A method, system, device and medium for judging gas storage effect of gas injection development reservoir

Abstract

The application discloses a kind of gas injection development reservoir gas storage effect judging method, system, equipment and medium, and the stage cumulative gas injection volume subvolume is calculated, and then the stage gas storage ratio is calculated;The stage cumulative oil production subvolume and stage cumulative water production subvolume are calculated, and the stage cumulative total production is added;According to stage cumulative gas injection volume subvolume and stage cumulative total production, stage injection-production ratio is calculated;According to stage cumulative oil production subvolume, stage cumulative water production subvolume and stage cumulative gas production subvolume, the subvolume gas-liquid ratio is calculated;Stage injection-production ratio and subvolume gas-liquid ratio are brought into stage gas storage ratio calculation, and then the gas storage ratio chart is obtained;The stage gas storage ratio of other production cycle is calculated, and the result is added to the gas storage ratio chart, the stage gas storage ratio corresponding to different production cycles is observed, and the gas storage effect and trend of different production cycles are judged.

Description

Technical Field

[0001] This invention belongs to the field of reservoir development technology and relates to a method, system, equipment and medium for judging the gas storage effect of gas injection development reservoirs. Background Technology

[0002] For gas-driven reservoirs, the purpose of gas injection is to maximize the recovery of crude oil. Gas injection is a reservoir gas injection process conducted to improve crude oil recovery. Through a series of injection wells, gas is injected into the reservoir to drive the remaining crude oil into the surrounding production wells. Therefore, the injected gas should be stored underground as much as possible to fully utilize the miscibility and mass transfer of the injected gas with the crude oil, reduce the viscosity of the crude oil, increase the volume coefficient of the crude oil, and increase the fluidity of the crude oil.

[0003] However, the gas injection development industry has long lacked methods for assessing gas storage effectiveness, which hinders the development of gas injection projects. Summary of the Invention

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

[0005] To achieve the above objectives, the present invention employs the following technical solution:

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

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

[0008] The underground volumes of cumulative oil production and cumulative water production for each stage are calculated. The total cumulative production for each stage is obtained by adding the underground volumes of cumulative oil production, cumulative water production, and cumulative gas production for each stage.

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

[0010] The underground volume gas-liquid ratio is calculated based on the underground volume of cumulative oil production, cumulative water production, and cumulative gas production.

[0011] The stage injection-production ratio and the underground volume gas-liquid ratio are substituted into the stage gas storage ratio calculation to 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.

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

[0013] Preferably, the underground volume of the staged cumulative gas injection is obtained by multiplying the surface volume of the staged cumulative gas injection by the injected gas volume factor:

[0014] ΔG inj =G inj *B ginj

[0015] In the formula: ΔG inj G represents the cumulative underground volume of gas injection during the stage. inj B represents the cumulative gas injection volume over the ground. ginj The injection gas volume coefficient;

[0016] The cumulative underground gas production volume is obtained by multiplying the cumulative surface gas production volume by the produced gas volume factor.

[0017] ΔQ g =G p *B gp

[0018] Where: ΔQ g G represents the cumulative underground gas production volume during a given period. p B represents the cumulative gas production per stage on the ground surface; gp This is the output gas volume coefficient.

[0019] Preferably, the staged gas storage ratio is obtained by dividing the difference between the staged cumulative gas injection volume and the staged cumulative gas production volume underground by the staged cumulative gas injection volume underground.

[0020]

[0021] In the formula: ΔSR g The gas storage ratio for each stage; ΔG inj The cumulative underground volume of gas injection in each stage; ΔQ g The underground volume representing the cumulative gas production at each stage.

[0022] Preferably, the underground volume of the staged cumulative oil production is obtained by dividing the staged cumulative oil production by the surface crude oil density and then multiplying by the crude oil volume factor:

[0023]

[0024] Where: ΔQ o The underground volume representing the cumulative oil production over a period of time, N p ρ represents the surface volume of the cumulative oil production over a given period. o B represents the density of crude oil at ground level.oi This is the crude oil volume coefficient;

[0025] The cumulative water production per stage and the groundwater volume are obtained by dividing the cumulative water production per stage by the formation water density and then multiplying by the formation water volume factor.

[0026]

[0027] Where: ΔQ w W represents the cumulative groundwater production volume over a given period. p ρ represents the cumulative water production per stage of the surface volume. w B is the density of formation water. w This is the formation water volume coefficient.

