Method for evaluating operation opportunity of deep medium-high condensate oil condensate gas reservoir to gas storage

Abstract

The invention discloses a method for evaluating the operation opportunity of converting a deep medium-high condensate oil condensate gas reservoir into a gas storage. The method comprises the following steps: establishing a three-dimensional geologic model based on a pre-obtained analysis result of development geology and dynamic evaluation of the condensate gas reservoir and a plurality of modeling static parameters; adjusting the control parameters through the pre-determined fitting fluid parameters of the fluid sample, and establishing an oil and gas reservoir numerical simulation model based on the plurality of simulation parameters; performing development dynamic simulation calculation on the three-dimensional geologic model according to the oil and gas reservoir numerical simulation model to obtain development dynamic fitting data, comparing the development dynamic fitting data with corresponding historical development dynamic actual data, and adjusting the three-dimensional geologic model; and based on the adjusted three-dimensional geological model and the oil and gas reservoir numerical simulation model, carrying out gas injection scheme numerical simulation calculation at different gas injection opportunities, and determining corresponding development index prediction results, thereby determining gas injection schemes at different gas injection opportunities, carrying out optimal evaluation, and determining a condensate gas reservoir-to-building gas storage operation scheme with the highest comprehensive value.

Description

Technical Field

[0001] The present application relates to a method for evaluating the operation timing of a gas storage reservoir in a deep medium-high condensate oil-containing condensate gas reservoir. Background Art

[0002] The demand for natural gas in the national consumer market fluctuates day and night and seasonally, and the natural gas supply mode of immediate production and transmission is unbalanced with the market gas consumption. Therefore, the construction of natural gas storage facilities can regulate the supply and demand relationship of natural gas and improve the safety and reliability of the natural gas transmission and distribution system. The construction of gas storage using depleted oil and gas reservoirs has the advantages of rich basic data, low investment cost and low subsequent maintenance cost. It is the best type of underground gas storage from an economic perspective. At present, the construction of gas storage in conventional oil and gas reservoirs in China is mainly of this type.

[0003] There have been some successful examples of building gas storage in conventional oil and gas reservoirs in China, but the transformation of medium-high condensate oil-condensate gas reservoirs into gas storage is still in the exploratory stage, and there are very few mature technologies that can be used for reference. Compared with conventional oil and gas reservoirs, medium-high condensate oil-condensate gas reservoirs have complex fluid phase change laws and seepage characteristics, and the choice of development methods has a decisive influence on the efficient development of such gas reservoirs. The gas-oil ratio of the formation fluid of medium-high condensate oil-condensate gas reservoirs is generally not less than 600-800 cubic meters / cubic meters, the oil and gas system is rich in intermediate hydrocarbon components, and the dew point pressure is relatively high; when the medium-high condensate oil-condensate gas reservoir is exhausted for a period of time, the formation pressure drops to the dew point pressure, and severe retrograde condensation will occur, especially in the near-well area where there is a pressure drop funnel. The large amount of condensate oil precipitated will increase the seepage resistance and seriously pollute the formation near the wellbore, causing the production capacity of the production well to be greatly reduced or even difficult to produce normally. In addition, for condensate gas reservoirs with edge and bottom water, the invasion of edge and bottom water into the formation after the pressure is reduced will also seriously damage the reservoir, causing the gas flow capacity to be further reduced. Therefore, for the efficient development of deep medium-high condensate gas reservoirs, it is often necessary to circulate dry gas to maintain pressure development. Circulating dry gas injection can well maintain formation pressure and inhibit the invasion of edge and bottom water, so as to improve the ultimate recovery rate of condensate oil and gas. Summary of the invention

[0004] In order to better realize the operation timing evaluation of a gas storage reservoir for a deep medium-high condensate oil-condensate gas reservoir, an embodiment of the present application provides an operation timing evaluation method for a gas storage reservoir for a deep medium-high condensate oil-condensate gas reservoir.

[0005] In a first aspect, an embodiment of the present application provides a method for evaluating the operation timing of a gas storage reservoir for a deep medium-high condensate oil condensate gas reservoir, the method comprising:

[0006] A three-dimensional geological model is established based on the previously obtained analysis results of the development geological evaluation and development dynamic evaluation of the condensate gas reservoir and multiple modeling static parameters;

[0007] adjusting the control parameter by fitting the fluid parameter of the predetermined fluid sample, and establishing a numerical simulation model of the oil and gas reservoir based on the control parameter and a plurality of predetermined simulation parameters;

[0008] Performing development dynamic simulation calculation on the three-dimensional geological model according to the oil and gas reservoir numerical simulation model to obtain development dynamic fitting data;

[0009] According to the comparison result between the development dynamic fitting data and the corresponding historical development dynamic actual data, the three-dimensional geological model is adjusted to obtain an adjusted three-dimensional geological model;

[0010] Based on the adjusted three-dimensional geological model and the oil and gas reservoir numerical simulation model, numerical simulation calculations of gas injection schemes at different gas injection times are carried out to determine corresponding prediction results of condensate gas reservoir development indicators;

[0011] According to the prediction results of the development index of condensate gas reservoirs corresponding to each gas injection opportunity, the operation plan of converting condensate gas reservoirs into gas storage at each gas injection opportunity is determined;

[0012] An optimal evaluation is performed based on the condensate gas reservoir-to-gas storage operation plans at each gas injection opportunity to determine the condensate gas reservoir-to-gas storage operation plan with the highest comprehensive value.

[0013] In an optional implementation of the embodiment of the present application, the three-dimensional geological model is established based on the analysis results of the development geological evaluation and development dynamic evaluation of the condensate gas reservoir obtained in advance and multiple modeling static parameters, including:

[0014] Grid division is performed based on the previously obtained reservoir characteristics of the condensate gas reservoir to determine the basic data for modeling;

[0015] Carry out reservoir structure modeling based on the pre-acquired digital data of the structural map and breakpoint data;

[0016] Reservoir attribute modeling is performed based on the previously acquired single well scattered sedimentary facies data;

[0017] Based on the analysis results of the development geological evaluation and development dynamic evaluation of the condensate gas reservoir obtained in advance, a three-dimensional geological model is established according to the basic modeling data, reservoir structure modeling and reservoir attribute modeling.

