitute the cumulative gas injection volume in step 1 and the cumulative gas production volume in step 2 into the gas storage ratio definition formula in step 3 to obtain:

[0067]

[0068] (4) Calculation of underground volume of cumulative oil production during each stage.

[0069] The cumulative oil production in the report data is measured in 10,000 tons by mass. For subsequent calculations, the cumulative oil production needs to be converted into underground volume measured in 10,000 cubic meters; that is, the cumulative oil production is divided by the density of ground crude oil, and then multiplied by the crude oil volume coefficient.

[0070]

[0071] Where: ΔQ o is the underground volume of the cumulative oil production in the stage, N p is the cumulative surface volume of oil production in the stage, ρ o is the density of crude oil on the ground, B oi is the volume coefficient of crude oil.

[0072] (5) Calculation of underground volume of cumulative water production in each stage.

[0073] The cumulative water production in the report data is measured in ten thousand tons of mass. For subsequent calculations, the cumulative water production needs to be converted into underground volume measured in ten thousand cubic meters; that is, the cumulative water production is divided by the formation water density, and then multiplied by the formation water volume coefficient.

[0074]

[0075] Where: ΔQ w is the underground volume of the cumulative water production in the stage, W p is the cumulative water production volume at the stage, ρ w is the formation water density, B w is the formation water volume coefficient.

[0076] (6) Calculation of total cumulative output in each stage.

[0077] Cumulative total output of the stage ΔQ owg It includes the underground volume of the cumulative oil production in the stage, the underground volume of the cumulative water production in the stage, and the underground volume of the cumulative gas production in the stage, namely:

[0078] ΔQ owg =ΔQ o +ΔQ w +ΔQ g (7)

[0079] Where: ΔQ g ΔQ is the underground volume of the cumulative gas production in the stage; o is the underground volume of the cumulative oil production in the stage; ΔQ w is the underground volume of the cumulative water production in that stage.

[0080] Substitute the cumulative oil production of step 4, the cumulative water production of step 5, and the cumulative gas production of step 2 into the definition of the cumulative total production of the stage, and we get:

[0081]

[0082] (7) Calculation of injection-production ratio in each stage.

[0083] The stage injection-production ratio is defined as the underground volume of the cumulative gas injection volume divided by the cumulative total production of the stage:

[0084]

[0085] Substitute the underground volume of the cumulative gas injection volume processed in step 1 and the total production of the stage calculated in step 6 into the definition of the stage injection-production ratio to obtain:

[0086]

[0087] Where: N p W is the cumulative oil production in the stage, in tons. p is the surface mass of water production in the stage, 10,000 tons; ρ o B is the density of crude oil on the ground, tons / cubic meter; oi is the crude oil volume coefficient, dimensionless; ρ w is the formation water density, tons / cubic meter; B w is the formation water volume coefficient, dimensionless.

[0088] (8) Calculation of underground volume gas-liquid ratio.

[0089] The underground volume gas-liquid ratio is defined as the underground volume of the cumulative gas production in a stage divided by the underground volume of the cumulative liquid production in a stage (i.e., the sum of the underground volume of the cumulative oil production in a stage and the underground volume of the cumulative water production in a stage):

[0090]

[0091] Where: GLR is the underground volume gas-liquid ratio, ΔQ g ΔQ is the underground volume of the cumulative gas production in the stage; o is the underground volume of the cumulative oil production in the stage; ΔQ w is the underground volume of the cumulative water production in that stage.

[0092] (9) Establishment of gas storage ratio chart.

[0093] Substitute the stage injection-production ratio calculated in step 7 and the underground volume gas-liquid ratio calculated in step 8 into the stage gas storage ratio calculated in step 3, and further simplify to obtain:

[0094]

[0095] Where ΔSR g is the gas storage ratio in the stage, ΔZ inj-p Stage injection-production ratio, GLR is the underground volume gas-liquid ratio.