[0028] Preferably, the staged injection-production ratio is calculated by dividing the cumulative injection volume per stage by the cumulative total production per stage:

[0029] ΔQ owg =ΔQ o +ΔQ w +ΔQ g

[0030] Where: ΔQ g The underground volume representing the cumulative gas production per stage; ΔQ o The underground volume representing the cumulative oil production per stage; ΔQ w The underground volume represents the cumulative water production during a given period.

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

[0032]

[0033] In the formula: GLR is the underground gas-liquid ratio, ΔQ g The underground volume representing the cumulative gas production per stage; ΔQ o The underground volume representing the cumulative oil production per stage; ΔQ w The underground volume represents the cumulative water production during a given period.

[0034] Preferably, the staged injection-production ratio and the underground volume gas-liquid ratio are incorporated into the staged gas storage ratio calculation as follows:

[0035]

[0036] In the formula, ΔSR g The gas storage ratio at each stage is 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 reservoirs includes:

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

[0039] The phase cumulative total production calculation module is used to calculate the phase cumulative oil production underground volume and the phase cumulative water production underground volume. The phase cumulative total production is obtained by adding the phase cumulative oil production underground volume, the phase cumulative water production underground volume and the phase cumulative gas production underground volume.

[0040] The stage injection-production ratio calculation module is used to calculate the stage injection-production ratio based on the stage cumulative gas injection volume, underground volume, and stage cumulative total production.

[0041] The underground volume gas-liquid ratio calculation module is used to calculate the underground volume gas-liquid ratio based on the underground volume of cumulative oil production, underground volume of cumulative water production, and underground volume of cumulative gas production.

[0042] The gas storage ratio chart creation module is used to incorporate the stage injection-production ratio and the underground volume gas-liquid ratio into the stage gas storage ratio calculation to 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 other production cycles and add the results to the gas storage ratio chart to observe the gas storage ratio of different production cycles and judge the gas storage effect and trend of different production cycles.

[0044] A computer device includes a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein the processor executes the computer program to implement the steps of the method for judging the gas storage effect of gas injection development reservoir.

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

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

[0047] This invention creatively derives and establishes a gas storage ratio chart, specifically a chart showing the relationship between the stage gas storage ratio and the stage injection-production ratio and the underground gas-liquid ratio. Given different values ​​for the injection-production ratio and gas-liquid ratio, the corresponding stage gas storage ratio is calculated. Connecting the calculated data points yields the corresponding curve for that injection-production ratio. Following the same method, connecting the stage gas storage ratios under different injection-production ratios and different gas-liquid ratios establishes a theoretical chart of the gas storage ratio and the underground gas-liquid ratio. With this universal theoretical chart of the gas storage ratio, the gas storage effect of actual gas-injected reservoirs can be evaluated. Specifically, the gas storage ratio and gas-liquid ratio of the actual gas-injected reservoir are calculated, and the actual gas injection data is input into the universal chart to determine the size of the gas storage ratio. Furthermore, based on the changing trends of the gas storage ratio and gas-liquid ratio data points, changes in the amount of gas produced can be further determined, thereby judging changes in the gas storage ratio and the gas storage effect. Attached Figure Description

[0048] Figure 1 This is a diagram illustrating the gas storage ratio in the gas injection development reservoir of the present invention.

[0049] Figure 2 This is a diagram showing the gas storage ratio of the X-injection development reservoir according to the present invention. Detailed Implementation

[0050] The technical solutions of the present invention will be clearly and completely described below with reference to the accompanying drawings of the embodiments of the present invention. Obviously, the described embodiments are only some embodiments of the present invention, and not all embodiments. All other embodiments obtained by those skilled in the art based on the embodiments of the present invention without creative effort are within the scope of protection of the present invention.

[0051] It should be noted that the terms “front,” “back,” “left,” “right,” “up,” and “down” used in the following description refer to the directions shown in the attached diagrams, while the terms “inside” and “outside” refer to the 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 commonly understood by one of ordinary skill in the art to which this invention pertains. The terminology used herein in the specification of this invention is for the purpose of describing particular embodiments only and is not intended to be limiting of the invention. The term "and / or" as used herein includes any and all combinations of one or more of the associated listed items.

