CN118065842B - Well pattern optimization method and system based on carbon dioxide incomplete miscible displacement characteristics - Google Patents
Well pattern optimization method and system based on carbon dioxide incomplete miscible displacement characteristics Download PDFInfo
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- CURLTUGMZLYLDI-UHFFFAOYSA-N Carbon dioxide Chemical compound O=C=O CURLTUGMZLYLDI-UHFFFAOYSA-N 0.000 title claims abstract description 148
- 229910002092 carbon dioxide Inorganic materials 0.000 title claims abstract description 74
- 239000001569 carbon dioxide Substances 0.000 title claims abstract description 74
- 238000000034 method Methods 0.000 title claims abstract description 40
- 238000006073 displacement reaction Methods 0.000 title claims abstract description 38
- 238000005457 optimization Methods 0.000 title claims abstract description 36
- 230000008569 process Effects 0.000 claims abstract description 16
- 238000000605 extraction Methods 0.000 claims abstract description 7
- 239000003921 oil Substances 0.000 claims description 104
- 238000004519 manufacturing process Methods 0.000 claims description 39
- 238000002347 injection Methods 0.000 claims description 37
- 239000007924 injection Substances 0.000 claims description 37
- 239000010779 crude oil Substances 0.000 claims description 19
- 230000035699 permeability Effects 0.000 claims description 17
- 238000011084 recovery Methods 0.000 claims description 10
- 239000012530 fluid Substances 0.000 claims description 9
- 238000004364 calculation method Methods 0.000 claims description 6
- 238000010276 construction Methods 0.000 claims description 6
- 238000013508 migration Methods 0.000 claims description 6
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- 238000004458 analytical method Methods 0.000 description 1
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- E—FIXED CONSTRUCTIONS
- E21—EARTH OR ROCK DRILLING; MINING
- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/16—Enhanced recovery methods for obtaining hydrocarbons
- E21B43/164—Injecting CO2 or carbonated water
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- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B43/00—Methods or apparatus for obtaining oil, gas, water, soluble or meltable materials or a slurry of minerals from wells
- E21B43/30—Specific pattern of wells, e.g. optimising the spacing of wells
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- E—FIXED CONSTRUCTIONS
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- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B49/00—Testing the nature of borehole walls; Formation testing; Methods or apparatus for obtaining samples of soil or well fluids, specially adapted to earth drilling or wells
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- E21B—EARTH OR ROCK DRILLING; OBTAINING OIL, GAS, WATER, SOLUBLE OR MELTABLE MATERIALS OR A SLURRY OF MINERALS FROM WELLS
- E21B2200/00—Special features related to earth drilling for obtaining oil, gas or water
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Abstract
The invention discloses a well pattern optimization method and a system based on carbon dioxide incomplete miscible displacement characteristics, wherein the method comprises the following steps: calculating an actual limit well distance based on indoor experimental data; obtaining the limit well spacing of the carbon dioxide flooding well based on the actual limit well spacing; and optimizing the limit well spacing of the carbon dioxide flooding well to finish well pattern optimization. The invention is based on the carbon dioxide incomplete miscible displacement characteristics, combines a mathematical method and oil reservoir numerical simulation, considers parameters such as a starting pressure gradient, an oil extraction speed and the like, develops optimization of a technical limit well spacing of a low-permeability oil reservoir, and on the basis, defines component front edges, phase front edges and pressure front edge rules in the carbon dioxide development process of the low-permeability oil reservoir, and establishes a well spacing optimization method based on the carbon dioxide incomplete miscible displacement characteristics for the first time.
Description
Technical Field
The invention relates to the field of well spacing optimization, in particular to a well pattern optimization method and system based on carbon dioxide incomplete miscible displacement characteristics.
Background
The low-permeability oil reservoir has the characteristics of strong reservoir heterogeneity, complex pore structure, micro-nano pore-throat development and the like, and the problems of poor energy supplement, low production degree and the like in conventional failure development and water injection development can be effectively solved by the technology of improving the recovery ratio of carbon dioxide injection oil displacement.
At present, the development of carbon dioxide injection of low-permeability oil reservoirs is realized, because the pores are relatively smaller, the throat is relatively thinner, the connectivity among the pores is relatively poorer, the phenomenon of pressure funnels exists among injection and production wells, the pressure is reduced from the injection well to the production well, and meanwhile, the pressure distribution is wider under the condition of large well spacing of the offshore low-permeability oil reservoirs, and the integral phase mixing of the oil reservoirs is difficult to realize.