[0096] Establishment of theoretical chart of gas storage ratio: According to the derived stage gas storage ratio chart, expression (12) is calculated. When the injection-production ratio (0.1, 0.15, 0.2, 0.4, 0.6, 0.8, 1, 1.2) and the gas-liquid ratio take different values ​​(0.01-1), the corresponding stage gas storage ratio is calculated. For example, when the injection-production ratio takes a value of 0.1, the underground volume gas-liquid ratio takes a value of 0.01. At this time, the calculated stage gas storage ratio is 0.90099. The gas storage ratios of other stages under this injection-production ratio can be calculated in the same way. The calculation results are shown in Table 1. The corresponding curve under this injection-production ratio can be obtained by connecting the calculated data points. In the same way, the stage gas storage ratios under different injection-production ratios and different gas-liquid ratios can be connected, so as to establish a theoretical chart of gas storage ratio and underground volume gas-liquid ratio. The horizontal axis is the underground volume gas-liquid ratio, and the vertical axis is the stage gas storage ratio. Figure 1 .

[0097] Table 1

[0098]

[0099]

[0100]

[0101]

[0102] (10) Determination of gas storage effect.

[0103] Calculate the gas storage ratio of other production cycles and add the results to the gas storage ratio chart, observe the gas storage ratio corresponding to different production cycles, and judge the gas storage effect and trend of different production cycles.

[0104] The following is a calculation using a specific reservoir example:

[0105] Processing the production data of gas injection development of oil reservoir X, the crude oil density is 0.86, the crude oil volume coefficient is 1.071, the formation water density is 1.1, the formation water volume coefficient is 1, the injected gas volume coefficient and the produced gas volume coefficient are both 0.0035. The following takes the production data of gas injection development of oil reservoir X in July 2014 as an example to show the specific detailed calculation process (Table 2).

[0106] Step 1: Calculate the monthly underground gas injection volume. Multiply the reported monthly gas injection volume by the injected gas volume coefficient 0.0035 to obtain the monthly underground gas injection volume of 0.2957311 million cubic meters.

[0107] Step 2: Calculate the monthly underground gas production volume. Multiply the reported monthly gas production by the injected gas volume coefficient of 0.0035 to obtain the monthly underground gas production of 0.029365 million cubic meters.

[0108] Step 3: Calculate the monthly gas storage ratio. Based on the stage gas storage ratio calculation formula (3), the difference between the monthly gas injection underground volume calculated in step 1 and the monthly gas production underground volume calculated in step 2 is divided by the monthly gas injection underground volume in step 1. The result is 0.900703714.

[0109] Step 4: Calculate the monthly underground oil production volume by dividing the reported monthly oil production by the crude oil density of 0.86 and then multiplying by the crude oil volume coefficient of 1.071 to obtain the monthly underground oil production of 1.434048837 million cubic meters;

[0110] Step 5: Calculate the monthly underground water volume. Divide the reported monthly water production by the formation water density 1.1, and then multiply by the formation water volume coefficient 1. The monthly underground water production is 234,845,454 cubic meters.

[0111] Step 6: Calculate the monthly underground volume of liquid production. Add the monthly underground volume of oil production calculated in step 4 and the monthly underground volume of water production calculated in step 5 to obtain the monthly underground volume of liquid production of 3782503383 cubic meters.

[0112] Step 7: Calculate the underground volume of gas-liquid ratio: Divide the monthly gas production underground volume calculated in step 2 by the calculated monthly liquid production underground volume calculated in step 6 to obtain the underground volume of gas-liquid ratio of 0.007763377;

[0113] Step 8: Input the monthly gas storage ratio calculated in step 3 and the gas-liquid ratio data points calculated in step 7 into the gas storage ratio theoretical chart 1.

[0114] In the same way, the data of other production months can be calculated, and finally all the example data points are put into the theoretical graph of gas storage ratio to establish Figure 2 .Depend on Figure 2 It can be seen that in the early stage of the X reservoir (i.e., when the underground volume gas-liquid ratio is in the range of 0 to 0.30), the calculated gas storage ratio is above 0.6, indicating that the gas storage ratio of the injected gas is large and the gas injection development reservoir gas drive utilization rate is high; however, as the gas injection proceeds, the gas production volume increases, the gas storage ratio decreases, and the gas injection utilization rate decreases.

