CN115618768A - Method for calculating effective gas storage space of gas storage - Google Patents
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Abstract
The invention discloses a method for calculating an effective gas storage space of a gas storage, which is carried out according to the following steps: s1, establishing a three-dimensional geological model of a gas storage; s2, coarsening the grid system; s3, preparing numerical simulation basic parameters; s4, obtaining a relative permeability curve; s5, acquiring PVT parameters; s6, establishing a gas storage numerical simulation model; s7, carrying out overall process history fitting on the gas storage numerical simulation model; s8, performing zonal division on the gas storage based on the critical saturation parameter; s9, extracting the pore volume of the gas storage; s10, determining the utilization efficiency of each permeation zone of the gas storage; s11, determining the effective gas storage space of the gas storage. By adopting the method, the size of the effective gas storage space of the reservoir can be accurately determined when the depleted oil-gas reservoir is reconstructed into the gas storage, and a scientific basis is provided for the design of the storage capacity parameters of the gas storage.
Description
Technical Field
The invention belongs to the technical field of oil and gas exploitation, and particularly relates to a method for calculating an effective gas storage space of a gas storage.
Background
The natural gas underground gas storage (hereinafter referred to as "gas storage") is an underground large container which is reconstructed by original oil and gas reservoirs, salt caverns and other reservoirs, has a certain sealing capacity and can store natural gas. The gas storage reservoir is formed by reconstructing depleted or operating oil and gas reservoirs, the working gas amount accounts for more than 75% of the total working gas amount of the world gas storage reservoirs, and the gas storage reservoir is the gas storage reservoir with the longest reservoir building time, the largest peak regulation scale and the most complete technical matching and is a main facility for peak regulation and storage in natural gas seasons in China. The gas storage is different from gas reservoir one-way gas production, and has the characteristics of violent gas alternate strong injection and strong production working conditions, high-flow throughput fluid high-speed seepage of injection and production gas wells, periodic disturbance of ground stress fields and the like. The underground gas storage is mostly built by depleted and weak-edge water-gas reservoirs, edge bottom water with larger volume is developed in most reservoirs, the relation of oil, gas and water is complex during building the storage, water invasion is serious, and the technical difficulty of the design of the gas storage construction and operation optimization scheme is aggravated.
The reservoir capacity is an important monitoring and control content for the normal operation of the gas storage, and reservoir capacity parameter design and evaluation are two common reservoir capacity evaluation methods, namely a static method and a dynamic method, in the current key technology of the construction and operation of the gas storage. The static storage capacity evaluation method has poor applicability in a multi-cycle dynamic injection and production process, and cannot accurately evaluate the utilization degree of the storage capacity; the dynamic method generally reflects the change of the reservoir capacity in the real operation process by establishing a material balance injection-production dynamic prediction model and a reservoir capacity analysis model, but the required parameters are only pressure test of partial well points, which cannot represent the real pressure distribution of the whole area, and the test cost is high. And because the exhausted oil and gas reservoirs mostly face the severe flooding condition, deviation can occur in single-well pressure test, and the reservoir capacity is difficult to accurately calculate by using a dynamic method.
Therefore, it is necessary to provide a reasonable method for extracting the effective gas storage space of the gas storage.
Disclosure of Invention
In view of this, the present invention provides a method for calculating an effective gas storage space of a gas storage, so as to solve the problem that it is difficult to determine the effective gas storage space of the gas storage in the prior art.