Through the analysis, the key point of the carbon dioxide flooding is to ensure the miscible degree, the quantitative representation of the miscible degree of the oil reservoir is important to the prediction of the development index of the carbon dioxide flooding, the representation of the miscible degree of the carbon dioxide flooding firstly needs to describe the migration rules of the pressure front, the component front and the phase front, and the position of the formation pressure equal to the minimum miscible pressure of the carbon dioxide and the crude oil between the injection and production wells is called as the miscible pressure front; the position closest to the injection well, where the mole fraction of the carbon dioxide component between the injection and production wells is 0, is defined as the component front during the displacement process; the position closest to the production well that is swept by the oil and gas interfacial tension of 0 between the injection and production wells during displacement is defined as the phase front.
The injection and production well spacing is a key factor influencing the development effect of the low-permeability reservoir, and the low-permeability reservoir has larger seepage resistance, so that the well spacing is overlarge, the pressure loss between the injection and production wells is serious, and the pressure loss between the injection and production wells is overcome, so that effective displacement cannot be formed; too small well spacing increases investment cost and development risk. The related research provides corresponding methods for determining the reasonable well spacing of the low-permeability oil reservoir, but the methods do not consider the influence of the stress sensitivity effect of the reservoir on the permeability, and all assume that the reservoir permeability is static and unchanged. In practice, however, the pressure sensitive effects of the reservoir will cause changes in permeability which are different in the hydrocarbon well zone.
The common carbon dioxide flooding limit well spacing optimization method is to establish a technical limit well spacing and an economic limit well spacing, wherein the technical limit well spacing of the low-permeability oil reservoir is that the radial distance around the injection well in the quasi-western flow state is the technical limit well spacing under a certain injection and production pressure difference condition. The economic and reasonable well spacing is usually larger than the technical limit well spacing, and effective displacement cannot be formed in the middle of oil and water wells due to the large starting pressure gradient. At this time, the driving pressure difference has a larger influence on the combined oil supply radius, and the increased displacement pressure difference has a smaller influence on the well spacing and the exploitation effect. In addition, the conventional limit well spacing optimization does not consider typical incomplete miscible displacement characteristics of low-permeability reservoirs, errors exist in recovery ratio evaluation, gas-finding time prediction and oil-gas migration rules, well spacing design under the condition of a real low-permeability reservoir is not facilitated, and difficulty is brought to policy formulation of actual development of the low-permeability reservoir.
Disclosure of Invention
In order to solve the technical problems in the background, the invention establishes an optimization scheme of oil reservoir well spacing based on incomplete miscible characteristics such as component leading edge, phase leading edge, pressure leading edge law and the like in the low-permeability oil reservoir carbon dioxide development process. Simultaneously, the economic conditions of crude oil development such as oil reservoir recovery ratio, accumulated oil yield, oil change rate and the like and the social benefits of energy conservation and emission reduction of carbon dioxide burial are comprehensively considered to formulate an optimization scheme of oil reservoir well spacing.
To achieve the above object, the present invention provides a well pattern optimization method based on carbon dioxide incomplete miscible displacement characteristics, comprising the steps of:
Calculating an actual limit well distance based on indoor experimental data;
obtaining the limit well spacing of the carbon dioxide flooding well based on the actual limit well spacing;
and optimizing the limit well spacing of the carbon dioxide flooding well to finish well pattern optimization.
Preferably, the method for calculating the actual limit well spacing comprises the following steps:
Based on the indoor experimental data, determining the starting pressure gradient of the fluid under the oil reservoir condition;
calculating a theoretical maximum technical limit well distance based on the starting pressure gradient;
and calculating the actual limit well spacing based on the theoretical maximum technical limit well spacing.
Preferably, the method for calculating the theoretical maximum technical limit well spacing comprises the following steps:
Wherein G (k) represents the starting pressure gradient in units of: mpa·m -1;PH represents the supply pressure in units: MPa; p W represents the bottom hole flow pressure in units: MPa; r represents well spacing, unit: m; r W denotes well radius, unit: m; k represents the effective permeability in units of: and mD.
Preferably, the theoretical maximum technical limit well spacing is further optimized by combining different oil extraction speeds and injection-production pressure differences in actual production, so as to obtain the actual limit well spacing:
Wherein, Q 1、Q2 represents crude oil yield, unit: m 3/d; v represents the oil recovery rate; r represents well spacing, unit: m; h represents the effective thickness of the oil reservoir, in units of: m; s o represents oil saturation; Representing porosity; Δp represents the injection and production differential pressure in units of: MPa; k represents the effective permeability in units of: mD; mu represents viscosity, unit: mPas.