[0115] Table 2

[0116]

[0117]

[0118]

[0119] The following are device embodiments of the present invention, which can be used to perform method embodiments of the present invention. For details not disclosed in the device embodiments, please refer to the method embodiments of the present invention.

[0120] In yet another embodiment of the present invention, a system for judging the gas storage effect of oil reservoirs during gas injection development is provided. The system for judging the gas storage effect of oil reservoirs during gas injection development can be used to implement the above-mentioned method for judging the gas storage effect of oil reservoirs during gas injection development. Specifically, the system for judging the gas storage effect of oil reservoirs during gas injection development includes a stage gas storage ratio calculation module, a stage cumulative total production calculation module, a stage injection-production ratio calculation module, an underground volume gas-liquid ratio calculation module, a gas storage ratio map establishment module and a gas storage effect judgment module.

[0121] Among them, the stage gas storage ratio calculation module is used to calculate the underground volume of the stage cumulative gas injection and the underground volume of the stage cumulative gas production, and then calculate the stage gas storage ratio.

[0122] The stage cumulative total production calculation module is used to calculate the underground volume of the stage cumulative oil production and the underground volume of the stage cumulative water production, and the stage cumulative total production is obtained by adding the underground volume of the stage cumulative oil production, the underground volume of the stage cumulative water production and the underground volume of the stage cumulative gas production.

[0123] The stage injection-production ratio calculation module is used to calculate the stage injection-production ratio according to the underground volume of the stage cumulative gas injection volume and the stage cumulative total production.

[0124] The underground volume gas-liquid ratio calculation module is used to calculate the underground volume gas-liquid ratio according to the underground volume of the cumulative oil production in a stage, the underground volume of the cumulative water production in a stage and the underground volume of the cumulative gas production in a stage.

[0125] The gas storage ratio chart establishment module is used to bring the stage injection-production ratio and the underground volume gas-liquid ratio into the stage gas storage ratio calculation, and then obtain the gas storage ratio chart. The horizontal axis in the gas storage ratio chart is the underground volume gas-liquid ratio, and the vertical axis is the stage gas storage ratio.

[0126] The gas storage effect judgment module is used to calculate the gas storage ratio of other production cycles, and add the results to the gas storage ratio chart, observe the gas storage ratio of different production cycles, and judge the gas storage effects and trends of different production cycles.

[0127] In another embodiment of the present invention, a terminal device is provided, which includes a processor and a memory, wherein the memory is used to store a computer program, the computer program includes program instructions, and the processor is used to execute the program instructions stored in the computer storage medium. The processor may be a central processing unit (CPU), or may be other general-purpose processors, digital signal processors (DSP), application-specific integrated circuits (ASIC), field-programmable gate arrays (FPGA) or other programmable logic devices, discrete gates or transistor logic devices, discrete hardware components, etc. It is the computing core and control core of the terminal, which is suitable for implementing one or more instructions, and is specifically suitable for loading and executing one or more instructions to implement the corresponding method flow or corresponding function; the processor described in the embodiment of the present invention can be used for the operation of the gas storage effect judgment method of gas injection development oil reservoir, including: calculating the underground volume of the cumulative gas injection volume and the underground volume of the cumulative gas production volume in the stage, and then calculating the gas storage ratio in the stage; calculating the underground volume of the cumulative oil production volume in the stage and the underground volume of the cumulative water production volume in the stage, and converting the underground volume of the cumulative oil production volume in the stage and the underground volume of the cumulative water production volume in the stage into the gas storage ratio; calculating ... water production volume in the stage and the underground volume of the cumulative The underground volume and the underground volume of the cumulative gas production in the stage are added to obtain the cumulative total production of the stage; the stage injection-production ratio is calculated according to the underground volume of the cumulative gas injection and the cumulative total production of the stage; the underground volume gas-liquid ratio is calculated according to the underground volume of the cumulative oil production, the underground volume of the cumulative water production and the underground volume of the cumulative gas production; the stage injection-production ratio and the underground volume gas-liquid ratio are brought into the calculation of the stage gas storage ratio, and then the gas storage ratio chart is obtained, the horizontal axis of the gas storage ratio chart is the underground volume gas-liquid ratio, and the vertical axis is the stage gas storage ratio; the stage gas storage ratios of other production cycles are calculated, and the results are added to the gas storage ratio chart, the stage gas storage ratios corresponding to different production cycles are observed, and the gas storage effects and trends of different production cycles are judged.