The technical scheme is as follows:
a method for calculating the effective gas storage space of a gas storage comprises the following steps:
s1, establishing a three-dimensional geological model of a gas storage;
establishing a three-dimensional geological model of the gas storage according to geological static data of the oil-gas reservoir and a longitudinal distribution rule of oil, gas and water;
s2, coarsening the grid system;
carrying out coarsening on a grid and attribute data volume on the basis of a three-dimensional geological model of the gas storage;
s3, preparing numerical simulation basic parameters;
preparing required numerical simulation basic parameters, wherein the numerical simulation basic parameters comprise reservoir parameters and fluid parameters of a gas storage;
s4, obtaining a relative permeability curve;
obtaining oil gas relative permeability data and oil water relative permeability data according to the test of the experimental sample, and obtaining an oil gas relative permeability curve and an oil water relative permeability curve through normalization treatment;
s5, acquiring PVT parameters;
establishing a stratum fluid state equation by using the high-pressure physical property experimental data of the well fluid of the production well, fitting to obtain PVT parameters, and determining the critical temperature and the critical pressure;
s6, establishing a gas storage numerical simulation model;
establishing a gas storage numerical simulation model based on a gas storage three-dimensional geological model, numerical simulation basic parameters, relative permeability curves and PVT parameters, and initializing the gas storage numerical simulation model;
s7, carrying out overall process history fitting on the gas storage numerical simulation model;
performing overall-process history fitting on the numerical simulation model of the gas storage according to the production history dynamic characteristics and the fluid distribution characteristics of the gas storage;
s8, performing zonal division on the gas storage based on the critical saturation parameter;
according to different parameters of fluid saturation, dividing each permeation zone of the gas storage into a pure gas zone, a gas-oil transition zone, a pure oil zone and a water flooding zone;
s9, extracting the pore volume of the gas storage;
introducing the zone division result into a gas storage numerical simulation model in a data stream mode, and extracting the pore volume of each permeation zone of the gas storage, wherein the pore volume comprises a pore volume containing gas, a pore volume containing oil, a pore volume containing water and a pore volume containing hydrocarbon;
s10, determining the utilization efficiency of each permeation zone of the gas storage;
determining the utilization efficiency of each permeation zone of the gas storage according to the multi-cycle injection-production simulation experiment result;
s11, determining an effective gas storage space of a gas storage;
and calculating to obtain the effective gas storage space of the gas storage according to the pore volume and the utilization efficiency of each permeation zone of the gas storage.
Compared with the prior art, the invention has the beneficial effects that:
by adopting the method for calculating the effective gas storage space of the gas storage provided by the invention, the size of the effective gas storage space of the reservoir can be accurately determined when the depleted oil-gas reservoir is reconstructed into the gas storage, and a scientific basis is provided for the design of the storage capacity parameters of the gas storage.
Drawings
FIG. 1 is a flow chart of the present invention;
FIG. 2 is a schematic diagram of a geological model mesh parameter design;
FIG. 3 is a schematic diagram of a fault model;
FIG. 4 is a schematic diagram of a layer model;
FIG. 5 is a schematic diagram of a deposition microphase model;
FIG. 6 is a schematic illustration of the isochronous sand envelope of each individual well;
FIG. 7 is a schematic view of a sandwiched mud phase model;
FIG. 8 is a schematic of a porosity model;
FIG. 9 is a schematic of a permeability model;
FIG. 10 is a schematic diagram of a saturation model;
FIG. 11 is a probability distribution of porosity data;
FIG. 12 is a permeability data probability distribution;
FIG. 13 is a saturation data probability distribution;
FIG. 14 is a graph of porosity correlation versus accuracy for each well;
FIG. 15 is a graph of permeability dependence versus accuracy for each well.
Detailed Description
The present invention will be described in further detail with reference to the accompanying drawings.
Referring to fig. 1, a method for calculating an effective gas storage space of a gas storage is provided, which comprises the following steps:
s1, establishing a three-dimensional geological model of a gas storage
And establishing a three-dimensional geological model of the gas storage according to geological static data of the oil-gas reservoir and the longitudinal distribution rule of oil, gas and water.
Specifically, step S1 is performed according to the following steps:
s1-1, setting grid cells and dimensions of the model.
Referring to fig. 2, in order to control the morphology of the geologic body and ensure the modeling accuracy, in the embodiment, an angular point grid is adopted, and a plane is divided by 20m × 20 m; in order to make the model reflect the longitudinal heterogeneity of the reservoir, the longitudinal dimension is controlled at the level of a small layer and is divided into 0.5-1 m.