[0053] The method for judging the gas storage effect of gas injection development reservoirs according to the present invention includes the following process:

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

[0055] The cumulative gas injection volume in the report is in tens of thousands of cubic meters and is the surface volume; for subsequent calculations, it needs to be converted to underground volume, which can be done by multiplying it by the injected gas volume coefficient.

[0056] ΔG inj =G inj *B ginj (1)

[0057] In the formula: ΔG inj The cumulative underground volume of gas injection during the stage is 10,000 cubic meters; G inj B represents the cumulative gas injection volume over the ground, in ten thousand cubic meters. ginj The volume coefficient of the injected gas is dimensionless.

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

[0059] The cumulative gas production in the report is in tens of thousands of cubic meters and is the surface volume; for subsequent calculations, it needs to be converted to underground volume, which can be done by multiplying it by the gas production volume coefficient.

[0060] ΔQ g =G p *B gp (2)

[0061] Where: ΔQ g The cumulative underground gas production volume for each stage is expressed in 10,000 cubic meters; G p B represents the cumulative surface volume of gas production over a given period, in ten thousand cubic meters. gp The volume coefficient of the produced gas is dimensionless.

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

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

[0064]

[0065] In the formula: ΔSR g The gas storage ratio for each stage; ΔG inj The cumulative underground volume of gas injection in each stage; ΔQ g The underground volume representing the cumulative gas production at each stage.

[0066] Substituting the cumulative gas injection volume processed in step 1 and the cumulative gas production volume processed in step 2 into the gas storage ratio definition in step 3, we get:

[0067]

[0068] (4) Calculation of underground volume of cumulative oil production in stages.

[0069] The cumulative oil production in the report 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. This involves dividing the cumulative oil production by the surface crude oil density and then multiplying it by the crude oil volume factor.

[0070]

[0071] Where: ΔQ o The underground volume representing the cumulative oil production over a period of time, N p ρ represents the surface volume of the cumulative oil production over a given period. o B represents the density of crude oil at ground level. oi This is the crude oil volume coefficient.

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

[0073] The cumulative water production in the report is measured in 10,000 tons of mass. For subsequent calculations, the cumulative water production needs to be converted into underground volume measured in 10,000 cubic meters. This involves dividing the cumulative water production by the formation water density and then multiplying it by the formation water volume factor.

[0074]

[0075] Where: ΔQ w W represents the cumulative groundwater production volume over a given period. p ρ represents the cumulative water production per stage of the surface volume. w B is the density of formation water. w This is the formation water volume coefficient.

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

[0077] Cumulative total output ΔQ owg This includes the underground volume of cumulative oil production, cumulative water production, and cumulative gas production, i.e.:

[0078] ΔQ owg =ΔQ o +ΔQ w +ΔQ g (7)

[0079] Where: ΔQ g The underground volume representing the cumulative gas production per stage; ΔQ o The underground volume representing the cumulative oil production per stage; ΔQ w The underground volume represents the cumulative water production during a given period.

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

[0081]

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

[0083] The staged injection-production ratio is defined as the cumulative injection volume per stage divided by the cumulative total production per stage:

[0084]

[0085] Substituting the cumulative gas injection volume and subsurface 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, we get:

[0086]

[0087] Where: N p The cumulative oil production per stage is measured in tons (W). p The water production per unit area is measured in tons per unit area; ρ o B represents the density of crude oil at ground level, in tons per cubic meter. oi ρ is the crude oil volume coefficient, dimensionless; w B represents the density of formation water, in tons per cubic meter. w is the formation water volume coefficient, dimensionless.

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

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

[0090]

[0091] In the formula: GLR is the underground gas-liquid ratio, ΔQ g The underground volume representing the cumulative gas production per stage; ΔQ o The underground volume representing the cumulative oil production per stage; ΔQ w The underground volume represents the cumulative water production during a given period.

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

[0093] Substituting 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 simplifying, we obtain:

[0094]

[0095] In the formula, ΔSR g The gas storage ratio at each stage is ΔZ. inj-p Stage injection-production ratio, GLR is the underground volume gas-liquid ratio.