[0018] In an optional implementation manner of the embodiment of the present application, after establishing the three-dimensional geological model, the method further includes:

[0019] The reserves obtained according to the three-dimensional geological model are compared with the historical reserve results obtained in advance to verify the three-dimensional geological model.

[0020] In an optional implementation of the embodiment of the present application, the three-dimensional geological model is subjected to development dynamic simulation calculation according to the oil and gas reservoir numerical simulation model to obtain development dynamic fitting data, including:

[0021] Performing simulation calculation on the oil and gas geological reserves according to the oil and gas reservoir numerical simulation model to obtain the oil and gas geological reserves fitting value;

[0022] Performing simulation calculation on the oil and gas reservoir pressure according to the oil and gas reservoir numerical simulation model to obtain the oil and gas reservoir pressure fitting value;

[0023] The gas well production performance is simulated and calculated according to the oil and gas reservoir numerical simulation model to obtain a gas well production performance fitting curve.

[0024] In an optional implementation of the embodiment of the present application, the operation plan for converting the condensate gas reservoir into a gas storage reservoir at each gas injection opportunity is determined according to the prediction results of the condensate gas reservoir development index at each gas injection opportunity, including:

[0025] According to the prediction results of the development index of the condensate gas reservoir at each gas injection opportunity, based on the numerical simulation model of the oil and gas reservoir, a numerical simulation model for converting the condensate gas reservoir into a gas storage reservoir at each gas injection opportunity is established;

[0026] According to the numerical simulation model of converting the condensate gas reservoir into a gas storage reservoir at each gas injection opportunity, an operation plan for converting the condensate gas reservoir into a gas storage reservoir at each gas injection opportunity is determined.

[0027] In an optional implementation of the embodiment of the present application, the optimal evaluation of the condensate gas reservoir conversion gas storage operation plan according to each gas injection opportunity to determine the condensate gas reservoir conversion gas storage operation plan with the highest comprehensive value includes:

[0028] According to the condensate gas reservoir conversion gas storage operation plan at each gas injection opportunity, determining the prediction result of the gas storage operation dynamic index at each gas injection opportunity;

[0029] Determine several optimal gas storage conversion operation plans based on the prediction results of the gas storage operation dynamic indicators at each gas injection opportunity;

[0030] According to the calculated total profits of several optimal condensate gas reservoir conversion gas storage operation plans, the condensate gas reservoir conversion gas storage operation plan with the highest comprehensive value is determined.

[0031] In a second aspect, an embodiment of the present application provides a device for evaluating the operation timing of a gas storage reservoir for a deep medium-high condensate oil condensate gas reservoir, the device comprising:

[0032] The first modeling module is used to establish a three-dimensional geological model based on the analysis results of the development geological evaluation and development dynamic evaluation of the condensate gas reservoir obtained in advance and a plurality of modeling static parameters;

[0033] a second modeling module, for adjusting the control parameter by fitting the fluid parameter of the predetermined fluid sample, and establishing a numerical simulation model of the oil and gas reservoir based on the control parameter and a plurality of predetermined simulation parameters;

[0034] A first determination module is used to perform development dynamic simulation calculation on the three-dimensional geological model according to the oil and gas reservoir numerical simulation model to obtain development dynamic fitting data;

[0035] A model adjustment module, used to adjust the three-dimensional geological model according to the comparison result between the development dynamic fitting data and the corresponding historical development dynamic actual data, so as to obtain an adjusted three-dimensional geological model;

[0036] The second determination module is used to carry out numerical simulation calculations of gas injection schemes at different gas injection times based on the adjusted three-dimensional geological model and the oil and gas reservoir numerical simulation model, and determine the corresponding prediction results of condensate gas reservoir development indicators;

[0037] The third determination module is used to determine the operation plan of converting the condensate gas reservoir into a gas storage reservoir at each gas injection opportunity according to the prediction results of the condensate gas reservoir development indicators corresponding to each gas injection opportunity;

[0038] The fourth determination module is used to perform optimal evaluation on the condensate gas reservoir conversion gas storage operation plan at each gas injection opportunity, and determine the condensate gas reservoir conversion gas storage operation plan with the highest comprehensive value.

[0039] In a third aspect, an embodiment of the present application provides a computer-readable storage medium having a computer program stored thereon, which, when executed by a processor, implements the above-mentioned timing evaluation method for operating a gas storage reservoir for a deep medium-high condensate oil content condensate gas reservoir.

[0040] In a fourth aspect, an embodiment of the present application provides a computer device, including a memory, a processor, and a computer program stored in the memory and executable on the processor, wherein when the processor executes the computer program, the method for evaluating the operating timing of a gas storage reservoir for a deep medium-high condensate oil content condensate gas reservoir is implemented as described above.

[0041] In a fifth aspect, an embodiment of the present application provides a computer program product comprising instructions, which, when executed on a computer device, enables the computer device to execute the above-mentioned method for evaluating the timing of operation of a gas storage reservoir for a deep medium-high condensate oil content condensate gas reservoir.

[0042] In a sixth aspect, an embodiment of the present application provides a chip, the chip comprising a processor and a communication interface, the communication interface and the processor are coupled, and the processor is used to run a computer program or instruction to implement the above-mentioned method for evaluating the timing of operation of a gas storage reservoir for a deep medium-high condensate oil content condensate gas reservoir.

[0043] The beneficial effects of the above technical solution provided by the embodiment of the present application include at least:

[0044] The method for evaluating the timing of converting a deep medium-high condensate oil-containing condensate gas reservoir into a gas storage reservoir provided in the embodiment of the present application establishes a three-dimensional geological model and a numerical simulation model, simulates and calculates the prediction results of development indicators at different gas injection times, and thus designs the operation schemes for converting a condensate gas reservoir into a gas storage reservoir at different gas injection times, and determines the scheme with the highest comprehensive value according to the prediction results of the gas storage reservoir operation dynamic indicators and the total profit corresponding to different schemes. The method can reasonably select the timing of converting a deep medium-high condensate oil-containing condensate gas reservoir into a gas storage reservoir, which is conducive to the efficient operation of the gas storage reservoir, and can convert the gas storage reservoir when the condensate gas reservoir has not produced a large amount of condensate oil and the edge and bottom water has not obviously invaded the formation, which can effectively improve the operation efficiency of the gas storage reservoir, and at the same time can effectively increase the recovery rate of condensate oil, reduce the operation cost of the gas storage reservoir, and improve the economic benefits.