S1-2, establishing a gas storage structure model.
And constructing a space lattice of which the model reflects the reservoir, wherein the space lattice comprises a fault model and a layer model. The following processing is carried out for improving the quality of the fault model: (1) small fault treatment: for small faults which do not break through the entire model in the longitudinal direction, when processing fault columns, the length of the fault column is properly extended to penetrate through the entire model, and the top and bottom of each fault column are on the same horizontal plane, so as to prevent the skeleton grid model from being disordered. And (2) fault column direction processing: the directions of all fault columns in the block are generally grasped, namely, the directions of all fault columns in the model area are kept to be approximately similar, the spacing distribution is uniform, the quantity is proper, and the shape of the section is correctly reflected. Referring to fig. 3, the fault model established on the basis can accurately reflect the real form of the fault in the work area spread in the three-dimensional space.
In this embodiment, a gas storage structure model is built based on single well basic data, seismic interpretation data and regional geological data of a gas storage region, wherein the gas storage comprises a plurality of stacked small layers, and a layer model reflects three-dimensional distribution of a stratum interface, please refer to fig. 4, and the layer model of each small layer is stacked together to form the gas storage structure model.
S1-3, establishing a gas storage deposit microphase model.
The sedimentary microfacies model is a three-dimensional spatial distribution of different microfacies types within the reservoir. The sedimentary facies controls the spreading direction and the distribution rule of the physical parameters of the reservoir and the flowing characteristics of underground fluid to a certain extent. Therefore, the accurate establishment of the sedimentary microfacies three-dimensional model is a key technology for phase control simulation of reservoir physical properties and research of reservoir heterogeneity at a later stage.
In this embodiment, the sedimentary microfacies of the gas storage area are divided according to the research results of the area background data, the well logging interpretation, the core analysis and the like, then the two-dimensional sedimentary microfacies distribution map of each small layer is subjected to boundary digitization, and a sedimentary microfacies model of the gas storage is established by an assignment method, as shown in fig. 5.
S1-4, establishing a gas storage reservoir lithofacies model.
The lithofacies model mainly reflects three-dimensional distribution of different lithologies of target intervals in a research area, and is the basis of fault plugging calculation, geomechanical modeling and reservoir physical property simulation. In the embodiment, an envelope surface method is adopted for lithofacies modeling, specifically, on the basis of completing fine identification of single sand bodies of each well point, in an isochronous small layer, isochronous sand body envelope surfaces at the top and the bottom of each single sand body are determined by taking top and bottom data of the single sand body identified by each single well as constraint (see fig. 6), and a single sand body lithofacies model and interlayer mud facies models among the sand bodies are established by taking the envelope surfaces as constraint (see fig. 7), so that the gas storage reservoir lithofacies model is formed by each single sand body lithofacies model and each interlayer mud facies model.
S1-5, establishing a gas storage attribute model, wherein the gas storage attribute model comprises a porosity model, a permeability model and a saturation model.
In this embodiment, on the basis of a gas storage sedimentary microfacies model and a gas storage lithofacies model, sedimentary facies are used as constraints, the reservoir physical property correlation in each sedimentary facies is analyzed, then interpolation calculation is performed on logging data by using a stochastic simulation method, weighting and conditional constraint are performed on the simulation calculation by using a cokriging method, so that the interpolation of logging values is close to interwell distribution, deterministic modeling and stochastic modeling can be combined, and a porosity model (see fig. 8), a permeability model (see fig. 9) and a saturation model (see fig. 10) are respectively established.
S1-6, checking whether the accuracy of the gas storage structure model, the gas storage sedimentary microfacies model, the gas storage lithofacies model and the gas storage attribute model is qualified or not: if not, returning to the step S1-1 and adjusting parameters; yes, the process proceeds to step S2.