[0128] In another embodiment, the present invention further provides a computer-readable storage medium (Memory), which is a memory device in a terminal device for storing programs and data. It is understandable that the computer-readable storage medium here can include both the built-in storage medium in the terminal device and the extended storage medium supported by the terminal device. The computer-readable storage medium provides a storage space, which stores the operating system of the terminal. In addition, one or more instructions suitable for being loaded and executed by the processor are also stored in the storage space, and these instructions can be one or more computer programs (including program codes). It should be noted that the computer-readable storage medium here can be a high-speed RAM memory or a non-volatile memory, such as at least one disk memory.

[0129] One or more instructions stored in a computer-readable storage medium can be loaded and executed by a processor to implement the corresponding steps of the method for determining the gas storage effect of a gas-filled reservoir in the above-mentioned embodiment; one or more instructions in the computer-readable storage medium are loaded by the processor and the following steps are executed: the underground volume of the cumulative gas injection volume and the underground volume of the cumulative gas production volume in the stage are calculated, and then the gas storage ratio of the stage is calculated; the underground volume of the cumulative oil production volume and the underground volume of the cumulative water production volume in the stage are calculated, and the cumulative total production volume of the stage is obtained by adding the underground volume of the cumulative oil production volume, the underground volume of the cumulative water production volume and the underground volume of the cumulative gas production volume in the stage. ; The stage injection-production ratio is calculated according to the underground volume of the stage cumulative gas injection and the stage cumulative total production; the underground volume gas-liquid ratio is calculated according to the underground volume of the stage cumulative oil production, the underground volume of the stage cumulative water production and the underground volume of the stage cumulative gas production; the stage injection-production ratio and the underground volume gas-liquid ratio are brought into the stage gas storage ratio calculation, and then the gas storage ratio chart is obtained, the horizontal axis of the gas storage ratio chart is the underground volume gas-liquid ratio, and the vertical axis is the stage gas storage ratio; the stage gas storage ratios of other production cycles are calculated, and the results are added to the gas storage ratio chart, the stage gas storage ratios corresponding to different production cycles are observed, and the gas storage effects and trends of different production cycles are judged.

[0130] Those skilled in the art will appreciate that the embodiments of the present application may be provided as methods, systems, or computer program products. Therefore, the present application may adopt the form of a complete hardware embodiment, a complete software embodiment, or an embodiment in combination with software and hardware. Moreover, the present application may adopt the form of a computer program product implemented in one or more computer-usable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) that include computer-usable program code.

[0131] The present application is described with reference to the flowcharts and / or block diagrams of the methods, devices (systems), and computer program products according to the embodiments of the present application. It should be understood that each process and / or box in the flowchart and / or block diagram, as well as the combination of the processes and / or boxes in the flowchart and / or block diagram, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, a special-purpose computer, an embedded processor, or other programmable data processing device to generate a machine, so that the instructions executed by the processor of the computer or other programmable data processing device generate instructions for implementing the processes in the flowchart and / or block diagram. Figure 1 A process or multiple processes and / or boxes Figure 1 A device that provides the functions specified in a block or multiple blocks.

[0132] These computer program instructions may also be stored in a computer-readable memory capable of directing a computer or other programmable data processing device to operate in a specific manner, so that the instructions stored in the computer-readable memory produce an article of manufacture comprising an instruction device, which implements the process Figure 1 A process or multiple processes and / or boxes Figure 1 A function specified in one or more boxes.

[0133] These computer program instructions can also be loaded onto a computer or other programmable data processing device so that a series of operating steps are executed on the computer or other programmable device to produce a computer-implemented process, thereby providing instructions for implementing the process. Figure 1 A process or multiple processes and / or boxes Figure 1 A step that specifies a function in one or more boxes.