[0045] Other features and advantages of the present application will be described in the following description, and partly become apparent from the description, or be understood by practicing the present application. The purpose and other advantages of the present application can be realized and obtained by the structures specifically pointed out in the written description, claims, and drawings.

[0046] The technical solution of the present application is further described in detail below through the accompanying drawings and embodiments. BRIEF DESCRIPTION OF THE DRAWINGS

[0047] The accompanying drawings are used to provide a further understanding of the present application and constitute a part of the specification. Together with the embodiments of the present application, they are used to explain the present application and do not constitute a limitation of the present application. In the accompanying drawings:

[0048] Figure 1 A schematic diagram of the steps of a method for evaluating the timing of operation of a gas storage reservoir for a deep medium-high condensate oil condensate gas reservoir provided in an embodiment of the present application;

[0049] Figure 2 A schematic diagram of a process for evaluating the timing of operation of a gas storage reservoir for a deep medium-high condensate oil condensate gas reservoir provided in an embodiment of the present application;

[0050] Figure 3 This is a schematic diagram of the structure of a timing evaluation device for a deep medium-high condensate oil-containing condensate gas reservoir during operation of a storage gas reservoir provided in an embodiment of the present application. DETAILED DESCRIPTION

[0051] In the following description, specific details such as specific system structures, technologies, etc. are provided for the purpose of illustration rather than limitation, so as to provide a thorough understanding of the embodiments of the present application. However, it should be clear to those skilled in the art that the present application may also be implemented in other embodiments without these specific details. In other cases, detailed descriptions of well-known systems, devices, circuits, and methods are omitted to prevent unnecessary details from obstructing the description of the present application.

[0052] It should be understood that when used in the present specification and the appended claims, the term "comprising" indicates the presence of described features, wholes, steps, operations, elements and / or components, but does not exclude the presence or addition of one or more other features, wholes, steps, operations, elements, components and / or combinations thereof.

[0053] It should also be understood that the term “and / or” used in the specification and appended claims refers to any and all possible combinations of one or more of the associated listed items, and includes these combinations.

[0054] As used in the specification and appended claims of this application, the term "if" can be interpreted as "when" or "uponce" or "in response to determining" or "in response to detecting", depending on the context. Similarly, the phrase "if it is determined" or "if [described condition or event] is detected" can be interpreted as meaning "uponce it is determined" or "in response to determining" or "uponce [described condition or event] is detected" or "in response to detecting [described condition or event]", depending on the context.

[0055] In addition, in the description of the present application specification and the appended claims, the terms "first", "second", "third", etc. are only used to distinguish the descriptions and cannot be understood as indicating or implying relative importance.

[0056] References to "one embodiment" or "some embodiments" etc. described in the specification of this application mean that one or more embodiments of the present application include specific features, structures or characteristics described in conjunction with the embodiment. Therefore, the statements "in one embodiment", "in some embodiments", "in some other embodiments", "in some other embodiments", etc. that appear in different places in this specification do not necessarily refer to the same embodiment, but mean "one or more but not all embodiments", unless otherwise specifically emphasized in other ways. The terms "including", "comprising", "having" and their variations all mean "including but not limited to", unless otherwise specifically emphasized in other ways.

[0057] It should be understood that the size of the serial numbers of the steps in the following embodiments does not mean the order of execution. The execution order of each process should be determined by its function and internal logic, and should not constitute any limitation on the implementation process of the embodiments of the present application.

[0058] In order to illustrate the technical solution of the present application, a specific embodiment is provided below for illustration.

[0059] The inventors have found that in the prior art, it is crucial to reasonably select the timing of converting a deep medium-high condensate oil-containing condensate gas reservoir into a gas storage facility for the efficient operation of the gas storage facility. If the gas storage facility is converted too early, the condensate gas reservoir will not be sufficiently developed, the gas storage facility operation cost will be high, and the economic benefits will be low. However, when the condensate gas reservoir does not produce a large amount of condensate oil and the edge and bottom water does not obviously invade the formation, the gas storage facility can be converted, which can effectively improve the operation efficiency of the gas storage facility and effectively increase the recovery rate of the condensate oil. However, there is currently no evaluation method for the operation timing of converting a deep medium-high condensate oil-containing condensate gas reservoir into a gas storage facility. Based on this, the inventors have made this application after further research and development, providing a method for evaluating the operation timing of converting a deep medium-high condensate oil-containing condensate gas reservoir into a gas storage facility.

[0060] Embodiment 1

[0061] The present application embodiment provides a method for evaluating the operation timing of a gas storage reservoir for a deep medium-high condensate oil condensate gas reservoir, referring to Figure 1 As shown, the method includes:

[0062] S101: Building a three-dimensional geological model based on the previously obtained analysis results of the development geological evaluation and development dynamic evaluation of the condensate gas reservoir and a plurality of modeling static parameters.

[0063] The inventors found that currently, China usually chooses exhausted oil and gas reservoirs that have reached the limit of economic development value for gas storage reconstruction, and the timing of conversion to gas storage is basically in the late stage of oil and gas reservoir development. Compared with the current common exhausted oil and gas reservoir gas storage type, deep medium-high condensate oil condensate gas reservoir conversion gas storage operation has the following advantages:

[0064] 1. Good airtightness and stable storage capacity;

[0065] 2. Injecting dry gas can effectively maintain formation pressure;

[0066] 3. Continuously increase the dryness of condensate gas in the gas reservoir, reduce the dew point pressure, inhibit the precipitation of condensate oil, and improve the condensate oil recovery rate while the gas storage is in operation, killing two birds with one stone;

[0067] 4. It can effectively inhibit the intrusion of edge and bottom water.

[0068] For deep medium-high condensate oil and condensate gas reservoirs, if the mid-to-late stage gas storage operation is considered, a large amount of condensate oil accumulated in the formation is difficult to produce due to the low formation pressure. In addition, a considerable amount of edge and bottom water invades the formation under the pressure difference, and the oil, gas and water flow resistance is huge. The operation of gas storage for deep medium-high condensate oil and condensate gas reservoirs with gas injection at different times has the following advantages and disadvantages:

[0069] 1. Early gas injection

[0070] Advantages: Keeping the formation pressure above the dew point can effectively suppress the intrusion of edge and bottom water, no need for gas padding, high single well working efficiency during operation, and high final recovery rate of condensate oil;

[0071] Disadvantages: high gas injection pressure, high compressor operating cost, narrow operating pressure range of gas storage, small working gas volume, and large investment.