When a model is built, the size of the mesh size of the model, the selection of the variation function and the difference of the modeling method all affect the accuracy of the model. Therefore, the implementation adopts the following two methods to test the accuracy of the gas storage structure model, the gas storage sedimentary microfacies model, the gas storage lithofacies model and the gas storage attribute model:
(1) Probability distribution consistency check
When a geostatistics method is applied to modeling, a three-dimensional geological model of the gas storage reservoir is established through condition simulation, and due to the fact that interpolation and extrapolation with certain precision are conducted on unknown space points, a three-dimensional data body with gridded target interval is obtained, and the data amount is increased by thousands of times. If the model has high precision, the data distribution rule of the model is approximately consistent with the distribution rule of the original data, namely the model and the original data have the same distribution region and peak value forms, otherwise, the model and the original data have larger difference. Referring to fig. 11 to 13, comparing the model data volume of porosity, permeability and saturation with the distribution histogram of the original data, where blue represents the data volume of the attribute model, red represents the original data volume, and green represents the data volume obtained by discretizing the original data, it can be seen that, except that the maximum and minimum values at the head and the tail have a certain non-difference due to the peak-eliminating effect, they have similar distribution rules, which indicates that the three models have higher precision.
(2) Inspection of single well physical property parameter and original curve goodness of fit
When the random simulation method is used for inter-well prediction of reservoir parameters, the model is necessarily faithful to the data on the well. Therefore, the accuracy of the reservoir attributes on a single well depends on the size of the vertical grid of the model and is not influenced by the modeling method. The size of the vertical grid is too small, the model precision is high, but the calculation amount is large; if the vertical dimension is too large, the model accuracy is low, and the difference between the well property and the original curve is too large. Therefore, when the size of the vertical grid is determined, the physical property of a single-well reservoir stratum can be accurately represented, the feasibility of modeling is considered, and the grid size is preferably smaller. Referring to fig. 14 and 15, the degree of coincidence between the envelope of the discretized data of each well grid and the original hole, seepage and saturation curves is high, reaching more than 95%, and the model precision is ensured to a certain extent.
S2, coarsening the grid system
And coarsening the grid and attribute data volume on the basis of the three-dimensional geological model of the gas storage. The numerical simulation modeling accuracy requirement of the gas storage is higher than that of a common residual oil gas prediction model, the step length of a common plane grid is not more than 25 x 25m, and the actual complex conditions of edge bottom water, oil rings and the like need to be considered in a longitudinal grid.
S3, preparing numerical simulation basic parameters
Preparing required numerical simulation basic parameters, wherein the numerical simulation basic parameters comprise reservoir parameters and fluid parameters of the gas storage reservoir. The reservoir parameters of the gas storage mainly comprise reservoir temperature and pressure, surface temperature and pressure, an oil-gas-water interface, matrix rock compression coefficients and the like; the fluid parameters mainly comprise natural gas relative density, surface crude oil density, crude oil volume coefficient, formation water viscosity, original dissolved gasoline ratio and the like.
S4, obtaining a relative permeability curve
And obtaining oil gas relative permeability data and oil water relative permeability data according to the test of the experimental sample, and obtaining an oil gas relative permeability curve and an oil water relative permeability curve through normalization treatment.
Wherein, the normalization processing is carried out by adopting the following formula:
oil-water two-phase system:
in the formulae (1) and (2), K ro Represents the relative permeability of the oil;
represents the relative permeability of the oil phase at irreducible water saturation, mD; s w Indicating water saturation; s orw Represents the residual oil saturation,%, of the two oil and water phases; s wc Indicating irreducible water saturation; k rw Represents the relative permeability of water;
represents the relative water phase permeability at residual oil saturation; n is o Representing the relative permeability curve index of the oil phase without dimension; n is a radical of an alkyl radical w Represents the water relative permeability curve index without dimension;
oil gas two-phase system:
in the formulae (3) and (4),
represents the relative permeability of the oil phase at residual gas saturation, mD; s. the g Indicating the gas saturation; s lc Denotes the total critical liquid saturation,%, and, S lc ＝S wc +S org ；S org Represents residual oil saturation,%, in both oil and gas phases; s gc Represents critical gas saturation,%; k rg Represents the relative permeability of gas;
represents the relative gas phase permeability at residual oil saturation; s gc Indicates residual gas saturation,%; n is g Represents the gas phase versus permeability curve index without dimension; n is a radical of an alkyl radical go Representing the relative permeability curve index of oil in the gas-oil two phases without dimension.