Preferably, the method for completing the well pattern optimization comprises the following steps: judging the oil reservoir state by judging the front edge characteristics in the carbon dioxide displacement process; when the oil reservoir state is a non-complete miscible state, analyzing the migration rule of the front edge characteristic, and completing well spacing optimization based on the carbon dioxide non-complete miscible displacement characteristic; wherein the leading edge feature comprises: mixed phase pressure front characteristics, component front characteristics, and phase front characteristics.
The invention also provides a well pattern optimization system based on the carbon dioxide incomplete miscible displacement characteristic, which is used for realizing the method and comprises the following steps: the system comprises a calculation module, a construction module and an optimization module;
the calculation module is used for calculating the actual limit well distance based on the indoor experimental data;
the construction module is used for obtaining the limit well spacing of the carbon dioxide flooding well based on the actual limit well spacing;
and the optimizing module is used for optimizing the limit well spacing of the carbon dioxide flooding well and completing well pattern optimization.
Preferably, the workflow of the computing module includes:
Based on the indoor experimental data, determining the starting pressure gradient of the fluid under the oil reservoir condition;
calculating a theoretical maximum technical limit well distance based on the starting pressure gradient;
and calculating the actual limit well spacing based on the theoretical maximum technical limit well spacing.
Preferably, the process of calculating the theoretical maximum technical limit well spacing includes:
Wherein G (k) represents the starting pressure gradient in units of: mpa·m -1;PH represents the supply pressure in units: MPa; p W represents the bottom hole flow pressure in units: MPa; r represents well spacing, unit: m; r W denotes well radius, unit: m; k represents the effective permeability in units of: and mD.
Compared with the prior art, the invention has the following beneficial effects:
The invention is based on the carbon dioxide incomplete miscible displacement characteristics, combines a mathematical method and oil reservoir numerical simulation, considers parameters such as a starting pressure gradient, an oil extraction speed and the like, develops optimization of a technical limit well spacing of a low-permeability oil reservoir, and on the basis, defines component front edges, phase front edges and pressure front edge rules in the carbon dioxide development process of the low-permeability oil reservoir, and establishes a well spacing optimization method based on the carbon dioxide incomplete miscible displacement characteristics for the first time.
Drawings
In order to more clearly illustrate the technical solutions of the present invention, the drawings that are needed in the embodiments are briefly described below, and it is obvious that the drawings in the following description are only some embodiments of the present invention, and that other drawings can be obtained according to these drawings without inventive effort for a person skilled in the art.
FIG. 1 is a schematic flow chart of a method according to an embodiment of the invention;
FIG. 2 is a graph of a start-up pressure gradient of an embodiment of the present invention;
FIG. 3 is a schematic diagram of the theoretical maximum technical limit well spacing results according to an embodiment of the present invention;
FIG. 4 is a schematic diagram of actual limiting well spacing at different oil recovery rates according to an embodiment of the present invention; wherein a), b), c), d), e) represent oil recovery speeds of 1%, 1.5%, 2%, 2.5%, 3%, respectively;
FIG. 5 is a schematic diagram of a carbon dioxide flooding of a well pattern according to an embodiment of the present invention; wherein a) is 500m×250m; b) 700 m.times.350 m;
FIG. 6 is a graphical illustration of three leading edge displacements at different well distances for an embodiment of the present invention; wherein a) is 500m×250m; b) 700 m.times.350 m.
Detailed Description
The following description of the embodiments of the present invention will be made clearly and completely with reference to the accompanying drawings, in which it is apparent that the embodiments described are only some embodiments of the present invention, but not all embodiments. All other embodiments, which can be made by those skilled in the art based on the embodiments of the invention without making any inventive effort, are intended to be within the scope of the invention.
In order that the above-recited objects, features and advantages of the present invention will become more readily apparent, a more particular description of the invention will be rendered by reference to the appended drawings and appended detailed description.
Example 1
Based on the defects, the embodiment designs a well pattern optimization method based on the carbon dioxide incomplete miscible displacement characteristic, as shown in fig. 1, comprising the following steps:
S1, calculating the limit well spacing of the carbon dioxide flooding well based on indoor experimental data. The method comprises the following specific steps:
based on the laboratory experimental data, the starting pressure gradient of the fluid under the reservoir conditions is determined.
The starting pressure gradient of the fluid under reservoir conditions is determined based on an in-house experiment as shown in figure 2.