[0072] 2. Late gas injection

[0073] Advantages: low gas injection pressure, low compressor operating cost, wide operating pressure range of gas storage, large working gas volume, and relatively low investment;

[0074] Disadvantages: low formation pressure, large amount of condensate oil precipitation, edge and bottom water intrusion, large flow resistance of multiphase fluid in the formation, large amount of cushion gas is required, and the final recovery rate of condensate oil is not high.

[0075] 3. Mid-term gas injection

[0076] The advantages and disadvantages are between early and late gas injection.

[0077] Therefore, it is crucial to the efficient operation of the gas storage to reasonably choose the time to convert the deep medium-high condensate oil-containing condensate gas reservoir into a gas storage. When the condensate gas reservoir does not produce a large amount of condensate oil and the edge and bottom water does not obviously invade the formation, the gas storage conversion can effectively improve the operation efficiency of the gas storage and effectively increase the recovery rate of condensate oil. However, if the gas storage is converted too early, the condensate gas reservoir will not be developed to a sufficient extent, the operation cost of the gas storage will be high, and the economic benefits will be low.

[0078] In the embodiment of the present application, before evaluating the timing of converting the condensate gas reservoir into a gas storage reservoir, it is necessary to first conduct a condensate gas reservoir geological evaluation and development evaluation on the target block to evaluate the feasibility of converting the deep medium-high condensate oil condensate gas reservoir in the target block into a gas storage reservoir. Among them, the gas reservoir development geological evaluation includes gas reservoir structure, reservoir, reservoir space, fluid saturation, fluid physical properties, formation pressure and temperature, condensate oil geological reserves, natural gas geological reserves, water body energy, etc.; gas reservoir development dynamic evaluation includes gas well testing, test production, pressure distribution, dynamic reserves, fluid phase state, condensate oil, gas, water production, water invasion dynamics, etc.

[0079] The specific process of geological evaluation for gas reservoir development is as follows:

[0080] 1.1: Regional geological evaluation. Evaluate the geographical location of the gas reservoir from the perspective of transportation, water source convenience, and economic conditions related to gas field development; evaluate the regional geological structure of the gas reservoir from the perspective of trap formation period, tectonic unit, sedimentary basin, stratigraphic sequence, and source-reservoir-cap combination through regional geological structure maps, stratigraphic tables, and comprehensive columnar profiles; and evaluate the feasibility of condensate gas reservoirs to gas storage reservoirs from the perspective of geological structure.

[0081] 1.2: Evaluation of gas reservoir structure. Evaluate the structural morphology of the gas reservoir from the type and size of the trap; determine the location of the gas reservoir in the trap through the gas reservoir structural plan and longitudinal and transverse profiles; determine the distribution of faults and fractures through fault and fracture data to provide a basis for geological modeling of the gas storage reservoir.

[0082] 1.3: Reservoir evaluation. Divide the strata into groups by referring to the division basis through the sequence comparison table; understand the reservoir lithology through lithology analysis experiments; judge the continuity of gas reservoir distribution through the gas-bearing area and effective thickness of the gas reservoir; analyze the development of interlayers through the interlayer plane distribution map, select the layers with perfect interlayer development as the preferred layers, and clarify the potential layers of gas storage.

[0083] 1.4: Reservoir space evaluation. This includes evaluating reservoir types and basic reservoir physical parameters; evaluating reservoir space and reservoir structure by analyzing pore and vug distribution and pore structure; and evaluating reservoir space physical parameters and reservoir types through core porosity and permeability measurement experiments and logging results analysis.

[0084] 1.5: Fluid saturation and fluid physical property evaluation. Through fluid sample testing experiments, determine the chemical composition and high-pressure physical property parameters of oil, gas and water.

[0085] 1.6: Formation pressure and temperature evaluation. Through formation temperature test and formation pressure test, draw the relationship curve between formation pressure, temperature and depth, and evaluate the formation pressure and temperature characteristics.

[0086] 1.7: Evaluation of condensate oil and natural gas geological reserves. Based on parameters such as porosity, saturation, reservoir thickness, and distribution area, the static condensate oil and natural gas geological reserves are calculated by volumetric method.

[0087] 1.8: Water body energy evaluation: Evaluate the static water body energy through reservoir formation, structural geology and fluid distribution characteristics.

[0088] The specific process of dynamic evaluation of gas reservoir development is as follows:

[0089] 2.1: Use multi-well test pressure measurement data to obtain pressure parameters, the connectivity between wells, within the gas reservoir, and between layers, and divide the gas reservoir pressure system.

[0090] 2.2: Perform binomial production capacity analysis through the back pressure test data table to determine the gas well production capacity, and obtain specific formation parameters by processing the well test data.

[0091] 2.3: Monitor the changes in pressure, condensate oil, gas, water production, oil-gas ratio and water-gas ratio of the test production wells.

[0092] 2.4: Based on dynamic production parameters, verify the dynamic reserves of gas reservoirs and analyze the water invasion dynamics of each well.

[0093] 2.5: Conduct fluid phase evaluation based on the well flow of condensate gas reservoirs.

[0094] Through the above-mentioned gas reservoir development geological evaluation and gas reservoir development dynamic evaluation process, the analysis results of gas reservoir development geological evaluation and gas reservoir development dynamic evaluation are obtained, the feasibility of gas storage conversion is analyzed, and on this basis, a three-dimensional geological model of the target block is established.

[0095] In the above step S101, the three-dimensional geological model is established based on the analysis results of the development geological evaluation and development dynamic evaluation of the condensate gas reservoir obtained in advance and multiple modeling static parameters, specifically including:

[0096] Grid division is performed based on the previously obtained reservoir characteristics of the condensate gas reservoir to determine the basic data for modeling;

[0097] Carry out reservoir structure modeling based on the pre-acquired digital data of the structural map and breakpoint data;

[0098] Reservoir attribute modeling is performed based on the previously acquired single well scattered sedimentary facies data;

[0099] Based on the analysis results of the development geological evaluation and development dynamic evaluation of the condensate gas reservoir obtained in advance, a three-dimensional geological model is established according to the basic modeling data, reservoir structure modeling and reservoir attribute modeling.