S5, acquiring PVT parameters
And establishing a state equation of the formation fluid by using the experimental data of the high-pressure physical properties of the well fluid of the production well, fitting to obtain PVT parameters, and determining the critical temperature and the critical pressure. The PVT parameters comprise parameters such as a PVT phase diagram of the gas storage, a natural gas volume coefficient, fluid density and a dissolved gas-oil ratio.
S6, establishing a numerical simulation model of the gas storage
Based on a gas storage three-dimensional geological model, a numerical simulation basic parameter, a relative permeability curve and a PVT parameter, establishing a gas storage numerical simulation model by utilizing an oil reservoir numerical simulation software ECLIPSE, initializing the gas storage numerical simulation model, and obtaining an oil reservoir initial gas-containing saturation field, an oil-containing saturation field and a pressure distribution field by adopting a vertical gravity balance mode, wherein the reference pressure, the reference depth, an oil-water interface and an oil-gas interface are included. Because the oil-gas-water interfaces of different fault blocks and different layer systems of the reservoir are slightly different, sim-office numerical simulation software is required to be used during initialization, the reservoir grid system is subjected to balanced partition assignment by taking the disconnected fault blocks and the layer systems as the basis, and the assigned value is led into a numerical simulation model. When the model grid system is coarsened, the pore volume of the reservoir is slightly changed, and the original geological reserves of oil and gas are fit in a partition mode.
S7, carrying out overall process history fitting on the numerical simulation model of the gas storage
When a numerical simulation method is applied to research the migration characteristics of reservoir fluid, the reservoir physical property parameters in the simulation calculation cannot completely reflect the real conditions of the oil and gas reservoir because the geological knowledge of the oil and gas reservoir has limitations. In order to reduce the calculation error caused by reservoir physical properties, the whole-process history fitting including the gas storage and the single-well index fitting is carried out on the gas storage numerical simulation model according to the production history dynamic characteristics and the fluid distribution characteristics of the gas storage.
During fitting, the gas storage index fitting can be performed by adopting modes of layering, breaking blocks and the like according to the gas storage development history dynamic data and based on the type of the gas storage and the crushing degree of a reservoir; the single-well index fitting can be performed according to the specific yield of oil, gas and water in production data by adopting a method of determining gas yield, water yield, oil yield and liquid yield. Generally, the historical fitting error is controlled to be more than 90%, and the numerical simulation model can accurately reflect the seepage condition of reservoir fluid.
S8, performing zonal division on the gas storage based on the critical saturation parameter
According to different parameters of fluid saturation, each permeation zone of the gas storage is divided into a pure gas zone, a gas-oil transition zone, a pure oil zone and a water flooded zone. When dividing zones, critical saturation parameters of different zones are determined according to initial gas saturation, residual oil saturation, residual gas saturation and irreducible water saturation. Based on the current oil-gas-water three-phase fluid saturation distribution characteristics obtained by a full-process history fitting numerical simulation model, a pure gas area, a gas-oil transition area, an oil ring and a water flooded area are finely described by combining critical saturation parameters of different zones.
In order to more finely depict the zones, the numerical simulation model is written into numerical simulation software sim-office, and the zones are depicted in a flow partitioning module in a grid assignment mode.
S9, extracting the pore volume of the gas storage
And (3) introducing the zone division results into a gas storage numerical simulation model in the form of data stream, and extracting the pore volume of each permeation zone of the gas storage, wherein the pore volume comprises a gas-containing pore volume, an oil-containing pore volume, a water-containing pore volume and a hydrocarbon-containing pore volume.