Then, based on the starting pressure gradient, a theoretical maximum technical limit well distance is calculated.
Specifically, based on the nonlinear seepage theory, when the minimum value of the pressure gradient between injection and production wells is equal to the starting pressure gradient, the injection and production well spacing at the moment is the theoretical maximum technical limit well spacing, namely:
Wherein G (k) represents the starting pressure gradient in units of: mpa·m -1;PH represents the supply pressure in units: MPa; p W represents the bottom hole flow pressure in units: MPa; r represents well spacing, unit: m; r W denotes well radius, unit: m; k represents the effective permeability in units of: and mD.
The theoretical maximum technical limit well spacing calculated by the above steps is shown in fig. 3.
And finally, calculating the actual limit well spacing based on the theoretical maximum technical limit well spacing.
Based on the theoretical maximum technical limit well spacing, the theoretical maximum technical limit well spacing is further optimized by combining different oil extraction speeds (1%, 1.5%, 2%, 2.5%, 3%) and injection and production pressure differences in actual production, and a yield relation is established based on the oil extraction speed, the pressure differences and a Darcy formula to obtain the limit well spacing of the carbon dioxide flooding well:
Wherein, Q 1、Q2 represents crude oil yield, unit: m 3/d; v represents the oil recovery rate; r represents well spacing, unit: m; h represents the effective thickness of the oil reservoir, in units of: m; s o represents oil saturation; Representing porosity; Δp represents the injection and production differential pressure in units of: MPa; k represents the effective permeability in units of: mD; mu represents viscosity, unit: mPas.
Based on the equality of crude oil production, the two equations are combined to obtain a limit well spacing (i.e., the actual limit well spacing) taking into account the oil recovery rate and the pressure differential, as shown in FIG. 4.
S2, obtaining the limit well spacing of the carbon dioxide flooding well based on the actual limit well spacing.
And establishing a three-dimensional oil deposit model through a GEM module of oil deposit numerical simulation software, and setting parameters such as oil deposit depth, oil deposit temperature, oil deposit pressure, oil deposit porosity, oil deposit permeability, oil deposit oil saturation, oil deposit temperature gradient, oil deposit pressure coefficient, saturation pressure and the like. And setting production parameters such as carbon dioxide injection quantity, injection pressure, production pressure and the like in the carbon dioxide displacement process by utilizing the established three-dimensional oil reservoir model and respectively considering well spacing conditions of different oil reservoirs, so as to obtain the limit well spacing of the carbon dioxide flooding well.
The carbon dioxide flooding fluid phase state changes are complex, and in this embodiment, the model constructed is a homogeneous three-dimensional reservoir model. The number of grids is set to 20×20×3=1200, each grid is 50m×50m, encryption of each grid 3×3 is performed, and physical parameters of the reservoir are as follows: the depth of the oil deposit is 3500m, the temperature of the oil deposit is 126 ℃, the initial pressure of the oil deposit is 55.0MPa, the porosity of the oil deposit is 13.9%, the permeability of the oil deposit is 8mD, the oil saturation of the oil deposit is 60%, and the viscosity of the crude oil of the stratum is 1.98 mPa.s. The density of the ground degassing crude oil is 0.862g/cm 3. The volume coefficient of the stratum crude oil is 1.14, and the viscosity of the stratum crude oil is 0.44-1.25 mPa.s. The block temperature-pressure test ground temperature gradient is 3.76 ℃/hm, the pressure coefficient is 1.44, the original stratum pressure is 55.0MPa, and the reservoir saturation pressure is 17.3MPa. Optimizing the type of the carbon dioxide flooding well distance based on the established homogeneous model, setting the production system of the carbon dioxide injection quantity, the injection pressure and the production pressure as a numerical simulation model, setting the single-well carbon dioxide injection quantity to 100000m 3/d, setting the injection pressure to 57.0MPa, setting the production pressure to 18.0MPa, and setting the production time to 30 years. Based on the five-point well pattern form, two well spacing conditions of 500m×250m and 700m×350m are considered respectively, as shown in fig. 5.
S3, optimizing the limit well spacing of the carbon dioxide flooding well, and completing well pattern optimization.
First, the state of the oil reservoir is judged by judging the front edge characteristics in the carbon dioxide displacement process.