[0100] In the embodiment of the present application, a three-dimensional geological model is established from the aspects of reservoir structure and reservoir properties. The modeling units are divided according to the characteristics of the gas reservoir reservoir, and the grid division is performed considering the modeling scale and accuracy to prepare the basic data for modeling; a fault model is established based on the digital data of the structural map and the breakpoint data, and a layer model is established on the basis of the fault distribution and the well point stratification data to complete the reservoir structure modeling; based on the sedimentary phase data of the scattered points of a single well, a sedimentary microfacies model is established by interpolation with the plane distribution and vertical distribution law of the sedimentary microfacies as constraints, and a porosity model and a permeability model are established by using the phase-controlled secondary control modeling method to complete the reservoir property modeling, thereby obtaining a three-dimensional geological model of the target block. Among them, the multiple modeling static parameters required for modeling can be obtained through experiments or actual research. The specific implementation method can refer to the detailed description in the prior art and is not specifically limited here.

[0101] In the embodiment of the present application, after the three-dimensional geological model is established, the following steps are further included:

[0102] The reserves obtained according to the three-dimensional geological model are compared with the historical reserve results obtained in advance to verify the three-dimensional geological model.

[0103] In the embodiment of the present application, after the three-dimensional geological model is established, the three-dimensional geological model needs to be initially verified to verify the reliability of the model. The original condensate oil reserves, original condensate gas reserves and original dry gas reserves of the condensate gas reservoir of the target block are calculated by volumetric method to obtain historical reserve results, and the historical reserve results are compared with the target block reserves calculated by the established three-dimensional geological model to initially verify the reliability of the model and complete the model block reserve fitting.

[0104] S102: adjusting control parameters by fitting fluid parameters of predetermined fluid samples, and establishing a numerical simulation model of an oil and gas reservoir based on the control parameters and a plurality of predetermined simulation parameters.

[0105] In the embodiment of the present application, a fluid sample of the target block is obtained, and the fluid sample components are split within the allowable error range of the phase diagram before and after the sample splitting to improve the fitting accuracy of the fluid parameters. The real fluid characteristic parameters are obtained through laboratory component expansion experiments, constant volume exhaustion experiments, and differential separation experiments. The control parameters of the EOS state parameter equation are adjusted based on the original test point distribution, so that the simulation experiment fitting value, i.e., the fitting fluid parameter, and the fluid parameter result obtained by the laboratory experiment tend to be consistent within the accuracy requirements.

[0106] Before establishing a numerical simulation model, if the three-dimensional geological model is large and the simulation operation rate is slow, the three-dimensional geological model can be meshed to meet the simulation operation rate. In the three-dimensional geological model, the basic parameters of oil and gas field development are imported, including oil-water (gas) relative permeability curve, reservoir parameters (original formation pressure, original formation temperature, saturation pressure, formation crude oil density, crude oil compression coefficient, degassed crude oil density, component volume coefficient, etc.), gas well production data (single well daily oil / gas / water production, well pressure, etc.) and other required simulation parameters to establish a numerical simulation model of oil and gas reservoirs.

[0107] S103: Performing development dynamic simulation calculation on the three-dimensional geological model according to the oil and gas reservoir numerical simulation model to obtain development dynamic fitting data.

[0108] In the above step S103, the three-dimensional geological model is subjected to development dynamic simulation calculation according to the oil and gas reservoir numerical simulation model to obtain development dynamic fitting data, which specifically includes:

[0109] The oil and gas geological reserves are simulated and calculated according to the oil and gas reservoir numerical simulation model to obtain the oil and gas geological reserves fitting value;

[0110] Performing simulation calculation on the oil and gas reservoir pressure according to the oil and gas reservoir numerical simulation model to obtain the oil and gas reservoir pressure fitting value;

[0111] The gas well production performance is simulated and calculated according to the oil and gas reservoir numerical simulation model to obtain a gas well production performance fitting curve.

[0112] In the embodiment of the present application, after establishing the three-dimensional geological model and the oil and gas reservoir numerical simulation model, the parameters of the three-dimensional geological model are adjusted until the fitted development dynamic data and the historical development dynamic real data are consistent by comparing the development dynamic data fitted by the oil and gas reservoir numerical simulation model. The fitted development dynamic data include oil and gas geological reserves, oil and gas reservoir pressure and gas well production performance.

[0113] S104: adjusting the three-dimensional geological model according to the comparison result between the development dynamics fitting data and the corresponding historical development dynamics actual data to obtain an adjusted three-dimensional geological model.

[0114] In the embodiment of the present application, after the numerical simulation model is used to simulate and calculate the oil and gas geological reserve fitting value, the oil and gas reservoir pressure fitting value and the gas well production dynamic fitting curve, the oil and gas geological reserve fitting value is compared with the actual oil and gas geological reserve data calculated by the volumetric method, and the three-dimensional geological model parameters are adjusted until the oil and gas geological reserve fitting value and the actual oil and gas geological reserve data tend to coincide within the simulation accuracy requirement range; the oil and gas reservoir pressure fitting value is compared with the actual data of the overall pressure of the oil and gas reservoir obtained by averaging the data points of the limited pressure measuring wells, and the three-dimensional geological model parameters are adjusted until the oil and gas reservoir pressure fitting value and the actual data of the overall pressure of the oil and gas reservoir tend to coincide within the simulation accuracy requirement range; with fixed gas production as the fitting premise, the average daily water production and average daily oil production of the gas reservoir are the main indicators, and the sensitive parameters are fine-tuned within the allowable range, so that the gas well production dynamic fitting curve obtained by numerical simulation is closer to the actual production curve, and the distribution of condensate gas reservoir formation fluid and pressure distribution under the current production state are obtained. After adjusting the parameters of the three-dimensional geological model in the above manner, the adjusted three-dimensional geological model is obtained.

[0115] S105: Based on the adjusted three-dimensional geological model and the oil and gas reservoir numerical simulation model, numerical simulation calculations of gas injection schemes at different gas injection times are carried out to determine corresponding prediction results of condensate gas reservoir development indicators.