[0096] Establishment of the theoretical chart of gas storage ratio: Based on the derived calculation expression (12) of the stage gas storage ratio chart, the corresponding stage gas storage ratio 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). For example, when the injection-production ratio is 0.1 and the underground volume gas-liquid ratio is 0.01, the calculated stage gas storage ratio is 0.90099. The other stage gas storage ratios under the same injection-production ratio can be calculated in the same way. The calculation results are shown in Table 1. Connecting the calculated data points will give the corresponding curve under the injection-production ratio. In the same way, the stage gas storage ratios under different injection-production ratios and different gas-liquid ratios are connected to establish the 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) Judgment of gas storage effect.

[0103] Calculate the gas storage ratio for 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 calculations are performed using a specific reservoir example:

[0105] The production data of gas injection development in reservoir X are processed. The crude oil density is 0.86, the crude oil volume factor is 1.071, the formation water density is 1.1, the formation water volume factor is 1, and the injected gas volume factor and the produced gas volume factor are both 0.0035. The detailed calculation process is shown below using the production data of gas injection development in reservoir X in July 2014 as an example (Table 2).

[0106] Step 1: Calculate the monthly underground gas injection volume. Multiply the monthly gas injection volume in the report by the gas injection volume coefficient of 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 monthly gas production volume in the report by the injection gas volume coefficient of 0.0035 to obtain the monthly underground gas production volume 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), subtract the difference between the monthly gas injection underground volume calculated in Step 1 and the monthly gas production underground volume calculated in Step 2, and divide the difference 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. Divide the monthly oil production reported by the crude oil density of 0.86, and then multiply by the crude oil volume coefficient of 1.071 to obtain the monthly underground oil production volume of 143,404,883.7 million cubic meters.

[0110] Step 5: Calculate the monthly groundwater production volume. Divide the monthly water production reported by the formation water density of 1.1, and then multiply by the formation water volume coefficient of 1 to obtain the monthly groundwater production volume of 23,484,545,450 cubic meters.

[0111] Step Six: Calculate the monthly underground volume of liquid production. Add the monthly underground volume of oil production calculated in Step Four to the monthly underground volume of water production calculated in Step Five, and sum them to obtain the monthly underground liquid production of 37,825,033,830 cubic meters.

[0112] Step 7: Calculate the underground volume of gas-liquid ratio: Divide the underground volume of monthly gas production calculated in Step 2 by the underground volume of monthly liquid production calculated in Step 6 to obtain the underground volume of gas-liquid ratio as 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, data for other production months can be calculated, and finally all instance data points are plotted into the gas storage ratio theoretical chart to establish... Figure 2 .Depend on Figure 2 It can be seen that in the early stage of reservoir X (i.e. when the underground 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 relatively large and the gas drive utilization rate of the gas-injected reservoir is relatively high. However, as gas injection proceeds, the gas production increases, the gas storage ratio decreases, and the gas injection utilization rate decreases.

[0115] Table 2

[0116]

[0117]

[0118]

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

[0120] In another embodiment of the present invention, a gas storage effect judgment system for gas injection development reservoirs is provided. This gas storage effect judgment system can be used to implement the above-mentioned gas storage effect judgment method for gas injection development reservoirs. Specifically, the gas storage effect judgment system for gas injection development reservoirs 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 chart establishment module, and a gas storage effect judgment module.

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

[0122] 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. The stage cumulative total production is obtained by adding the stage cumulative oil production underground volume, the stage cumulative water production underground volume and the stage cumulative gas production underground volume.

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

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

[0125] The gas storage ratio chart creation module is used to incorporate the stage injection-production ratio and the underground volume gas-liquid ratio into the stage gas storage ratio calculation, thereby obtaining 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.