In this embodiment, the leading edge features include: mixed phase pressure front characteristics, component front characteristics, and phase front characteristics. The definition of these three leading edges includes:
The location between the injection wells where the formation pressure equals the minimum miscible pressure of carbon dioxide and crude oil is referred to as the miscible pressure front;
supercritical carbon dioxide can be dissolved in crude oil and stratum water and convected and diffused along with fluids such as oil water and the like, so that the position closest to an injection well, which is swept by the mole fraction of the carbon dioxide component between injection wells of 0 in the displacement process, is defined as a component front;
carbon dioxide and crude oil are incompatible two phases at normal temperature and normal pressure, and supercritical carbon dioxide and crude oil can be dissolved into one phase under the formation temperature and pressure condition, so that the position closest to a production well, which is swept by the fact that the oil-gas interfacial tension between injection and production wells is 0in the displacement process, is defined as a phase front.
After the oil reservoir is set, a dat file of Bulider modules in the numerical simulation software CMG is saved, numerical simulation operation work is carried out based on the GEM module, an sr3 file with an operation Result being completed is opened through the Result module, and based on the file, an oil reservoir pressure field diagram, a carbon dioxide concentration field diagram and an oil-gas interfacial tension field diagram in the operation Result are analyzed, and the mixed phase pressure front characteristic, the component front characteristic and the phase front characteristic in the carbon dioxide displacement process are judged.
And when the oil reservoir state is a non-complete miscible state, analyzing the migration rule of the front edge characteristic.
When the pressure front contacts with the component front, namely the oil reservoir is in an incomplete miscible state, the migration rules of the three front edges are analyzed, the retraction speed of the miscible pressure front edge is judged, the carbon dioxide sweep coefficient is in a miscible degree, and well pattern optimization based on the carbon dioxide incomplete miscible displacement characteristic is carried out.
The AERIALVIEW plane display interface in the result file is opened, and based on the oil reservoir pressure field diagram, the carbon dioxide concentration field diagram and the oil-gas interfacial tension field diagram, the result is shown in fig. 6, as the injection and production well spacing is increased from 500m×250m to 700m×350m, the sweep range of the component front edge and the phase front edge is reduced by 6%, the miscible phase degree of a carbon dioxide-crude oil system in the oil reservoir range is reduced by 9%, the crude oil density reduction degree is reduced by 4.7%, the crude oil viscosity reduction degree is reduced by 4.5%, and the improvement of the crude oil development effect of carbon dioxide flooding is not facilitated, so that the actual development should select the well spacing of 500m×250m. Thus, well spacing optimization based on the carbon dioxide incomplete miscible displacement characteristic is completed.
Example two
The present real-time example also provides a well pattern optimization system based on carbon dioxide incomplete miscible displacement characteristics, comprising: the system comprises a calculation module, a construction module and an optimization module; the calculation module is used for calculating the actual limit well distance based on the indoor experimental data; the construction module is used for obtaining the limit well spacing of the carbon dioxide flooding well based on the actual limit well spacing; the optimization module is used for optimizing the limit well spacing of the carbon dioxide flooding well and completing well pattern optimization.
The workflow of the computing module includes: based on the indoor experimental data, determining the starting pressure gradient of the fluid under the oil reservoir condition; calculating a theoretical maximum technical limit well distance based on the starting pressure gradient; based on the theoretical maximum technical limit well spacing, calculating the actual limit well spacing.
The process for calculating the theoretical maximum technical limit well spacing comprises the following steps:
Wherein G (k) represents the starting pressure gradient in units of: mpa·m -1;PH represents the supply pressure in units: MPa; p W represents the bottom hole flow pressure in units: MPa; r represents well spacing, unit: m; r W denotes well radius, unit: m; k represents the effective permeability in units of: and mD.
And then, further optimizing the theoretical maximum technical limit well spacing by combining different oil extraction speeds and injection-production pressure differences in actual production to obtain the actual limit well spacing:
Wherein, Q 1、Q2 represents crude oil yield, unit: m 3/d; v represents the oil recovery rate; r represents well spacing, unit: m; h represents the effective thickness of the oil reservoir, in units of: m; s o represents oil saturation; Representing porosity; Δp represents the injection and production differential pressure in units of: MPa; k represents the effective permeability in units of: mD; mu represents viscosity, unit: mPas.
The above embodiments are merely illustrative of the preferred embodiments of the present invention, and the scope of the present invention is not limited thereto, but various modifications and improvements made by those skilled in the art to which the present invention pertains are made without departing from the spirit of the present invention, and all modifications and improvements fall within the scope of the present invention as defined in the appended claims.