[0116] In the embodiment of the present application, based on the adjusted three-dimensional geological model and the numerical simulation model of the oil and gas reservoir, numerical simulation calculations of the gas injection schemes at different gas injection times (early, middle and late gas injection) are carried out to obtain the prediction results corresponding to the prediction indicators of condensate gas reservoir development under different gas injection times and different injection and production well network conditions, including gas injection volume, gas production volume, pressure maintenance level, water invasion, condensate oil production and recovery rate, etc.

[0117] S106: According to the prediction results of the condensate gas reservoir development index corresponding to each gas injection opportunity, the operation plan for converting the condensate gas reservoir into a gas storage reservoir at each gas injection opportunity is determined.

[0118] In the above step S106, the operation plan for converting the condensate gas reservoir into a gas storage reservoir at each gas injection opportunity is determined according to the prediction results of the condensate gas reservoir development index at each gas injection opportunity, specifically including:

[0119] According to the prediction results of the development index of the condensate gas reservoir at each gas injection opportunity, based on the numerical simulation model of the oil and gas reservoir, a numerical simulation model for converting the condensate gas reservoir into a gas storage reservoir at each gas injection opportunity is established;

[0120] According to the numerical simulation model of converting the condensate gas reservoir into a gas storage reservoir at each gas injection opportunity, an operation plan for converting the condensate gas reservoir into a gas storage reservoir at each gas injection opportunity is determined.

[0121] In the embodiment of the present application, according to the prediction index of condensate gas reservoir development at different gas injection times, the parameters are modified on the basis of the established numerical simulation model of oil and gas reservoirs, and a numerical simulation model of condensate gas reservoir conversion to gas storage at different times is established. The injection and production well network is set, and the injection and production system of the injection / production well cycle is modified to prepare for obtaining a reasonable range of sensitive parameters.

[0122] The operation scheme design of condensate gas reservoir conversion to gas storage with different gas injection timings is carried out. The main design sensitive parameters include gas cushion scale, injection and production well network, injection and production cycle, operating pressure range, working gas volume, single well injection and production volume, injection and production speed, etc., and the operation scheme of condensate gas reservoir conversion to gas storage with different gas injection timings is obtained.

[0123] S107: Performing optimal evaluation on the condensate gas reservoir-to-gas storage operation plans at each gas injection opportunity, and determining the condensate gas reservoir-to-gas storage operation plan with the highest comprehensive value.

[0124] In the above step S107, the optimal evaluation is performed on the operation schemes for converting the condensate gas reservoir into a gas storage facility according to the gas injection opportunities to determine the operation scheme for converting the condensate gas reservoir into a gas storage facility with the highest comprehensive value, specifically including:

[0125] According to the condensate gas reservoir conversion gas storage operation plan at each gas injection opportunity, determining the prediction result of the gas storage operation dynamic index at each gas injection opportunity;

[0126] Determine several optimal gas storage conversion operation plans based on the prediction results of the gas storage operation dynamic indicators at each gas injection opportunity;

[0127] According to the calculated total profits of several optimal condensate gas reservoir conversion gas storage operation plans, the condensate gas reservoir conversion gas storage operation plan with the highest comprehensive value is determined.

[0128] In the embodiments of the present application, according to the operation scheme of converting the condensate gas reservoir into a gas storage at different gas injection times, numerical simulation calculations are carried out according to the sensitive parameter values ​​designed in the scheme, and the prediction results of the dynamic indexes of the gas storage operation under the operation scheme of converting the condensate gas reservoir into a gas storage at different gas injection times are obtained. The prediction results of the dynamic indexes of the gas storage operation mainly include the effective storage capacity of the gas storage, pressure distribution and change law, condensate oil and water production, effective working gas volume, water invasion dynamics and the saturation distribution of each fluid.

[0129] According to the prediction results of the dynamic indicators of gas storage operation under the above-mentioned condensate gas reservoir conversion gas storage operation schemes with different gas injection timings, several optimal condensate gas reservoir conversion gas storage operation schemes are selected from the technical optimal level, and then according to the total profit of the selected several optimal condensate gas reservoir conversion gas storage operation schemes, the condensate gas reservoir conversion gas storage operation scheme with the highest comprehensive value is determined. Among them, the total profit determination process of a condensate gas reservoir conversion gas storage operation scheme is as follows:

[0130] According to the sales revenue of natural gas produced in each operation cycle of the gas storage and the sales revenue of condensate oil produced in each operation cycle of the gas storage in a condensate gas reservoir conversion gas storage operation plan, the total project revenue under the operation plan is determined based on the following formula 1:

[0131] R=R G + R O Formula 1;

[0132] In the formula, R is the total project income; R G The revenue from natural gas sales during each operation cycle of the gas storage facility; R O The revenue from the sale of condensate oil is collected during each operation cycle of the gas storage facility.

[0133] According to the fixed operating costs, variable operating costs, natural gas procurement costs, natural gas processing costs, natural gas injection / production costs and produced water treatment costs in a condensate gas reservoir conversion gas storage operation plan, the engineering cost under the operation plan is determined based on the following formula 2:

[0134] O=O F +O V +O B +O P +O G +O W Formula 2;

[0135] Where, O is the project cost; O F is the fixed operating cost; V is the variable operating cost; B is the natural gas procurement cost; P is the natural gas processing cost; G is the natural gas injection / production cost; W is the cost of producing water treatment.

[0136] According to the investment in renovation and maintenance of old wells, investment in new wells, investment in natural gas distribution and injection system, investment in natural gas transmission pipelines and investment in water treatment equipment in a condensate gas reservoir-to-gas storage operation plan, the construction investment under the operation plan is determined based on the following formula 3:

[0137] I=I O +I N +I S +I P +I W Formula 3;

[0138] In the formula, I is the construction investment; O Investment in renovation and maintenance of old wells; N Invest in new wells; S Invest in a natural gas distribution system; P Invest in natural gas transmission pipelines; W Invest in water treatment plants.

[0139] According to the resource tax, value-added tax, education surcharge, urban construction tax and corporate income tax in a condensate gas reservoir conversion gas storage operation plan, the tax payment fee under the operation plan is determined based on the following formula 4:

[0140] T=T R +T VA +T E +T C + T I Formula 4;

[0141] In the formula, T is the tax payment cost; T R is resource tax; T VA T is the value added tax; E Additional tax for education; C Urban construction tax; T I For corporate income tax.