S10, determining the utilization efficiency of each permeation zone of the gas storage
Aiming at the stratum characteristics of the gas storage, a multi-cycle injection-production simulation experiment of the gas storage is carried out by utilizing an injection-production simulation experiment system, and the utilization efficiency of each permeation zone of the gas storage is determined according to the multi-cycle injection-production simulation experiment result. The experimental water is simulated formation water in a research area, the experimental gas is nitrogen, a natural formation core sample is selected as a reservoir model, and an experimental pressure interval is a design value of the operating pressure of the gas storage.
S11, determining the effective gas storage space of the gas storage
According to the pore volume and the utilization efficiency of each permeation zone of the gas storage, the effective gas storage space of the gas storage is obtained through calculation, then the effective storage capacity of the gas storage is obtained through calculation based on the natural gas volume coefficient of the target layer, and support is provided for the subsequent reasonable design of storage capacity parameters.
Finally, it should be noted that the above-mentioned description is only a preferred embodiment of the present invention, and that those skilled in the art can make various similar representations without departing from the spirit and scope of the present invention.
Claims (7)
1. A method for calculating the effective gas storage space of a gas storage is characterized by comprising the following steps:
s1, establishing a three-dimensional geological model of a gas storage;
establishing a three-dimensional geological model of the gas storage according to geological static data of the oil-gas reservoir and a longitudinal distribution rule of oil, gas and water;
s2, coarsening the grid system;
coarsening a grid and attribute data volume on the basis of a three-dimensional geological model of the gas storage;
s3, preparing numerical simulation basic parameters;
preparing required numerical simulation basic parameters, wherein the numerical simulation basic parameters comprise reservoir parameters and fluid parameters of a gas storage;
s4, obtaining a relative permeability curve;
obtaining oil gas relative permeability data and oil water relative permeability data according to the test of the experimental sample, and obtaining an oil gas relative permeability curve and an oil water relative permeability curve through normalization treatment;
s5, acquiring PVT parameters;
establishing a stratum fluid state equation by using the high-pressure physical property experimental data of the well fluid of the production well, fitting to obtain PVT parameters, and determining the critical temperature and the critical pressure;
s6, establishing a gas storage numerical simulation model;
establishing a gas storage numerical simulation model based on a gas storage three-dimensional geological model, numerical simulation basic parameters, relative permeability curves and PVT parameters, and initializing the gas storage numerical simulation model;
s7, carrying out overall process history fitting on the gas storage numerical simulation model;
performing overall-process history fitting on the numerical simulation model of the gas storage according to the production history dynamic characteristics and the fluid distribution characteristics of the gas storage;
s8, performing zonal division on the gas storage based on the critical saturation parameter;
according to different parameters of fluid saturation, dividing each permeation zone of the gas storage into a pure gas zone, a gas-oil transition zone, a pure oil zone and a water flooding zone;
s9, extracting the pore volume of the gas storage;
introducing the zone division result into a gas storage numerical simulation model in a data stream mode, and extracting the pore volume of each permeation zone of the gas storage, wherein the pore volume comprises a pore volume containing gas, a pore volume containing oil, a pore volume containing water and a pore volume containing hydrocarbon;
s10, determining the utilization efficiency of each permeation zone of the gas storage;
determining the utilization efficiency of each permeation zone of the gas storage according to the multi-cycle injection-production simulation experiment result;
s11, determining an effective gas storage space of a gas storage;
and calculating to obtain the effective gas storage space of the gas storage according to the pore volume and the utilization efficiency of each permeation zone of the gas storage.