[0134] It should be noted that, in this article, relational terms such as first and second, etc. are only used to distinguish one entity or operation from another entity or operation, and do not necessarily require or imply any such actual relationship or order between these entities or operations. Moreover, the terms "include", "comprise" or any other variants thereof are intended to cover non-exclusive inclusion, so that a process, method, article or device including a series of elements includes not only those elements, but also other elements not explicitly listed, or also includes elements inherent to such process, method, article or device.

[0135] It should be understood that the above description is for illustration and not for limitation. Many embodiments and many applications beyond the examples provided will be apparent to those skilled in the art upon reading the above description. Therefore, the scope of the present teachings should not be determined with reference to the above description, but rather with reference to the foregoing claims and the full scope of equivalents to which such claims are entitled. For the purpose of comprehensiveness, all articles and references, including disclosures of patent applications and publications, are incorporated herein by reference. The omission of any aspect of the subject matter disclosed herein in the foregoing claims is not intended to be a waiver of such subject matter, nor should it be considered that the applicant has not considered such subject matter to be part of the disclosed inventive subject matter.

Claims

1. A method for judging the gas storage effect of gas injection development in oil reservoirs, characterized in that: The process includes: The underground volume of the cumulative gas injection volume and the underground volume of the cumulative gas production volume in each stage are calculated, and then the gas storage ratio in each stage is calculated; The underground volume of the cumulative oil production in the stage and the underground volume of the cumulative water production in the stage are calculated, and the cumulative total production in the stage is obtained by adding the underground volume of the cumulative oil production in the stage, the underground volume of the cumulative water production in the stage and the underground volume of the cumulative gas production in the stage; The injection-production ratio of each stage is calculated based on the underground volume of the cumulative gas injection and the cumulative total production of each stage; The underground volume gas-liquid ratio is calculated according to the underground volume of the cumulative oil production in the stage, the underground volume of the cumulative water production in the stage and the underground volume of the cumulative gas production in the stage; The stage injection-production ratio and underground volume gas-liquid ratio are brought into the calculation of the stage gas storage ratio, and then the gas storage ratio chart is obtained. The horizontal axis of the gas storage ratio chart is the underground volume gas-liquid ratio, and the vertical axis is the stage gas storage ratio. Calculate the gas storage ratio of other production cycles, add the results to the gas storage ratio chart, observe the gas storage ratio of different production cycles, and judge the gas storage effect and trend of different production cycles.

2. The method for determining the gas storage effect of gas injection development in oil reservoirs according to claim 1, characterized in that: The underground volume of the cumulative gas injection in a stage is obtained by multiplying the surface volume of the cumulative gas injection in a stage by the injected gas volume coefficient: ΔG inj =G inj *B ginj Where: ΔG inj G is the underground volume of the cumulative gas injection volume in the stage; inj B is the surface volume of the cumulative gas injection volume in the stage; ginj is the volume coefficient of injected gas; The underground volume of the cumulative gas production in a stage is obtained by multiplying the surface volume of the cumulative gas production in the stage by the produced gas volume coefficient: ΔQ g =G p *B gp Where: ΔQ g G is the underground volume of the cumulative gas production in the stage; p B is the ground volume of the cumulative gas production in the stage; gp is the volume coefficient of produced gas.

3. The method for determining the gas storage effect of gas injection development in oil reservoirs according to claim 1, characterized in that: The gas storage ratio of a stage is obtained by dividing the difference between the underground volume of the stage cumulative gas injection and the underground volume of the stage cumulative gas production by the underground volume of the stage cumulative gas injection: Where: ΔSR g is the gas storage ratio of the stage; ΔG inj ΔQ is the underground volume of the cumulative gas injection volume in the stage; g It is the underground volume of cumulative gas production in that stage.