[0142] According to the total project income, project cost, construction investment and tax payment in a condensate gas reservoir-to-gas storage operation plan obtained in the above process, the total profit of a condensate gas reservoir-to-gas storage operation plan is determined based on the following formula 5:

[0143] P = ROIT Formula 5;

[0144] In the formula, P is the after-tax cash flow, that is, the total profit; R is the total project income; O is the project cost; I is the construction investment; and T is the tax payment fee.

[0145] The total profit of each optimal condensate gas reservoir-to-gas storage operation plan is calculated through the above process, and the condensate gas reservoir-to-gas storage operation plan with the maximum profit, i.e., the highest total profit, is selected as the condensate gas reservoir-to-gas storage operation plan with the highest comprehensive value.

[0146] In the embodiment of the present application, during the evaluation of the operation timing of a deep medium-high condensate oil condensate gas reservoir gas storage reservoir, if Figure 2 As shown, geological evaluation and dynamic evaluation of condensate gas reservoir development are carried out on the target block of condensate gas reservoir, including geological reserves, condensate oil reserves, dynamic reserves, formation pressure, dew point, maximum reverse condensate pressure and water invasion, etc., and feasibility analysis and evaluation are carried out; by carrying out three-dimensional geological modeling and oil and gas reservoir numerical simulation modeling of the target block, the numerical simulation calculation of gas injection schemes under different gas injection opportunities is carried out, and multiple rounds of injection and production in the gas storage operation pressure range under the condensate gas reservoir transfer gas reservoir at different gas injection opportunities are carried out to test the injection and production gas volume and condensate oil recovery rate; the scheme optimization design of the condensate gas reservoir transfer gas reservoir at different gas injection opportunities is carried out and parameter index prediction is carried out, and several optimal schemes of the condensate gas reservoir transfer gas reservoir are selected to calculate the total profit according to the cost-benefit relationship, and an economic evaluation is carried out to confirm the operation scheme of the condensate gas reservoir transfer gas reservoir with the highest comprehensive value, that is, to confirm the operation timing of the condensate gas reservoir transfer gas reservoir with medium and high condensate oil content in deep layers.

[0147] Embodiment 2

[0148] Based on the same inventive concept, the present application also provides a device for evaluating the operation timing of a gas storage reservoir for a deep medium-high condensate oil condensate gas reservoir, referring to Figure 3 As shown, the device comprises:

[0149] The first modeling module 101 is used to establish a three-dimensional geological model based on the analysis results of the development geological evaluation and development dynamic evaluation of the condensate gas reservoir obtained in advance and a plurality of modeling static parameters;

[0150] A second modeling module 102 is used to adjust the control parameter by fitting the fluid parameter of the predetermined fluid sample, and to establish a numerical simulation model of the oil and gas reservoir based on the control parameter and a plurality of predetermined simulation parameters;

[0151] The first determination module 103 is used to perform development dynamic simulation calculation on the three-dimensional geological model according to the oil and gas reservoir numerical simulation model to obtain development dynamic fitting data;

[0152] A model adjustment module 104 is used to adjust the three-dimensional geological model according to the comparison result between the development dynamic fitting data and the corresponding historical development dynamic actual data to obtain an adjusted three-dimensional geological model;

[0153] The second determination module 105 is used to carry out numerical simulation calculations of gas injection schemes at different gas injection times based on the adjusted three-dimensional geological model and the oil and gas reservoir numerical simulation model, and determine the corresponding prediction results of condensate gas reservoir development indicators;

[0154] The third determination module 106 is used to determine the operation plan of converting the condensate gas reservoir into a gas storage reservoir at each gas injection opportunity according to the prediction results of the condensate gas reservoir development index corresponding to each gas injection opportunity;

[0155] The fourth determination module 107 is used to perform optimal evaluation according to the condensate gas reservoir conversion gas storage operation schemes at each gas injection opportunity, and determine the condensate gas reservoir conversion gas storage operation scheme with the highest comprehensive value.

[0156] Embodiment 3

[0157] Based on the same inventive concept, an embodiment of the present application also provides a computer-readable storage medium on which a computer program is stored. When the program is executed by a processor, the method for evaluating the operating timing of a gas storage reservoir for a deep medium-high condensate oil content condensate gas reservoir as described in the above-mentioned embodiment 1 is implemented.

[0158] Embodiment 4

[0159] Based on the same inventive concept, an embodiment of the present application also provides a computer device, including 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 method for evaluating the operating timing of a gas storage reservoir for a deep medium-high condensate oil content condensate gas reservoir as described in the above-mentioned embodiment 1 is implemented.

[0160] Embodiment 5

[0161] Based on the same inventive concept, an embodiment of the present application also provides a computer program product comprising instructions. When the computer program product is executed on a computer device, the computer device executes the method for evaluating the operation timing of a gas storage reservoir for a deep medium-high condensate oil content condensate gas reservoir as described in the above-mentioned embodiment 1.

[0162] Embodiment 6

[0163] Based on the same inventive concept, an embodiment of the present application also provides a chip, the chip includes a processor and a communication interface, the communication interface and the processor are coupled, and the processor is used to run a computer program or instruction to implement the method for evaluating the operating timing of a deep medium-high condensate oil-containing condensate gas reservoir gas storage reservoir as described in the above-mentioned embodiment one.

[0164] 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 on one or more computer-usable storage media (including but not limited to disk storage and optical storage, etc.) that contain computer-usable program code.

[0165] 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.

[0166] 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.

[0167] 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 The steps for the functions specified in one or more boxes.

[0168] Obviously, those skilled in the art can make various changes and modifications to the present application without departing from the spirit and scope of the present application. Thus, if these modifications and variations of the present application fall within the scope of the claims of the present application and their equivalents, the present application is also intended to include these modifications and variations.