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

[0127] In another embodiment of the present invention, a terminal device is provided, comprising a processor and a memory. The memory stores a computer program, which includes program instructions. The processor executes the program instructions stored in the computer storage medium. The processor may be a Central Processing Unit (CPU), or other general-purpose processors, digital signal processors (DSPs), application-specific integrated circuits (ASICs), field-programmable gate arrays (FPGAs), or other programmable logic devices, discrete gate or transistor logic devices, discrete hardware components, etc. It is the computing and control core of the terminal, suitable for implementing one or more instructions, specifically suitable for loading and executing one or more instructions to achieve a corresponding method flow or corresponding function. The processor described in this embodiment can be used in the operation of a method for judging the gas storage effect of gas injection development reservoirs, including: calculating the underground volume of the cumulative gas injection volume and the underground volume of the cumulative gas production volume in a stage, and then calculating the gas storage ratio in the stage; calculating the underground volume of the cumulative oil production volume and the underground volume of the cumulative water production volume in a stage, and then... The cumulative total production for a stage is obtained by adding the underground volume of the lower volume and the underground volume of the cumulative gas production for each stage. The stage injection-production ratio is calculated based on the underground volume of the cumulative gas injection volume and the cumulative total production for each stage. The underground volume gas-liquid ratio is calculated based on 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 for each stage. The stage injection-production ratio and the underground volume gas-liquid ratio are then substituted into the stage gas storage ratio calculation to obtain the gas storage ratio chart. The horizontal axis of the gas storage ratio chart represents the underground volume gas-liquid ratio, and the vertical axis represents the stage gas storage ratio. The stage gas storage ratio for other production cycles is calculated, and the results are added to the gas storage ratio chart. The stage gas storage ratio corresponding to different production cycles is observed to determine the gas storage effect and trend for different production cycles.

[0128] In another embodiment, the present invention also provides a computer-readable storage medium (Memory), which is a memory device in a terminal device for storing programs and data. It is understood that the computer-readable storage medium here may include both the built-in storage medium in the terminal device and extended storage media supported by the terminal device. The computer-readable storage medium provides storage space that stores the terminal's operating system. Furthermore, the storage space also stores one or more instructions suitable for loading and execution by a processor, which may be one or more computer programs (including program code). It should be noted that the computer-readable storage medium here may be high-speed RAM or non-volatile memory, such as at least one disk storage device.

[0129] One or more instructions stored in the computer-readable storage medium can be loaded and executed by the processor to implement the corresponding steps of the gas storage effect judgment method for gas-focused oil reservoirs in the above embodiments; one or more instructions in the computer-readable storage medium are loaded and executed by the processor in the following steps: 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 and the underground volume of the cumulative water production volume in the stage, and adding the underground volumes of the cumulative oil production volume, the cumulative water production volume, and the cumulative gas production volume in the stage to obtain the cumulative total production in the stage. The injection-production ratio for each stage is calculated based on the cumulative underground volume of gas injected and the cumulative total production of each stage. The underground volume gas-liquid ratio is calculated based on the cumulative underground volume of oil produced, water produced, and gas produced. The injection-production ratio and the underground volume gas-liquid ratio are then used to calculate the gas storage ratio for each stage, resulting in a gas storage ratio chart. The horizontal axis of the gas storage ratio chart represents the underground volume gas-liquid ratio, and the vertical axis represents the gas storage ratio for each stage. The gas storage ratio for other production cycles is calculated, and the results are added to the gas storage ratio chart. The gas storage ratio for different production cycles is observed to determine the gas storage effect and trend for different production cycles.

[0130] Those skilled in the art will understand that embodiments of this application can be provided as methods, systems, or computer program products. Therefore, this application can take the form of a completely hardware embodiment, a completely software embodiment, or an embodiment combining software and hardware aspects. Furthermore, this application can take the form of a computer program product embodied on one or more computer-usable storage media (including but not limited to disk storage, CD-ROM, optical storage, etc.) containing computer-usable program code.

[0131] This application is described with reference to flowchart illustrations and / or block diagrams of methods, apparatus (systems), and computer program products according to embodiments of this application. It will be understood that each block of the flowchart illustrations and / or block diagrams, and combinations of blocks in the flowchart illustrations and / or block diagrams, can be implemented by computer program instructions. These computer program instructions can be provided to a processor of a general-purpose computer, special-purpose computer, embedded processor, or other programmable data processing apparatus to produce a machine, such that the instructions, which execute via the processor of the computer or other programmable data processing apparatus, generate instructions for implementing the flowchart... Figure 1 One or more processes and / or boxes Figure 1 A device that provides the functions specified in one or more boxes.

[0132] These computer program instructions may also be stored in a computer-readable storage medium that can direct a computer or other programmable data processing device to function in a particular manner, such that the instructions stored in the computer-readable storage medium produce an article of manufacture including instruction means, which are implemented in a process Figure 1 One or more processes and / or boxes Figure 1 The function specified in one or more boxes.