Claims (3)
1. The well pattern optimization method based on the carbon dioxide incomplete miscible displacement characteristic is characterized by comprising the following steps of:
Calculating an actual limit well distance based on indoor experimental data; the method for calculating the actual limit well distance comprises the following steps:
Based on the indoor experimental data, determining the starting pressure gradient of the fluid under the oil reservoir condition;
calculating a theoretical maximum technical limit well distance based on the starting pressure gradient; the method for calculating the theoretical maximum technical limit well spacing comprises the following steps:
Wherein G (k) represents the starting pressure gradient in units of: mpa·m -1;PH represents the supply pressure in units: MPa; p W represents the bottom hole flow pressure in units: MPa; r represents well spacing, unit: m; r W denotes well radius, unit: m; k represents the effective permeability in units of: mD;
Obtaining the limit well spacing of the carbon dioxide flooding well based on the actual limit well spacing; specifically, calculating the actual limit well spacing based on the theoretical maximum technical limit well spacing; and further optimizing the theoretical maximum technical limit well spacing by combining different oil extraction speeds and injection and production pressure differences in actual production to obtain the actual limit well spacing:
Wherein, Q 1、Q2 represents crude oil yield, unit: m 3/d; v represents the oil recovery rate; r represents well spacing, unit: m; h represents the effective thickness of the oil reservoir, in units of: m; s o represents oil saturation; representing porosity; Δp represents the injection and production differential pressure in units of: MPa; k represents the effective permeability in units of: mD; mu represents viscosity, unit: mPa.s;
Establishing a three-dimensional oil deposit model through a GEM module of oil deposit numerical simulation software, and setting the depth of an oil deposit, the temperature of the oil deposit, the pressure of the oil deposit, the porosity of the oil deposit, the permeability of the oil deposit, the oil deposit oil saturation, the temperature gradient of the oil deposit, the pressure coefficient of the oil deposit and the saturation pressure; setting carbon dioxide injection quantity, injection pressure and production pressure production parameters in the carbon dioxide displacement process by utilizing the established three-dimensional oil reservoir model and respectively considering well spacing conditions of different oil reservoirs to obtain the limit well spacing of the carbon dioxide displacement well;
and optimizing the limit well spacing of the carbon dioxide flooding well to finish well pattern optimization.
2. The method of optimizing a well pattern based on carbon dioxide non-fully miscible displacement characteristics of claim 1, wherein the method of performing the well pattern optimization comprises: judging the oil reservoir state by judging the front edge characteristics in the carbon dioxide displacement process; when the oil reservoir state is a non-complete miscible state, analyzing the migration rule of the front edge characteristic, and completing well spacing optimization based on the carbon dioxide non-complete miscible displacement characteristic; wherein the leading edge feature comprises: mixed phase pressure front characteristics, component front characteristics, and phase front characteristics.
3. A well pattern optimization system based on carbon dioxide non-fully miscible displacement characteristics for implementing the method of any of claims 1-2, comprising: the system comprises a calculation module, a construction module and an optimization module;
the calculation module is used for calculating the actual limit well distance based on the indoor experimental data; the workflow of the computing module includes:
Based on the indoor experimental data, determining the starting pressure gradient of the fluid under the oil reservoir condition;
Calculating a theoretical maximum technical limit well distance based on the starting pressure gradient; the process for calculating the theoretical maximum technical limit well spacing comprises the following steps:
Wherein G (k) represents the starting pressure gradient in units of: mpa·m -1;PH represents the supply pressure in units: MPa; p W represents the bottom hole flow pressure in units: MPa; r represents well spacing, unit: m; r W denotes well radius, unit: m; k represents the effective permeability in units of: mD;
Establishing a three-dimensional oil deposit model through a GEM module of oil deposit numerical simulation software, and setting the depth of an oil deposit, the temperature of the oil deposit, the pressure of the oil deposit, the porosity of the oil deposit, the permeability of the oil deposit, the oil deposit oil saturation, the temperature gradient of the oil deposit, the pressure coefficient of the oil deposit and the saturation pressure; setting carbon dioxide injection quantity, injection pressure and production pressure production parameters in the carbon dioxide displacement process by utilizing the established three-dimensional oil reservoir model and respectively considering well spacing conditions of different oil reservoirs to obtain the limit well spacing of the carbon dioxide displacement well;
Calculating the actual limit well spacing based on the theoretical maximum technical limit well spacing;
the construction module is used for obtaining the limit well spacing of the carbon dioxide flooding well based on the actual limit well spacing;
and the optimizing module is used for optimizing the limit well spacing of the carbon dioxide flooding well and completing well pattern optimization.
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