4. The method for determining the gas storage effect of gas injection development in oil reservoirs according to claim 1, characterized in that: The underground volume of the cumulative oil production of the stage is obtained by dividing the cumulative oil production of the stage by the density of the ground crude oil and then multiplying it by the crude oil volume coefficient: Where: ΔQ o is the underground volume of the cumulative oil production in the stage, N p is the cumulative surface volume of oil production in the stage, ρ o is the density of crude oil on the ground, B oi is the crude oil volume coefficient; The underground volume of the cumulative water production in a stage is obtained by dividing the cumulative water production in a stage by the formation water density and then multiplying it by the formation water volume coefficient: Where: ΔQ w is the underground volume of the cumulative water production in the stage, W p is the cumulative water production volume at the stage, ρ w is the formation water density, B w is the formation water volume coefficient.

5. The method for determining the gas storage effect of gas injection development in oil reservoirs according to claim 1, characterized in that: The stage injection-production ratio is calculated by dividing the underground volume of the stage cumulative gas injection by the stage cumulative total production: ΔQ owg =ΔQ o +ΔQ w +ΔQ g Where: ΔQ g ΔQ is the underground volume of the cumulative gas production in the stage; o ΔQ is the underground volume of the cumulative oil production in the stage; w is the underground volume of the cumulative water production in that stage.

6. The method for determining the gas storage effect of gas injection development in oil reservoirs according to claim 1, characterized in that: The underground volume gas-liquid ratio is calculated by dividing the underground volume of the cumulative gas production in the stage by the underground volume of the cumulative liquid production in the stage. The underground volume of the cumulative liquid production in the stage is the sum of the underground volume of the cumulative oil production in the stage and the underground volume of the cumulative water production in the stage: Where: GLR is the underground volume gas-liquid ratio, ΔQ g ΔQ is the underground volume of the cumulative gas production in the stage; o ΔQ is the underground volume of the cumulative oil production in the stage; w is the underground volume of the cumulative water production in that stage.

7. The method for determining the gas storage effect of gas injection development in oil reservoirs according to claim 1, characterized in that: Substituting the stage injection-production ratio and underground volume gas-liquid ratio into the calculation of stage gas storage ratio is: Where ΔSR g is the gas storage ratio in the stage, ΔZ inj-p Stage injection-production ratio, GLR is the underground volume gas-liquid ratio.

8. A system for judging the gas storage effect of gas injection development in oil reservoirs, characterized in that: include: The stage gas storage ratio calculation module is used to calculate the underground volume of the stage cumulative gas injection and the underground volume of the stage cumulative gas production, and then calculate the stage gas storage ratio; The stage cumulative total production calculation module is used to calculate the stage cumulative oil production underground volume and the stage cumulative water production underground volume, and add the stage cumulative oil production underground volume, the stage cumulative water production underground volume and the stage cumulative gas production underground volume to obtain the stage cumulative total production; The stage injection-production ratio calculation module is used to calculate the stage injection-production ratio according to the underground volume of the stage cumulative gas injection volume and the stage cumulative total production; An underground volume gas-liquid ratio calculation module is used to calculate the underground volume gas-liquid ratio according to the underground volume of the cumulative oil production in a stage, the underground volume of the cumulative water production in a stage, and the underground volume of the cumulative gas production in a stage; The gas storage ratio chart establishment module is used to bring the stage injection-production ratio and the underground volume gas-liquid ratio into the stage gas storage ratio calculation, and then obtain the gas storage ratio chart. The horizontal axis of the gas storage ratio chart is the underground volume gas-liquid ratio, and the vertical axis is the stage gas storage ratio; The gas storage effect judgment module is used to calculate the gas storage ratio of the stages of other production cycles, and add the results to the gas storage ratio chart, observe the gas storage ratios of the stages corresponding to different production cycles, and judge the gas storage effects and trends of different production cycles.

9. A computer device comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, characterized in that: When the processor executes the computer program, the steps of the method for determining the gas storage effect of gas injection development in an oil reservoir as described in any one of claims 1 to 7 are implemented.

10. A computer-readable storage medium storing a computer program, characterized in that: When the computer program is executed by a processor, the steps of the method for determining the gas storage effect of gas injection development in an oil reservoir as claimed in any one of claims 1 to 7 are implemented.

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