[0133] These computer program instructions may also be loaded onto a computer or other programmable data processing equipment to cause a series of operational steps to be performed on the computer or other programmable equipment to produce a computer-implemented process, thereby providing instructions that execute on the computer or other programmable equipment for implementing the process. Figure 1 One or more processes and / or boxes Figure 1 The steps of the function specified in one or more boxes.

[0134] It should be noted that, in this document, relational terms such as "first" and "second" are used only to distinguish one entity or operation from another, and do not necessarily require or imply any such actual relationship or order between these entities or operations. Furthermore, the terms "comprising," "including," or any other variations thereof are intended to cover non-exclusive inclusion, such that a process, method, article, or apparatus that comprises a list of elements includes not only those elements but also other elements not expressly listed, or elements inherent to such process, method, article, or apparatus.

[0135] It should be understood that the above description is for illustrative purposes and not for limitation. Many embodiments and applications beyond the provided examples will be apparent to those skilled in the art upon reading the above description. Therefore, the scope of this teaching should not be determined by reference to the above description, but rather by reference to the foregoing claims and the full scope of their equivalents. For purposes of completeness, all articles and references, including 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 as a waiver of that subject matter, nor should it be construed as an indication that the applicant has not considered that subject matter as part of the disclosed inventive subject matter.

Claims

1. A method for judging the gas storage effect in gas injection development reservoirs, characterized in that, Includes the following processes: The underground volume of cumulative gas injection and cumulative gas production in each stage are calculated, and then the gas storage ratio in each stage is calculated. The underground volumes of cumulative oil production and cumulative water production for each stage are calculated. The total cumulative production for each stage is obtained by adding the underground volumes of cumulative oil production, cumulative water production, and cumulative gas production for each stage. The stage injection-production ratio is calculated based on the stage cumulative gas injection volume, underground volume, and stage cumulative total production. The underground volume gas-liquid ratio is calculated based on the underground volume of cumulative oil production, cumulative water production, and cumulative gas production. Substituting the stage injection-production ratio and the underground volume gas-liquid ratio into the stage gas storage ratio calculation, we obtain: In the formula, The gas storage ratio for each stage, Phase injection-production ratio, The underground volumetric gas-liquid ratio; Calculate the corresponding gas storage ratio for a given stage when the injection-production ratio and underground volume gas-liquid ratio take different values. By connecting the calculated data points, the corresponding curve under the injection-production ratio can be obtained. In the same way, the gas storage ratio of different stages of injection-production ratio and different underground volume gas-liquid ratio can be connected to establish a theoretical chart of gas storage ratio. The horizontal axis is the underground volume gas-liquid ratio, and the vertical axis is the stage gas storage ratio. This leads to the gas storage ratio chart, where the horizontal axis represents the underground volume gas-liquid ratio and the vertical axis represents the stage gas storage ratio. Calculate the gas storage ratio for other production cycles and add the results to the gas storage ratio chart. Observe the gas storage ratio for different production cycles and judge the gas storage effect and trend for different production cycles. Calculate the gas storage ratio and gas-liquid ratio of the actual gas-injected reservoir. Plot the actual gas injection data into the theoretical gas storage ratio chart to determine the size of the gas storage ratio. Furthermore, based on the changing trends of the gas storage ratio and gas-liquid ratio data points, the changes in the amount of gas produced can be further determined, thereby judging the changes in the gas storage ratio and the gas storage effect.

2. The method for judging the gas storage effect of gas injection development reservoirs according to claim 1, characterized in that, The underground volume of the staged cumulative gas injection is obtained by multiplying the surface volume of the staged cumulative gas injection by the injected gas volume factor: In the formula: The cumulative underground volume of gas injection in each stage; The cumulative gas injection volume per stage is the ground volume. The injection gas volume coefficient; The cumulative underground gas production volume is obtained by multiplying the cumulative surface gas production volume by the produced gas volume factor. In the formula: The underground volume representing the cumulative gas production at each stage; The cumulative gas production per stage is the surface volume. This is the output gas volume coefficient.

3. The method for judging the gas storage effect of gas injection development reservoirs according to claim 1, characterized in that, The stage gas storage ratio is obtained by dividing the difference between the stage cumulative gas injection volume and the stage cumulative gas production volume of the underground area by the stage cumulative gas injection volume of the underground area. In the formula: This refers to the gas storage ratio at each stage; The cumulative underground volume of gas injection in each stage; The underground volume representing the cumulative gas production at each stage.