2. The method for calculating the effective gas storage space of a gas storage according to claim 1, wherein the step S1 is performed according to the following steps:
s1-1, setting grid units and scales of a model;
s1-2, establishing a gas storage structure model;
s1-3, establishing a gas storage deposit microphase model;
s1-4, establishing a gas storage reservoir lithofacies model;
s1-5, establishing a gas storage attribute model, wherein the gas storage attribute model comprises a porosity model, a permeability model and a saturation model;
s1-6, checking whether the accuracy of the gas storage structure model, the gas storage sedimentary microfacies model, the gas storage lithofacies model and the gas storage attribute model is qualified or not: if not, returning to the step S1-1, and adjusting the parameters; yes, the process proceeds to step S2.
3. The method of claim 2, wherein the method comprises the steps of: in the step S1-2, a structural model of the gas storage is established based on single well basic data, seismic interpretation data and regional geological data of the region of the gas storage, wherein the gas storage is composed of a plurality of small layers which are overlapped together, and layer models of each small layer are overlapped together to form the structural model of the gas storage.
4. The method of claim 3, wherein the method comprises the steps of: in the step S1-3, the two-dimensional deposition microphase distribution map of each small layer is subjected to boundary digitalization, and a gas storage deposition microphase model is established by adopting an assignment method.
5. The method for calculating the effective gas storage space of a gas storage according to claim 4, wherein: in the step S1-4, on the basis of finishing fine identification of single sand bodies of each well point, determining the equal-time sand body enveloping surfaces at the top and the bottom of each single sand body by taking the single sand body top and bottom data identified by each single well as constraint in an equal-time small layer, and establishing a single sand body lithofacies model and interlayer mud facies models among the sand bodies by taking the enveloping surfaces as constraint, so that the gas storage reservoir lithofacies model is formed by each single sand body lithofacies model and each interlayer mud facies model.
6. The method for calculating the effective gas storage space of a gas storage according to claim 5, wherein: in the step S1-5, on the basis of a gas storage sedimentary microfacies model and a gas storage lithofacies model, sedimentary facies are taken as constraints, reservoir physical property relevance in each sedimentary facies is firstly analyzed, then a stochastic simulation method is utilized to carry out interpolation calculation on logging data, and weighting and conditional constraint are carried out on simulation calculation through a cokriging method, so that the interpolation of logging values is close to interwell distribution, deterministic modeling and stochastic modeling can be combined, and a porosity model, a permeability model and a saturation model are respectively established.
7. The method for calculating the effective gas storage space of a gas storage according to claim 1, wherein: in step S4, the normalization process is performed by using the following formula:
oil-water two-phase system:
in the formulae (1) and (2), K ro Represents the relative permeability of the oil;
represents the relative permeability of the oil phase at irreducible water saturation, mD; s w Indicating water saturation; s. the orw Represents the residual oil saturation,%, of the two oil and water phases; s wc Indicating irreducible water saturation; k rw Represents the relative permeability of water;
represents the relative water phase permeability at residual oil saturation; n is a radical of an alkyl radical o Representing the relative permeability curve index of the oil phase without dimension; n is w Represents the water relative permeability curve index without dimension;
oil gas two-phase system:
in the formulae (3) and (4),
represents the relative permeability of the oil phase at residual gas saturation, mD; s g Indicating the gas saturation; s lc Denotes the total critical liquid saturation,%, and, S lc ＝S wc +S org ；S org Represents residual oil saturation,%, in both oil and gas phases; s gc Represents critical gas saturation,%; k rg Represents the relative permeability of gas;
represents the relative gas phase permeability at residual oil saturation; s gc Indicates residual gas saturation,%; n is a radical of an alkyl radical g Representing the gas phaseFor permeability curve index, no dimension; n is go Representing the relative permeability curve index of oil in the gas-oil two phases without dimension.
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| CN118095140A (en) * | 2024-04-17 | 2024-05-28 | 成都理工大学 | Method for diagnosing effective reservoir capacity of side water and gas reservoir type gas reservoir |
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| Publication number | Priority date | Publication date | Assignee | Title |
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| CN118095140A (en) * | 2024-04-17 | 2024-05-28 | 成都理工大学 | Method for diagnosing effective reservoir capacity of side water and gas reservoir type gas reservoir |
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