Claims

1. A method for evaluating the operation timing of a gas storage reservoir for a deep medium-high condensate oil condensate gas reservoir, characterized in that: include: A three-dimensional geological model is established based on the previously obtained analysis results of the development geological evaluation and development dynamic evaluation of the condensate gas reservoir and multiple modeling static parameters; adjusting the control parameter by fitting the fluid parameter of the predetermined fluid sample, and establishing a numerical simulation model of the oil and gas reservoir based on the control parameter and a plurality of predetermined simulation parameters; Performing development dynamic simulation calculation on the three-dimensional geological model according to the oil and gas reservoir numerical simulation model to obtain development dynamic fitting data; According to the comparison result between the development dynamic fitting data and the corresponding historical development dynamic actual data, the three-dimensional geological model is adjusted to obtain an adjusted three-dimensional geological model; Based on the adjusted three-dimensional geological model and the oil and gas reservoir numerical simulation model, numerical simulation calculations of gas injection schemes at different gas injection times are carried out to determine corresponding prediction results of condensate gas reservoir development indicators; According to the prediction results of the development index of condensate gas reservoirs corresponding to each gas injection opportunity, the operation plan of converting condensate gas reservoirs into gas storage at each gas injection opportunity is determined; An optimal evaluation is performed based on the condensate gas reservoir-to-gas storage operation plans at each gas injection opportunity to determine the condensate gas reservoir-to-gas storage operation plan with the highest comprehensive value.

2. The method according to claim 1, characterized in that The three-dimensional geological model is established based on the analysis results of the development geological evaluation and development dynamic evaluation of the condensate gas reservoir obtained in advance and multiple modeling static parameters, including: Grid division is performed based on the previously obtained reservoir characteristics of the condensate gas reservoir to determine the basic data for modeling; Carry out reservoir structure modeling based on the pre-acquired digital data of the structural map and breakpoint data; Reservoir attribute modeling is performed based on the previously acquired single well scattered sedimentary facies data; Based on the analysis results of the development geological evaluation and development dynamic evaluation of the condensate gas reservoir obtained in advance, a three-dimensional geological model is established according to the basic modeling data, reservoir structure modeling and reservoir attribute modeling.

3. The method according to claim 2, characterized in that After the three-dimensional geological model is established, the following steps are also included: The reserves obtained according to the three-dimensional geological model are compared with the historical reserve results obtained in advance to verify the three-dimensional geological model.

4. The method according to claim 1, characterized in that The performing development dynamic simulation calculation on the three-dimensional geological model according to the oil and gas reservoir numerical simulation model to obtain development dynamic fitting data includes: Performing simulation calculation on the oil and gas geological reserves according to the oil and gas reservoir numerical simulation model to obtain the oil and gas geological reserves fitting value; Performing simulation calculation on the oil and gas reservoir pressure according to the oil and gas reservoir numerical simulation model to obtain the oil and gas reservoir pressure fitting value; The gas well production performance is simulated and calculated according to the oil and gas reservoir numerical simulation model to obtain a gas well production performance fitting curve.

5. The method according to claim 1, characterized in that The operation plan for converting the condensate gas reservoir into a gas storage reservoir at each gas injection opportunity is determined based on the prediction results of the condensate gas reservoir development index at each gas injection opportunity, including: According to the prediction results of the development index of the condensate gas reservoir at each gas injection opportunity, based on the numerical simulation model of the oil and gas reservoir, a numerical simulation model for converting the condensate gas reservoir into a gas storage reservoir at each gas injection opportunity is established; According to the numerical simulation model of converting the condensate gas reservoir into a gas storage reservoir at each gas injection opportunity, an operation plan for converting the condensate gas reservoir into a gas storage reservoir at each gas injection opportunity is determined.

6. The method according to claim 1, characterized in that The optimal evaluation of the condensate gas reservoir conversion to gas storage operation plan according to each gas injection opportunity is performed to determine the condensate gas reservoir conversion to gas storage operation plan with the highest comprehensive value, including: According to the condensate gas reservoir conversion gas storage operation plan at each gas injection opportunity, determining the prediction result of the gas storage operation dynamic index at each gas injection opportunity; Determine several optimal gas storage conversion operation plans based on the prediction results of the gas storage operation dynamic indicators at each gas injection opportunity; According to the calculated total profits of several optimal condensate gas reservoir conversion gas storage operation plans, the condensate gas reservoir conversion gas storage operation plan with the highest comprehensive value is determined.

7. A device for evaluating the operation timing of a gas storage reservoir for deep medium-high condensate oil condensate gas reservoir, characterized in that: include: The first modeling module is used to establish a three-dimensional geological model based on the analysis results of the development geological evaluation and development dynamic evaluation of the condensate gas reservoir obtained in advance and a plurality of modeling static parameters; a second modeling module, for adjusting the control parameter by fitting the fluid parameter of the predetermined fluid sample, and establishing a numerical simulation model of the oil and gas reservoir based on the control parameter and a plurality of predetermined simulation parameters; A first determination module is used to perform development dynamic simulation calculation on the three-dimensional geological model according to the oil and gas reservoir numerical simulation model to obtain development dynamic fitting data; A model adjustment module, used to adjust the three-dimensional geological model according to the comparison result between the development dynamic fitting data and the corresponding historical development dynamic actual data, so as to obtain an adjusted three-dimensional geological model; The second determination module is used to carry out numerical simulation calculations of gas injection schemes at different gas injection times based on the adjusted three-dimensional geological model and the oil and gas reservoir numerical simulation model, and determine the corresponding prediction results of condensate gas reservoir development indicators; The third determination module is used to determine the operation plan of converting the condensate gas reservoir into a gas storage reservoir at each gas injection opportunity according to the prediction results of the condensate gas reservoir development indicators corresponding to each gas injection opportunity; The fourth determination module is used to perform optimal evaluation on the condensate gas reservoir conversion gas storage operation plan at each gas injection opportunity, and determine the condensate gas reservoir conversion gas storage operation plan with the highest comprehensive value.

8. A computer-readable storage medium storing instructions, which, when executed on a terminal, enable the terminal to execute the method for evaluating the timing of operation of a gas storage reservoir for a deep medium-high condensate oil content condensate gas reservoir as described in any one of claims 1 to 6.

9. A computer device, characterized in that: The method 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 method for evaluating the operating timing of a gas storage reservoir for a deep medium-high condensate oil content condensate gas reservoir is implemented as described in any one of claims 1 to 6.

10. A computer program product comprising instructions, which, when executed on a computer device, enables the computer device to execute the method for evaluating the timing of operation of a gas storage reservoir for a deep medium-high condensate oil content condensate gas reservoir as claimed in any one of claims 1 to 6.

11. A chip, comprising a processor and a communication interface, wherein the communication interface is coupled to the processor, and the processor is used to run a computer program or instruction to implement the method for evaluating the operating timing of a gas storage reservoir for a deep medium-high condensate oil content condensate gas reservoir as described in any one of claims 1 to 6.

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