4. The method for judging the gas storage effect of gas injection development reservoirs according to claim 1, characterized in that, The underground volume of cumulative oil production per stage is obtained by dividing the cumulative oil production per stage by the surface crude oil density and then multiplying by the crude oil volume factor. In the formula: The underground volume representing the cumulative oil production over a period of time. The cumulative oil production per stage is the surface volume. For ground crude oil density, This is the crude oil volume coefficient; The cumulative water production per stage and the groundwater volume are obtained by dividing the cumulative water production per stage by the formation water density and then multiplying by the formation water volume factor. In the formula: The cumulative underground water production volume at each stage The cumulative water production per stage is the surface volume. The density of the formation water, This is the formation water volume coefficient.

5. The method for judging the gas storage effect of gas injection development reservoirs according to claim 1, characterized in that, The staged injection-production ratio is calculated by dividing the cumulative injection volume per stage by the cumulative total production per stage. In the formula: The underground volume representing the cumulative gas production at each stage; The underground volume representing the cumulative oil production at each stage; The cumulative underground water production volume at each stage; This represents the cumulative total output for a given period.

6. The method for judging the gas storage effect of gas injection development reservoirs according to claim 1, characterized in that, The underground gas-liquid ratio is calculated by dividing the underground volume of cumulative gas production by the underground volume of cumulative liquid production. The underground volume of cumulative liquid production is the sum of the underground volumes of cumulative oil production and cumulative water production. In the formula: The underground volume gas-liquid ratio, The underground volume representing the cumulative gas production at each stage; The underground volume representing the cumulative oil production at each stage; The underground volume represents the cumulative water production during a given period.

7. A system for judging the gas storage effect in gas injection development 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 volume and the underground volume of the stage cumulative gas production volume, and then calculate the stage gas storage ratio. The phase cumulative total production calculation module is used to calculate the phase cumulative oil production underground volume and the phase cumulative water production underground volume. The phase cumulative total production is obtained by adding the phase cumulative oil production underground volume, the phase cumulative water production underground volume and the phase cumulative gas production underground volume. The stage injection-production ratio calculation module is used to calculate the stage injection-production ratio based on the stage cumulative gas injection volume, underground volume, and stage cumulative total production. The underground volume gas-liquid ratio calculation module is used to calculate the underground volume gas-liquid ratio based on the underground volume of cumulative oil production, underground volume of cumulative water production, and underground volume of cumulative gas production. The gas storage ratio chart creation module is used to incorporate the stage injection-production ratio and the underground volume gas-liquid ratio into the stage gas storage ratio calculation, resulting in: In the formula, The gas storage ratio for each stage, Phase injection-production ratio, The underground volumetric gas-liquid ratio; Calculate the corresponding gas storage ratio for a given stage when the injection-production ratio and underground volume gas-liquid ratio take different values. By connecting the calculated data points, the corresponding curve under the injection-production ratio can be obtained. In the same way, the gas storage ratio of different stages of injection-production ratio and different underground volume gas-liquid ratio can be connected to establish a theoretical chart of gas storage ratio. The horizontal axis is the underground volume gas-liquid ratio, and the vertical axis is the stage gas storage ratio. This leads to the gas storage ratio chart, where the horizontal axis represents the underground volume gas-liquid ratio and the vertical axis represents the stage gas storage ratio. 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 to observe the gas storage ratio of different production cycles and judge the gas storage effect and trend of different production cycles. Calculate the gas storage ratio and gas-liquid ratio of the actual gas-injected reservoir. Plot the actual gas injection data into the theoretical gas storage ratio chart to determine the size of the gas storage ratio. Furthermore, based on the changing trends of the gas storage ratio and gas-liquid ratio data points, the changes in the amount of gas produced can be further determined, thereby judging the changes in the gas storage ratio and the gas storage effect.

8. A computer device comprising a memory, a processor, and a computer program stored in the memory and executable on the processor, characterized in that, When the processor executes the computer program, it implements the steps of the gas injection development reservoir gas storage effect judgment method as described in any one of claims 1 to 6.

9. A computer-readable storage medium storing a computer program, characterized in that, When the computer program is executed by the processor, it implements the steps of the gas injection development reservoir gas storage effect judgment method as described in any one of claims 1 to 6.

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